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Chevron Corp (CVX) SEC Filing 10-K Annual Report for the fiscal year ending Friday, December 31, 2021

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Chevron Corp

CIK: 93410 Ticker: CVX

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news release
EXHIBIT 99.1
FOR RELEASE AT 3:45 AM PT
JANUARY 28, 2022

Chevron Announces Fourth Quarter 2021 Results
Fourth quarter earnings of $5.1 billion; annual earnings of $15.6 billion
Strong cash flow from operations of $29.2 billion in 2021
Record free cash flow of $21.1 billion in 2021
Dividends and share repurchases of $11.6 billion in 2021
San Ramon, Calif., January 28, 2022 – Chevron Corporation (NYSE: CVX) today reported earnings of $5.1 billion ($2.63 per share - diluted) for fourth quarter 2021, compared with a loss of $665 million ($(0.33) per share - diluted) in fourth quarter 2020. Included in the current quarter were asset sale gains of $520 million, losses on the early retirement of debt of $260 million and pension settlement costs of $82 million. Foreign currency effects decreased earnings by $40 million. Adjusted earnings of $4.9 billion ($2.56 per share - diluted) in fourth quarter 2021 compares to adjusted earnings of $298 million ($0.16 per share - diluted) in fourth quarter 2020.
Chevron reported full-year 2021 earnings of $15.6 billion ($8.14 per share - diluted), compared with a loss of $5.5 billion ($(2.96) per share - diluted) in 2020. Included in 2021 were net charges for special items of $289 million, compared to net charges of $5.1 billion for special items in 2020. Foreign currency effects increased earnings in 2021 by $306 million. Adjusted earnings of $15.6 billion ($8.13 per share - diluted) in 2021 compares to adjusted earnings of $172 million ($0.09 per share - diluted) in 2020. For a reconciliation of adjusted earnings/(loss), see Attachment 5.
Sales and other operating revenues in fourth quarter 2021 were $46 billion, compared to $25 billion in the year-ago period.
Earnings Summary
 Three Months
Ended Dec. 31
Year Ended Dec. 31
Millions of dollars
2021202020212020
Earnings by business segment
Upstream
$5,155$501$15,818$(2,433)
Downstream
760(338)2,91447
All Other
(860)(828)(3,107)(3,157)
Total (1)(2)
$5,055$(665)$15,625$(5,543)
(1) Includes foreign currency effects
$(40)$(534)$306$(645)
(2) Net income attributable to Chevron Corporation (See Attachment 1)
“In 2021, we delivered record free cash flow and accelerated our progress towards a lower carbon future,” said Mike Wirth, Chevron’s chairman and chief executive officer. “We’re an even

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The following information was filed by Chevron Corp (CVX) on Friday, January 28, 2022 as an 8K 2.02 statement, which is an earnings press release pertaining to results of operations and financial condition. It may be helpful to assess the quality of management by comparing the information in the press release to the information in the accompanying 10-K Annual Report statement of earnings and operation as management may choose to highlight particular information in the press release.

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
  ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2021
OR
  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from ______ to ______
Commission File Number 001-00368
Chevron Corporation
(Exact name of registrant as specified in its charter)
6001 Bollinger Canyon Road
Delaware94-0890210San Ramon,California94583-2324
(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
Securities registered pursuant to Section 12(b) of the Act:
 
Title of each classTrading SymbolName of each exchange on which registered
Common stock, par value $.75 per shareCVXNew York Stock Exchange
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes þ          No o
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
Yes o          No þ
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes þ          No o
Indicate by check mark whether the registrant has submitted electronically 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 þ          No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filerAccelerated filer
Non-accelerated filerSmaller 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. o  
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal controls over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.  ☑
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).      Yes        No þ
The aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter — $202.5 billion (As of June 30, 2021)
 Number of Shares of Common Stock outstanding as of February 10, 2022 — 1,947,553,346
DOCUMENTS INCORPORATED BY REFERENCE
(To The Extent Indicated Herein)
Notice of the 2022 Annual Meeting and 2022 Proxy Statement, to be filed pursuant to Rule 14a-6(b) under the Securities Exchange Act of 1934, in connection with the company’s 2022 Annual Meeting of Stockholders (in Part III)





TABLE OF CONTENTS
ITEMPAGE
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CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This Annual Report on Form 10-K of Chevron Corporation contains forward-looking statements relating to Chevron’s operations and energy transition plans 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,” “advances,” “commits,” “drives,” “aims,” “forecasts,” “projects,” “believes,” “approaches,” “seeks,” “schedules,” “estimates,” “positions,” “pursues,” “may,” “can,” “could,” “should,” “will,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on track,” “goals,” “objectives,” “strategies,” “opportunities,” “poised,” “potential,” “ambitions,” “aspires” 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 the company’s 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; technological advancements; changes to government policies in the countries in which the company operates; public health crises, such as pandemics (including coronavirus (COVID-19)) and epidemics, and any related government policies and actions; disruptions in the company’s global supply chain, including supply chain constraints and escalation of the cost of goods and services; 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; actions of competitors or regulators; timing of exploration expenses; timing of crude oil liftings; the competitiveness of alternate-energy sources or product substitutes; development of large carbon capture and offset markets; the results of operations and financial condition of the company’s suppliers, vendors, partners and equity affiliates, particularly 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 undertaken or 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 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, taxes and tax audits, 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 implement capital allocation strategies, including future stock repurchase programs and dividend payments; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; the company’s ability to identify and mitigate the risks and hazards inherent in operating in the global energy industry; and the factors set forth under the heading “Risk Factors” on pages 20 through 25 in this report. Other unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.
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PART I
Item 1. Business
General Development of Business
Summary Description of Chevron
Chevron Corporation,* a Delaware corporation, manages its investments in subsidiaries and affiliates and provides administrative, financial, management and technology support to U.S. and international subsidiaries that engage in integrated energy and chemicals operations. Upstream operations consist primarily of exploring for, developing, producing and transporting crude oil and natural gas; processing, liquefaction, transportation and regasification associated with liquefied natural gas; transporting crude oil by major international oil export pipelines; transporting, storage and marketing of natural gas; and a gas-to-liquids plant. Downstream operations consist primarily of refining crude oil into petroleum products; marketing of crude oil, refined products, and lubricants; manufacturing and marketing of renewable fuels; transporting crude oil and refined products by pipeline, marine vessel, motor equipment and rail car; and manufacturing and marketing of commodity petrochemicals, plastics for industrial uses and fuel and lubricant additives.
A list of the company’s major subsidiaries is presented in Exhibit 21.1.
Overview of Petroleum Industry
Petroleum industry operations and profitability are influenced by many factors. Prices for crude oil, natural gas, petroleum products and petrochemicals are generally determined by supply and demand. Production levels from the members of Organization of Petroleum Exporting Countries (OPEC), Russia and the United States are the major factors in determining worldwide supply. Demand for crude oil and its products and for natural gas is largely driven by the conditions of local, national and global economies, although weather patterns, the pace of energy transition and taxation relative to other energy sources also play a significant part. Laws and governmental policies, particularly in the areas of taxation, energy and the environment, affect where and how companies invest, conduct their operations, select feedstocks, and formulate their products and, in some cases, limit their profits directly.
Strong competition exists in all sectors of the petroleum and petrochemical industries in supplying the energy, fuel and chemical needs of industry and individual consumers. In the upstream business, Chevron competes with fully integrated, major global petroleum companies, as well as independent and national petroleum companies, for the acquisition of crude oil and natural gas leases and other properties and for the equipment and labor required to develop and operate those properties. In its downstream business, Chevron competes with fully integrated, major petroleum companies, as well as independent refining and marketing, transportation and chemicals entities and national petroleum companies in the refining, manufacturing, sale and marketing of fuels, lubricants, additives and petrochemicals.
Operating Environment
Refer to pages 32 through 40 of this Form 10-K in Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of the company’s current business environment and outlook.
Chevron’s Strategic Direction
Chevron’s strategy is to leverage its strengths to deliver lower carbon energy to a growing world. The company’s primary objective is to deliver higher returns, lower carbon and superior shareholder value in any business environment. In the upstream, the company’s strategy is to deliver industry-leading returns while developing high-value resource opportunities. In the downstream, the company’s strategy is to be the leading downstream and chemicals company that delivers on customer needs. Chevron aims to lower the carbon intensity of its traditional oil and gas operations and grow lower carbon businesses in renewable fuels, hydrogen, carbon capture and offsets. To grow its lower carbon businesses, Chevron plans to target sectors of the economy where emissions are harder to abate or that cannot be easily electrified, while leveraging the company’s capabilities, assets and customer relationships.
Information about the company is available on the company’s website at www.chevron.com. Information contained on the company’s website is not part of this Annual Report on Form 10-K. The company’s Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and any amendments to these reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 are available free of charge on the company’s website soon after such reports are filed with or furnished to the U.S. Securities and Exchange Commission (SEC). The reports are also available on the SEC’s website at www.sec.gov.
________________________________________________________
* Incorporated in Delaware in 1926 as Standard Oil Company of California, the company adopted the name Chevron Corporation in 1984 and ChevronTexaco Corporation in 2001. In 2005, ChevronTexaco Corporation changed its name to Chevron Corporation. As used in this report, the term “Chevron” and such terms as “the company,” “the corporation,” “our,” “we,” “us” and "its" may refer to Chevron Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole, but unless stated otherwise they do not include “affiliates” of Chevron — i.e., those companies accounted for by the equity method (generally owned 50 percent or less) or non-equity method investments. 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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Human Capital Management
Chevron invests in its employees and culture, with the objective of developing the full potential of its workforce to deliver energy solutions and drive human progress. The Chevron Way explains the company’s beliefs, vision, purpose and values. It guides how the company’s employees work and establishes a common understanding of culture and aspirations. Chevron hires, develops, and strives to retain a diverse workforce of high-performing talent, and fosters a culture that values diversity, inclusion and employee engagement. Chevron leadership is accountable for the company’s investment in people and the company’s culture. This includes reviews of metrics addressing critical function hiring, leadership development, retention, diversity and inclusion, and employee engagement.
The following table summarizes the number of Chevron employees by gender, where data is available, and by region as of December 31, 2021.
At December 31, 2021
FemaleMale
Gender data not available1
Total Employees
Number of EmployeesPercentageNumber of EmployeesPercentageNumber of EmployeesPercentageNumber of EmployeesPercentage
Non-Service Station Employees
U.S.5,090 26 %14,512 74 %25 — %19,627 46 %
Other Americas925 27 %2,484 72 %37 %3,446 %
Africa612 17 %2,991 83 %— %3,606 %
Asia2,493 35 %4,621 65 %31 — %7,145 17 %
Australia533 25 %1,634 75 %— %2,170 %
Europe381 25 %1,121 75 %— %1,504 %
Total Non-Service Station Employees10,034 27 %27,363 73 %101 — %37,498 88 %
Service Station Employees2,170 43 %1,732 34 %1,195 23 %5,097 12 %
Total Employees12,204 29 %29,095 68 %1,296 3 %42,595 100 %
1 Includes employees where gender data was not collected or employee chose not to disclose gender.
Hiring, Development and Retention
The company’s approach to attracting, developing and retaining a diverse workforce of high-performing talent is anchored in a long-term employment model that fosters an environment of personal growth and engagement. Chevron’s philosophy is to offer compelling career opportunities and a competitive total compensation and benefits package linked to individual and enterprise performance. Chevron recruits new employees in part through partnerships with universities and diversity associations. In addition, the company recruits experienced hires to provide specialized skills.
Chevron’s learning and development programs are designed to help employees achieve their full potential by building technical, operating and leadership capabilities at all levels to produce energy safely, reliably and efficiently. Chevron’s leadership regularly reviews metrics on employee training and development programs, which are continually evolving to meet the needs of our evolving business. For example, the company delivers learning experiences digitally to empower its employees, in any location, to develop, maintain and enhance critical skills. In addition, to ensure business continuity, leadership regularly reviews the talent pipeline, identifies and develops succession candidates, and builds succession plans for key positions. The Board of Directors provides oversight of CEO and executive succession planning.
Management routinely reviews the retention of its professional population, which includes executives, all levels of management, and the majority of its regular employee population. The annual voluntary attrition for this population was 4.5 percent, which is in line with rates over a five-year comparison period. The voluntary attrition rate generally excludes employee departures under enterprise-wide restructuring programs. Chevron believes its low voluntary attrition rate is in part a result of the company’s commitment to employee development, its long-term employment model, competitive pay and benefits, and its culture.
Diversity and Inclusion
Chevron believes innovative solutions to the most complex challenges emerge when diverse people, ideas, and experiences come together in an inclusive environment. Chevron reinforces the values of diversity and inclusion through recruitment and talent development, equitable selection processes, community partnerships and supplier diversity. Examples of
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initiatives to further advance diversity and inclusion include the company’s MARC (Men Advocating Real Change) program launched in 2017 in partnership with the non-profit organization Catalyst to facilitate discussions on gender equity in the workplace, and selection processes that reinforce the importance of diverse selection teams and candidate slates. In addition, Chevron has twelve employee networks (voluntary groups of employees that come together based on shared identity or interests) and a Chairman’s Inclusion Council, which provides the employee network presidents with a direct line of communication to the Chairman and Chief Executive Officer, the Chief Human Resources Officer, the Chief Diversity and Inclusion Officer, and the executive leadership team to collaborate and discuss how employee networks can reinforce Chevron’s values of diversity and inclusion.
Employee Engagement
Employee engagement is an indicator of employee well-being and commitment to the company’s values, purpose and strategies. Chevron regularly conducts employee surveys to assess the health of the company’s culture; recent surveys indicate high employee engagement. In 2021, the company increased survey frequency to better understand employee sentiment throughout the year, including focused efforts to gain insights into employee well-being. Chevron prioritizes the health, safety and well-being of its employees. Chevron’s safety culture empowers every member of its workforce to exercise stop-work authority without repercussion to address any potential unsafe work conditions. Chevron developed new safeguards and operating standards and updated existing protocols to adjust for the ever-changing conditions of the pandemic, including a return to the workplace strategy, with paced, condition-based stages. The company also announced a hybrid work model based on employee feedback and learnings from the pandemic, which will allow certain employees the flexibility to combine in-office and remote work. Additionally, the company offers long-standing employee support programs such as Ombuds, an independent resource designed to equip employees with options to address and resolve workplace issues; a company hotline, where employees can report concerns to the Corporate Compliance department; and an Employee Assistance Program, a confidential consulting service that can help employees resolve a broad range of personal, family and work-related concerns.






















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Description of Business and Properties
The upstream and downstream activities of the company and its equity affiliates are widely dispersed geographically, with operations and projects* in North America, South America, Europe, Africa, Asia and Australia. Tabulations of segment sales and other operating revenues, earnings, assets, and income taxes for the three years ending December 31, 2021, and assets as of the end of 2021 and 2020 — for the United States and the company’s international geographic areas — are in Note 14 Operating Segments and Geographic Data to the Consolidated Financial Statements. Similar comparative data for the company’s investments in and income from equity affiliates and property, plant and equipment are in Note 15 Investments and Advances and Note 18 Property, Plant and Equipment. Refer to page 45 of this Form 10-K in Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of the company’s capital and exploratory expenditures.

Upstream
Reserves
Refer to Table V for a tabulation of the company’s proved reserves by geographic area, at the beginning of 2019 and at each year-end from 2019 through 2021. Reserves governance, technologies used in establishing proved reserves additions, and major changes to proved reserves by geographic area for the three-year period ended December 31, 2021, are summarized in the discussion for Table V. Discussion is also provided regarding the nature of, status of, and planned future activities associated with the development of proved undeveloped reserves. The company recognizes reserves for projects with various development periods, sometimes exceeding five years. The external factors that impact the duration of a project include scope and complexity, remoteness or adverse operating conditions, infrastructure constraints, and contractual limitations.
At December 31, 2021, 34 percent of the company’s net proved oil-equivalent reserves were located in the United States, 19 percent were located in Australia and 16 percent were located in Kazakhstan.
The net proved reserve balances at the end of each of the three years 2019 through 2021 are shown in the following table:
At December 31
202120202019
Liquids — Millions of barrels
Consolidated Companies4,756 4,475 4,771 
Affiliated Companies1,357 1,672 1,750 
Total Liquids6,113 6,147 6,521 
Natural Gas — Billions of cubic feet
Consolidated Companies28,314 27,006 26,587 
Affiliated Companies2,594 2,916 2,870 
Total Natural Gas30,908 29,922 29,457 
Oil-Equivalent — Millions of barrels1
Consolidated Companies9,475 8,976 9,202 
Affiliated Companies1,789 2,158 2,229 
Total Oil-Equivalent11,264 11,134 11,431 
1 Oil-equivalent conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil.
________________________________________________________
*    As used in this report, the term “project” may describe new upstream development activity, individual phases in a multiphase development, maintenance activities, certain existing assets, new investments in downstream and chemicals capacity, investments in emerging and sustainable energy activities, and certain other activities. All of these terms are used for convenience only and are not intended as a precise description of the term “project” as it relates to any specific governmental law or regulation.

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Net Production of Liquids and Natural Gas
The following table summarizes the net production of liquids and natural gas for 2021 and 2020 by the company and its affiliates. Worldwide oil-equivalent production of 3.099 million barrels per day in 2021 was up approximately 1 percent from 2020. Additional production from the Noble Energy, Inc. (Noble) acquisition and lower production curtailments were partially offset by asset sale related decreases of 80,000 barrels per day, expiration of the Rokan concession in Indonesia, unfavorable entitlement effects, and normal field declines. Refer to the “Results of Operations” section beginning on page 38 for a detailed discussion of the factors explaining the changes in production for crude oil, condensate, natural gas liquids, synthetic oil and natural gas, and refer to Table V for information on annual production by geographical region.
Components of Oil-Equivalent
Oil-EquivalentLiquidsNatural Gas
Thousands of barrels per day (MBPD)
(MBPD)1
(MBPD)(MMCFPD)
Millions of cubic feet per day (MMCFPD)202120202021202020212020
United States2
1,139 1,058 858 790 1,689 1,607 
Other Americas
Argentina
33 25 28 21 31 24 
Brazil
3 3  
Canada3
161 159 136 138 150 126 
Colombia4
  —  14 
Total Other Americas197 192 167 165 181 165 
Africa
Angola
78 87 70 78 52 53 
Equatorial Guinea2
52 11 18 204 42 
Nigeria
165 183 124 140 246 260 
Republic of Congo
39 46 37 44 13 13 
Total Africa334 327 249 267 515 368 
Asia
Azerbaijan4
   
Bangladesh
112 107 2 655 622 
China
30 32 12 15 104 100 
Indonesia
67 138 62 131 30 43 
Israel2
91 20 1 — 541 116 
Kazakhstan
41 55 24 32 103 136 
Kurdistan Region of Iraq2  2    
Myanmar
15 15  — 92 92 
Partitioned Zone5
58 18 56 17 7 
Philippines4
   25 
Thailand
163 207 41 54 736 918 
Total Asia579 604 200 260 2,268 2,058 
Australia
 Australia449 441 43 42 2,434 2,392 
Total Australia449 441 43 42 2,434 2,392 
Europe
United Kingdom4
14 14 13 13 6 
Total Europe14 14 13 13 6 
Total Consolidated Companies2,712 2,636 1,530 1,537 7,093 6,595 
Affiliates6
387 447 284 331 616 695 
Total Including Affiliates7
3,099 3,083 1,814 1,868 7,709 7,290 
1 Oil-equivalent conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil.
2 Includes production associated with the acquisition of Noble commencing October 2020.
3 Includes synthetic oil: Canada, net
55 5455 54 — 
4 Chevron sold its interest in various upstream producing assets in 2020 and 2021.
5 Located between Saudi Arabia and Kuwait. Production was shut-in in May 2015 and resumed in July 2020.
6 Volumes represent Chevron’s share of production by affiliates, including Tengizchevroil in Kazakhstan and Angola LNG in Angola.
7 Volumes include natural gas consumed in operations of 592 million and 603 million cubic feet per day in 2021 and 2020, respectively. Total “as sold” natural gas volumes were 7,117 million and 6,687 million cubic feet per day for 2021 and 2020, respectively.
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Production Outlook
The company estimates its average worldwide oil-equivalent production in 2022 to be flat to down three percent compared to 2021 assuming a Brent crude oil price of $60 per barrel and excluding the impact of asset sales that may close in 2022. Excluding contract expirations and 2022 asset sales, 2022 production is expected to increase by two to five percent compared to 2021. This estimate is subject to many factors and uncertainties, as described beginning on page 35. Refer to the “Review of Ongoing Exploration and Production Activities in Key Areas,” beginning on page 10, for a discussion of the company’s major crude oil and natural gas development projects.
Average Sales Prices and Production Costs per Unit of Production
Refer to Table IV for the company’s average sales price per barrel of crude (including crude oil and condensate) and natural gas liquids and per thousand cubic feet of natural gas produced, and the average production cost per oil-equivalent barrel for 2021, 2020 and 2019.
Gross and Net Productive Wells
The following table summarizes gross and net productive wells at year-end 2021 for the company and its affiliates:
At December 31, 2021
Productive Oil Wells1
Productive Gas Wells1
Gross Net Gross Net
United States37,346 28,321 2,430 2,055 
Other Americas1,094 682 245 161 
Africa1,744 683 50 19 
Asia2,276 1,158 2,454 1,168 
Australia533 299 105 29 
Europe34 — — 
Total Consolidated Companies43,027 31,150 5,284 3,432 
Affiliates2
1,662 600 — — 
Total Including Affiliates44,689 31,750 5,284 3,432 
Multiple completion wells included above731 431 148 116 
1 Gross wells represent the total number of wells in which Chevron has an ownership interest. Net wells represent the sum of Chevron’s ownership interest in gross wells.
2 Includes gross 1,423 and net 480 productive oil wells for interests accounted for by the non-equity method.
Acreage
At December 31, 2021, the company owned or had under lease or similar agreements undeveloped and developed crude oil and natural gas properties throughout the world. The geographical distribution of the company’s acreage is shown in the following table:
Undeveloped2
Developed Developed and Undeveloped
Thousands of acres1
Gross Net Gross Net Gross Net
United States3,949 3,383 4,513 3,136 8,462 6,519 
Other Americas20,156 11,314 1,088 240 21,244 11,554 
Africa9,066 4,941 2,522 1,051 11,588 5,992 
Asia17,445 6,397 1,593 773 19,038 7,170 
Australia9,999 6,099 2,061 812 12,060 6,911 
Europe109 21 15 124 24 
Total Consolidated Companies60,724 32,155 11,792 6,015 72,516 38,170 
Affiliates3
697 287 107 49 804 336 
Total Including Affiliates61,421 32,442 11,899 6,064 73,320 38,506 
1 Gross acres represent the total number of acres in which Chevron has an ownership interest. Net acres represent the sum of Chevron’s ownership interest in gross acres.
2 The gross undeveloped acres that will expire in 2022, 2023 and 2024 if production is not established by certain required dates are 11,590, 4,778, and 282, respectively.
3 Includes gross 405 and net 141 undeveloped and gross 19 and net 5 developed acreage for interests accounted for by the non-equity method.
Delivery Commitments
The company sells crude oil and natural gas from its producing operations under a variety of contractual obligations. Most contracts generally commit the company to sell quantities based on production from specified properties, but some natural gas and crude oil sales contracts specify delivery of fixed and determinable quantities.
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In the United States, the company is contractually committed to deliver approximately 16 million barrels of crude oil and 759 billion cubic feet of natural gas to third parties from 2022 through 2024. The company believes it can satisfy these contracts through a combination of equity production from the company’s proved developed U.S. reserves and third-party purchases. These commitments are primarily based on contracts with indexed pricing terms.
Outside the United States, the company is contractually committed to deliver a total of 2.9 trillion cubic feet of natural gas to third parties from 2022 through 2024 from operations in Australia and Israel. The Australia sales contracts contain variable pricing formulas that generally reference the prevailing market price for crude oil, natural gas or other petroleum products at the time of delivery. The sales contracts for Israel contain formulas that generally reflect an initial base price subject to price indexation, Brent-linked or other, over the life of the contract. The company believes it can satisfy these contracts from quantities available from production of the company’s proved developed reserves in these countries.
Development Activities
Refer to Table I for details associated with the company’s development expenditures and costs of proved property acquisitions for 2021, 2020 and 2019.
The following table summarizes the company’s net interest in productive and dry development wells completed in each of the past three years, and the status of the company’s development wells drilling at December 31, 2021. A “development well” is a well drilled within the known area of a crude oil or natural gas reservoir to the depth of a stratigraphic horizon known to be productive.
 
 
Wells Drilling1
Net Wells Completed
at 12/31/21202120202019
Gross Net Prod. Dry Prod. DryProd. Dry
United States108 66 319 2 539 682 
Other Americas7 4 54  27 — 36 — 
Africa3 1 4  — 26 — 
Asia38 18 35  94 181 
Australia    — — — — 
Europe  1  — — 
Total Consolidated Companies156 89 413 2 666 926 
Affiliates16 1 8  13 — 43 — 
Total Including Affiliates172 90 421 2 679 969 
1 Gross wells represent the total number of wells in which Chevron has an ownership interest. Net wells represent the sum of Chevron’s ownership interest in gross wells.
 
Exploration Activities
Refer to Table I for detail on the company’s exploration expenditures and costs of unproved property acquisitions for 2021, 2020 and 2019.
The following table summarizes the company’s net interests in productive and dry exploratory wells completed in each of the last three years, and the number of exploratory wells drilling at December 31, 2021. “Exploratory wells” are wells drilled to find and produce crude oil or natural gas in unknown areas and include delineation and appraisal wells, which are wells drilled to find a new reservoir in a field previously found to be productive of crude oil or natural gas in another reservoir or to extend a known reservoir.
Wells Drilling*Net Wells Completed
at 12/31/21202120202019
Gross Net Prod. Dry Prod. Dry Prod. Dry
United States3 2 2 2 10 
Other Americas1    — — 
Africa    — — — — 
Asia1 1   — — — — 
Australia    — — — — 
Europe    — — — — 
Total Consolidated Companies5 3 2 2 10 
Affiliates    — — — — 
Total Including Affiliates5 3 2 2 10 
* Gross wells represent the total number of wells in which Chevron has an ownership interest. Net wells represent the sum of Chevron’s ownership interest in gross wells.
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Review of Ongoing Exploration and Production Activities in Key Areas
Chevron has exploration and production activities in many of the world’s major hydrocarbon basins. Chevron’s 2021 key upstream activities, some of which are also discussed in Management’s Discussion and Analysis of Financial Condition and Results of Operations, beginning on page 38, are presented below. The comments include references to “total production” and “net production,” which are defined under “Production” in Exhibit 99.1.
The discussion that follows references the status of proved reserves recognition for significant long-lead-time projects not on production as well as for projects recently placed on production. Reserves are not discussed for exploration activities or recent discoveries that have not advanced to a project stage, or for mature areas of production that do not have individual projects requiring significant levels of capital or exploratory investment.
United States
Upstream activities in the United States are primarily located in Texas, New Mexico, California, Colorado, and the Gulf of Mexico. Acreage for the United States can be found in the table on page 8. Net daily oil-equivalent production in the United States can be found in the table on page 7.
Chevron is one of the largest producers in the Permian Basin with a production outlook of more than one million barrels of net oil equivalent production per day by 2025. The company’s advantaged portfolio of development areas in west Texas and southeast New Mexico is comprised of stacked formations enabling production from multiple geologic zones from single surface locations. Chevron has implemented a Permian factory development strategy utilizing multi-well pads to drill a series of horizontal wells that are subsequently completed concurrently using hydraulic fracture stimulation. Top tier drilling and completions performance has enabled year-over-year capital expenditure efficiency improvement and cycle time reduction generating higher returns throughout Chevron’s Permian portfolio. Chevron’s Permian operations have also demonstrated continual progress on its lower carbon and water goals, consistently ranking among the best Permian operators for methane emissions intensity, routine flaring, and water handling (utilizing 99 percent brackish or recycled sources). In 2021, Chevron’s net daily unconventional production in the Permian Basin averaged 284,000 barrels of crude oil, 1.1 billion cubic feet of natural gas and 148,000 barrels of NGLs. Conventional production averaged 10,000 barrels of crude oil, 39 million cubic feet of natural gas and 2,000 barrels of NGLs per day.
Chevron holds mature assets in the Eagle Ford Shale in Texas that produced 29,000 barrels of oil-equivalent per day in 2021.
In 2021, Chevron was one of the largest crude oil producers in California with a net daily oil equivalent production of 96,000 barrels. Chevron completed front-end engineering and design (FEED) in second quarter 2021 on a carbon capture project for emissions reduction from the gas turbines in one of our California co-generation facilities. This project leverages two innovative technologies—carbon dioxide concentration and carbon capture—and has the potential to scale across our full fleet of turbines. A final investment decision for this project is expected in third quarter 2022, with anticipated start-up in 2024. Chevron is also progressing the installation of a 20MWh battery at the solar power plant in the Lost Hills field with start-up expected in third quarter 2022.
In Colorado, development in the Denver-Julesburg (DJ) Basin is primarily focused on Chevron’s Mustang and Wells Ranch areas where the company’s comprehensive drilling plans allow for efficient resource development. Chevron’s net daily production in the DJ Basin averaged 56,000 barrels of crude oil, 302 million cubic feet of natural gas and 36,000 barrels of NGLs during 2021.
Chevron also has operations in Colorado’s Piceance Basin as well as acreage positions in Wyoming and Utah.
During 2021, net daily production in the Gulf of Mexico averaged 180,000 barrels of crude oil, 102 million cubic feet of natural gas and 12,000 barrels of NGLs. Chevron is engaged in various operated and nonoperated exploration, development and production activities in the deepwater Gulf of Mexico. Chevron also holds nonoperated interests in several shelf fields.
The deepwater Jack and St. Malo fields are being jointly developed with a host floating production unit located between the two fields. Chevron has a 50 percent interest in the Jack Field and a 51 percent interest in the St. Malo Field. Both fields are company operated. The company has a 40.6 percent interest in the production host facility, which is designed to accommodate production from the Jack/St. Malo development and third-party tiebacks. Additional development opportunities for the Jack and St. Malo fields progressed in 2021. The St. Malo Stage 4 waterflood project includes two new production wells, three injector wells, and topsides water injection equipment at the St. Malo Field. Two oil production wells were placed online, and first injection is expected in 2023. Additional Jack development in 2021 consisted
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of a single well tieback and related subsea infrastructure installation. The Stage 4 multiphase subsea pump project replaced the single-phase subsea pumps in both the Jack and St. Malo fields. Multiphase pump modules were completed and received in 2021 with installation expected to commence in 2022. Proved reserves have been recognized for the multiphase subsea pump project. The Jack and St. Malo fields have an estimated remaining production life of 30 years.
The company has a 15.6 percent nonoperated working interest in the deepwater Mad Dog Field. Project execution continued in 2021 on the Mad Dog 2 Project with installation of the floating production platform in November 2021. First oil is expected in the second half of 2022. Proved reserves have been recognized for the Mad Dog 2 Project.
Chevron has a 60 percent-owned and operated interest in the Big Foot Project, located in the deepwater Walker Ridge area. Development drilling activities are ongoing, with an additional production well coming online in July 2021. The project has an estimated remaining production life of 30 years.
The company has a 58 percent-owned and operated interest in the deepwater Tahiti Field. First production from the Tahiti Upper Sands Project was achieved in April 2021. The Tahiti Field has an estimated remaining production life of more than 20 years.
Chevron holds a 25 percent nonoperated working interest in the Stampede Field, which is located in the Green Canyon area. The field has an estimated remaining production life of 25 years.
Chevron has owned and operated interests of 62.9 to 75.4 percent in the unit areas containing the Anchor Field. Stage 1 of the Anchor development consists of a seven-well subsea development and a semi-submersible floating production unit. Drilling of the first development well began in December 2021. Proved reserves were recognized in 2021 for Anchor, with first production expected in 2024.
Chevron has a 60 percent-owned and operated interest in the Ballymore Field located in the Mississippi Canyon, which is being developed as a subsea tieback to the existing Blind Faith facility. Chevron entered FEED for Ballymore in March 2021, and a final investment decision is expected in second quarter 2022.
The company holds a 40 percent nonoperated working interest in the Whale discovery located in the Perdido area. A final investment decision was made for Whale in July 2021. First production is expected for Whale in 2024 and proved reserves have been recognized for this project.
During 2021, the company participated in four exploration wells in the deepwater Gulf of Mexico. Chevron was formally awarded eight blocks during 2021 as a result of 2020 U.S. Gulf of Mexico lease sales.
Other Americas
“Other Americas” includes Argentina, Brazil, Canada, Colombia, Mexico, Suriname and Venezuela. Acreage for “Other Americas” can be found in the table on page 8. Net daily oil-equivalent production from these countries can be found in the table on page 7.
Argentina Chevron holds a 50 percent nonoperated interest in the Loma Campana and Narambuena concessions in the Vaca Muerta Shale. In 2021, the appraisal program at Narambuena was completed, with the final two wells of the four-well campaign placed on production. With completion of this program, Chevron achieved its farm-in commitment for this block. At Loma Compana, 32 horizontal wells were drilled in 2021, with 39 wells in total put on production. This concession expires in 2048.
Chevron also owns and operates a 100 percent interest in the El Trapial Field with both conventional production and Vaca Muerta Shale potential. The company utilizes waterflood operations to mitigate declines at the operated El Trapial Field and completed the Vaca Muerta appraisal program in 2021, with the final three wells of this program placed on production. The El Trapial concession expires in 2032.
Brazil Chevron holds between 30 and 45 percent of both operated and nonoperated interests in 11 blocks within the Campos and Santos basins. One exploration well began drilling in 2021, and one exploration well commenced drilling in early 2022.
In July 2021, the company sold its 37.5 percent nonoperated interest in the Papa-Terra oil field.
Canada Upstream interests in Canada are concentrated in Alberta and the offshore Atlantic region of Newfoundland and Labrador. The company also has interests in the Northeast British Columbia and the Beaufort Sea region of the Northwest Territories.
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The company holds a 20 percent nonoperated working interest in the Athabasca Oil Sands Project (AOSP) and associated Quest carbon capture and storage project in Alberta. Oil sands are mined from both the Muskeg River and the Jackpine mines, and bitumen is extracted from the oil sands and upgraded into synthetic oil. Carbon dioxide emissions from the upgrader are reduced by carbon capture and storage facilities.
Chevron has a 70 percent-owned and operated interest in most of its Duvernay shale acreage. By early 2022, a total of 227 wells have been tied into production facilities.
Chevron holds a 26.9 percent nonoperated working interest in the Hibernia Field and a 24.1 percent nonoperated working interest in the unitized Hibernia Southern Extension areas offshore Atlantic Canada. The company holds a 29.6 percent nonoperated working interest in the heavy oil Hebron Field, also offshore Atlantic Canada, which has an expected remaining economic life of 30 years.
The company holds a 25 percent nonoperated working interest in blocks EL 1145, EL 1146 and EL 1148 and a 40 percent nonoperated working interest in EL 1149 located in offshore Atlantic Canada.
Colombia Chevron holds a 40 percent-owned and operated working interest in the offshore Colombia-3 and Guajira Offshore-3 Blocks.
Mexico The company owns and operates a 33.3 percent interest in Block 3 in the Perdido area of the Gulf of Mexico. In the Cuenca Salina area in the deepwater Gulf of Mexico, Chevron holds a 37.5 percent-owned and operated interest in Block 22. The company also holds a 40 percent nonoperated interest in Blocks 20, 21 and 23.
Suriname Chevron was the successful bidder in an April 2021 bid round for a 40 percent-owned and operated working interest in Block 5 and signed the production-sharing contract (PSC) in October 2021. Chevron also holds a 33.3 percent nonoperated working interest in deepwater Block 42 where one exploration well is expected to be drilled during 2022.
Venezuela Chevron’s interests in Venezuela are located in western Venezuela and the Orinoco Belt. At December 31, 2021, no proved reserves are recognized for these interests. In 2021, the company conducted activities in Venezuela consistent with the authorization provided pursuant to general licenses issued by the United States government. The company remains committed to its people, assets, and operations in Venezuela.
Chevron holds a 39.2 percent interest in Petroboscan, which operates the Boscan Field in western Venezuela under an agreement expiring in 2026. Chevron has a 30 percent interest in Petropiar, which operates the heavy oil Huyapari Field under an agreement expiring in 2033. Chevron also holds a 25.2 percent interest in Petroindependiente, which operates the LL-652 Field in Lake Maracaibo under a contract expiring in 2026, and a 35.7 percent interest in Petroindependencia, which includes the Carabobo 3 heavy oil project located in three blocks in the Orinoco Belt. The Petroindependencia contract expires in 2035.
Chevron also operates and holds a 60 percent interest in the Loran gas field offshore Venezuela. This is part of a cross- border field that includes the Manatee Field in Trinidad and Tobago. This license expires in 2039.
Africa
In Africa, the company is engaged in upstream activities in Angola, the Republic of Congo, Cameroon, Egypt, Equatorial Guinea, and Nigeria. Acreage for Africa can be found in the table on page 8. Net daily oil-equivalent production from these countries can be found in the table on page 7.
Angola The company operates and holds a 39.2 percent interest in Block 0, a concession adjacent to the Cabinda coastline. The Block 0 partners and National Concessionaire signed an extension for an additional 20 years in December 2021. This extension to 2050 is subject to legislative approvals. The Block 0 Sanha Lean Gas Connection Project (SLGC) reached final investment decision in January 2021. SLGC is a new platform that ties the existing complex to new connecting pipelines for gathering and exporting gas from Blocks 0 and 14 to Angola LNG.
Chevron also operates and holds a 31 percent interest in a PSC for deepwater Block 14 which expires in 2028. During 2021, drilling operations restarted in Block 14 following the coronavirus (COVID-19) pandemic related shut-down.
Chevron has a 36.4 percent interest in Angola LNG Limited, which operates an onshore natural gas liquefaction plant in Soyo, Angola. The plant has the capacity to process 1.1 billion cubic feet of natural gas per day. This is the world’s first LNG plant supplied with associated gas, where the natural gas is a byproduct of crude oil production. Feedstock for the plant originates from multiple fields and operators. During 2021, work continued toward developing non-associated gas in offshore Angola, which is expected to supply the Angola LNG plant.
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Angola-Republic of Congo Joint Development Area Chevron operates and holds a 31.3 percent interest in the Lianzi Unitization Zone, located in an area shared equally by Angola and the Republic of Congo. This interest expires in 2031.
Republic of Congo Chevron has a 31.5 percent nonoperated working interest in the offshore Haute Mer permit area. The permits for Nkossa, Nsoko and Moho-Bilondo expire in 2027, 2034 and 2030, respectively.
Cameroon Chevron owns and operates the YoYo Block in the Douala Basin. Preliminary development plans include a possible joint development between YoYo and the Yolanda Field in Equatorial Guinea.
Egypt In the Mediterranean Sea, Chevron holds a 90 percent-owned and operated interest in North Sidi Barrani (Block 2), North El Dabaa (Block 4) and the Nargis block, as well as a 27 percent nonoperated working interest in both North Marina (Block 6) and North Cleopatra (Block 7). In the Red Sea, the company holds a 45 percent-owned and operated interest in Block 1.
Equatorial Guinea Chevron has a 38 percent-owned and operated interest in the Aseng oil field and the Yolanda natural gas field in Block I and a 45 percent-owned and operated interest in the Alen natural gas and condensate field in Block O. The Alen Gas Project was completed in February 2021, with the first LNG cargo shipped in March 2021.
Chevron signed a production sharing agreement for an 80 percent-owned and operated interest in Block EG-09, offshore Equatorial Guinea, in the Douala Basin located south of the Alen and Aseng oil fields.
The company also holds a 32 percent nonoperated interest in the natural gas and condensate Alba Field, a 28 percent nonoperated interest in the Alba LPG Plant and a 45 percent interest in the Atlantic Methanol Production Company.
Nigeria Chevron operates and holds a 40 percent interest in eight concessions, seven operated and one nonoperated in the onshore and near-offshore regions of the Niger Delta. The company also holds acreage positions in three operated and six nonoperated deepwater blocks, with working interests ranging from 20 to 100 percent.
Chevron is the operator of the Escravos Gas Plant (EGP) with a total processing capacity of 680 million cubic feet per day of natural gas and liquified petroleum gas and condensate export capacity of 58,000 barrels per day. The company is also the operator of the 33,000-barrel-per-day Escravos Gas to Liquids facility. In addition, the company holds a 36.9 percent interest in the West African Gas Pipeline Company Limited affiliate, which supplies Nigerian natural gas to customers in Benin, Togo and Ghana.
Chevron operates and holds a 67.3 percent interest in the Agbami Field, located in deepwater Oil Mining Lease (OML) 127 and OML 128. Additionally, Chevron holds a 30 percent nonoperated working interest in the Usan Field in OML 138. The leases that contain the Usan and Agbami Fields expire in 2023 and 2024, respectively.
Also, in the deepwater area, the Aparo Field in OML 132 and OML 140 and the third-party-owned Bonga SW Field in OML 118 share a common geologic structure and are planned to be developed jointly. Chevron holds a 16.6 percent nonoperated working interest in the unitized area. The development plan involves subsea wells tied back to a floating production, storage and offloading vessel. Work continues to progress toward a final investment decision. At the end of 2021, no proved reserves were recognized for this project.
In deepwater exploration, Chevron operates and holds a 55 percent interest in the deepwater Nsiko discoveries in OML 140. Chevron also holds a 27 percent interest in adjacent licenses OML 139 and OML 154. The company continues to work with the operator to evaluate development options for the multiple discoveries in the Usan area, including the Owowo Field, which straddles OML 139 and OML 154. The development plan for the Owowo field involves a subsea tie-back to the existing Usan floating, production, storage, and offloading vessel.
In April 2021, further to the exercise of a preemptive right by its joint venture partner, the company signed an agreement to divest its 40 percent operated interest in OML 86 and OML 88. This sale is subject to customary closing conditions.
Asia
In Asia, the company is engaged in upstream activities in Bangladesh, China, Cyprus, Indonesia, Israel, Kazakhstan, Kurdistan Region of Iraq, Myanmar, the Partitioned Zone between Saudi Arabia and Kuwait, Russia, and Thailand. Acreage for Asia can be found in the table on page 8. Net daily oil-equivalent production for these countries can be found in the table on page 7.

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Bangladesh Chevron operates and holds a 100 percent interest in Block 12 (Bibiyana Field) and Blocks 13 and 14 (Jalalabad and Moulavi Bazar fields). The rights to produce from Jalalabad expire in 2030, from Moulavi Bazar in 2033 and from Bibiyana in 2034.
China Chevron has nonoperated working interests in several areas in China. The company has a 49 percent nonoperated working interest in the Chuandongbei Project, including the Loujiazhai and Gunziping natural gas fields located onshore in the Sichuan Basin.
The company also has nonoperated working interests of 32.7 percent in Block 16/19 in the Pearl River Mouth Basin and 24.5 percent in the Qinhuangdao (QHD) 32-6 Block in the Bohai Bay. The PSCs for Block 16/19 and QHD 32-6 expire in 2028 and 2024, respectively.
Cyprus The company holds a 35 percent-owned and operated interest in the Aphrodite gas field in Block 12. Chevron operates the field with the Government of Cyprus and has a license that expires in 2044.
Indonesia Chevron has working interests through various PSCs in Indonesia. In offshore eastern Kalimantan, the company operates and holds a 62 percent interest in two PSCs in the Kutei Basin (Rapak and Ganal) and operates and holds a 72 percent interest in the Makassar Strait PSC. The PSCs for offshore eastern Kalimantan expire in December 2027 (Rapak and Makassar Strait) and February 2028 (Ganal). The Chevron-operated Rokan PSC in Sumatra expired in August 2021.
Chevron concluded during 2019 that the Indonesia Deepwater Development held by the Kutei Basin PSCs did not compete in its portfolio and is evaluating strategic alternatives for the participating interest in these PSCs.
Israel Chevron holds a 39.7 percent-owned and operated interest in the Leviathan Field, which operates under a concession that expires in 2044. The company also holds a 25 percent-owned and operated interest in the Tamar gas field, which operates under a concession that expires in 2038. Opportunities to further monetize the existing gas resources are being assessed for both the Tamar and Leviathan fields.
Kazakhstan Chevron has a 50 percent interest in the Tengizchevroil (TCO) affiliate and an 18 percent nonoperated working interest in the Karachaganak Field.
TCO is developing the Tengiz and Korolev crude oil fields in western Kazakhstan under a concession agreement that expires in 2033. All of TCO’s 2021 crude oil production was exported through the Caspian Pipeline Consortium (CPC) pipeline.
In 2021, TCO continued construction on the Future Growth Project and Wellhead Pressure Management Project (FGP/WPMP), with all modules being placed on foundation as of April 2021. The third of four metering stations associated with the project was completed in September 2021, collectively delivering over 100 MBOED of production through existing facilities in the fourth quarter. The project also successfully integrated the utility modules for the 3rd generation plant. At year-end, the project was approximately 89 percent complete. Due to pandemic impacts, it is expected that the WPMP portion will start up in mid-2023, with FGP expected to come online in late-2023 to mid-2024. Proved reserves have been recognized for FGP/WPMP.
The Karachaganak Field is located in northwest Kazakhstan, and operations are conducted under a PSC that expires in 2038. Most of the exported liquids were transported through the CPC pipeline during 2021. Development continued on the Karachaganak Expansion Project Stage 1A during 2021. The initial recognition of proved reserves occurred in 2021 for this project.
Kazakhstan/Russia Chevron has a 15 percent interest in the CPC. Progress continued on the debottlenecking project, which is expected to further increase capacity. During 2021, CPC transported an average of 1.3 million barrels of crude oil per day, composed of 1.1 million barrels per day from Kazakhstan and 0.2 million barrels per day from Russia.
Kurdistan Region of Iraq The company holds a 50 percent nonoperated interest in the Sarta PSC, which expires in 2047, and a 40 percent nonoperated interest in the Qara Dagh PSC. Chevron relinquished operatorship of the Sarta block effective January 2022.
Myanmar Chevron has a 28.3 percent nonoperated working interest in a PSC for the production of natural gas from the Yadana, Badamyar and Sein fields, within Blocks M5 and M6, in the Andaman Sea. The PSC expires in 2028. The company also has a 28.3 percent nonoperated working interest in a pipeline company that transports natural gas to the Myanmar-Thailand border for delivery to power plants in Thailand. In January 2022, Chevron announced its intention to begin the process of a planned and orderly transition that will lead to an exit from the country.
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Partitioned Zone Chevron holds a concession to operate the Kingdom of Saudi Arabia’s 50 percent interest in the hydrocarbon resources in the onshore area of the Partitioned Zone between Saudi Arabia and Kuwait. The concession expires in 2046. Current activities focus on base business optimization and production enhancement opportunities.
Thailand Chevron holds operated interests in the Pattani Basin, located in the Gulf of Thailand, with ownership ranging from 35 percent to 80 percent. Concessions for producing areas within this basin expire between 2022 and 2035. Chevron also has a 16 percent nonoperated working interest in the Arthit Field located in the Malay Basin. Concessions for the producing areas within this basin expire between 2036 and 2040.
Within the Pattani Basin, the company holds ownership ranging from 70 to 80 percent of the Erawan concession, which expires in April 2022. Chevron also has a 35 percent-owned and operated interest in the Ubon Project in Block 12/27.
Chevron holds between 30 to 80 percent operated and nonoperated working interests in the Thailand-Cambodia Overlapping Claims Area that are inactive, pending resolution of border issues between Thailand and Cambodia.
Australia
Chevron is Australia's largest producer of LNG. Acreage can be found in the table on page 8. Net daily oil-equivalent production can be found in the table on page 7.
Upstream activities in Australia are concentrated offshore Western Australia, where the company is the operator of two major LNG projects, Gorgon and Wheatstone, and has a nonoperated working interest in the North West Shelf (NWS) Venture and exploration acreage in the Carnarvon Basin.
Chevron holds a 47.3 percent-owned and operated interest in Gorgon on Barrow Island, which includes the development of the Gorgon and Jansz-Io fields, a three-train 15.6 million-metric-ton-per-year LNG facility, a carbon capture and underground storage facility and a domestic gas plant. Progress on the Gorgon Stage 2 project continued in 2021, with the completion of the pipelay in May 2021 and first production expected in third quarter 2022. The company reached a final investment decision on the Jansz-Io Compression Project in July 2021, and proved reserves have been recognized for this project. Gorgon’s estimated remaining economic life exceeds 40 years.
Chevron holds an 80.2 percent interest in the offshore licenses and a 64.1 percent-owned and operated interest in the LNG facilities associated with Wheatstone. Wheatstone includes the development of the Wheatstone and Iago fields, a two-train, 8.9 million-metric-ton-per-year LNG facility, and a domestic gas plant. The onshore facilities are located at Ashburton North on the coast of Western Australia. Wheatstone’s estimated remaining economic life exceeds 20 years.
Chevron has a 16.7 percent nonoperated working interest in the NWS Venture in Western Australia.
The company continues to evaluate exploration and appraisal activity across the Carnarvon Basin in which it holds more than 6.0 million net acres. Chevron relinquished 0.5 million net acres in 2021 in the Carnarvon and Browse basins.
Chevron owns and operates the Clio, Acme and Acme West fields. The company is collaborating with other Carnarvon Basin participants to assess the possibility of developing Clio and Acme through shared utilization of existing infrastructure.
United Kingdom
Acreage can be found in the table on page 8. Net oil equivalent production for the United Kingdom can be found in the table on page 7.
Chevron holds a 19.4 percent nonoperated working interest in the Clair Field, located west of the Shetland Islands. The Clair Ridge Project is the second development phase of the Clair Field, with a design capacity of 120,000 barrels of crude oil and 100 million cubic feet of natural gas per day. The Clair Field has an estimated remaining production life extending beyond 2050.
Sales of Natural Gas and Natural Gas Liquids
 The company sells natural gas and NGLs from its producing operations under a variety of contractual arrangements. In addition, the company also makes third-party purchases and sales of natural gas and NGLs in connection with its supply and trading activities.
During 2021, U.S. and international sales of natural gas averaged 4.0 billion and 5.2 billion cubic feet per day, respectively, which includes the company’s share of equity affiliates’ sales. Outside the United States, substantially all of the natural gas
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sales from the company’s producing interests are from operations in Angola, Argentina, Australia, Bangladesh, Canada, Equatorial Guinea, Kazakhstan, Indonesia, Israel, Nigeria and Thailand.
U.S. and international sales of NGLs averaged 230,000 and 180,000 barrels per day, respectively, in 2021.
Refer to “Selected Operating Data,” on page 42 in Management’s Discussion and Analysis of Financial Condition and Results of Operations, for further information on the company’s sales volumes of natural gas and natural gas liquids. Refer also to “Delivery Commitments” beginning on page 8 for information related to the company’s delivery commitments for the sale of crude oil and natural gas.
Downstream
Refining Operations
At the end of 2021, the company had a refining network capable of processing 1.8 million barrels of crude oil per day. Operable capacity at December 31, 2021, and daily refinery inputs for 2019 through 2021 for the company and affiliate refineries, are summarized in the table below.
Average crude oil distillation capacity utilization was 82 percent in 2021 and 76 percent in 2020. At the U.S. refineries, crude oil distillation capacity utilization averaged 83 percent in 2021, compared with 73 percent in 2020. Chevron processes both imported and domestic crude oil in its U.S. refining operations. Imported crude oil accounted for about 60 percent and 59 percent of Chevron’s U.S. refinery inputs in 2021 and 2020, respectively.
In the United States, the company continued work on projects aimed at improving refinery flexibility and reliability. At the El Segundo Refinery in California, production of renewable fuels from bio-feedstocks was achieved in third quarter 2021. At the refinery in Salt Lake City, Utah, the alkylation retrofit project reached start-up in April 2021. The Pasadena Refinery enables processing of greater amounts of Permian light crude oil and provides integration with Chevron’s Gulf Coast Pascagoula, Mississippi refinery and Houston Blend Center.
Outside the United States, the company has three large refineries in Singapore, South Korea and Thailand. The Singapore Refining Company (SRC), a 50 percent-owned joint venture, has a total capacity of 290,000 barrels of crude per day and manufactures a wide range of petroleum products, including higher-quality gasoline that meets stricter emission standards. Refinery upgrades have enabled SRC to produce higher-quality gasoline that meets stricter emission standards. The 50 percent-owned, GS Caltex (GSC) operated, Yeosu Refinery in South Korea remains one of the world’s largest refineries with a total crude capacity of 800,000 barrels per day. The company’s 60.6 percent-owned refinery in Map Ta Phut, Thailand, continues to supply high-quality petroleum products through the Caltex brand into regional markets.
Petroleum Refineries: Locations, Capacities and Inputs
Capacities and inputs in thousands of barrels per dayDecember 31, 2021Refinery Inputs
Locations Number Operable Capacity 202120202019
PascagoulaMississippi1 369 333 305 358 
El SegundoCalifornia1 290 233 176 241 
RichmondCalifornia1 257 211 198 236 
Pasadena1
Texas1 110 76 69 58 
Salt Lake CityUtah1 58 50 45 54 
Total Consolidated Companies — United States 5 1,084 903 793 947 
Map Ta PhutThailand1 175 135 143 134 
Total Consolidated Companies — International 1 175 135 143 134 
Affiliates
Various Locations2
2 545 441 441 483 
Total Including Affiliates — International 3 720 576 584 617 
Total Including Affiliates — Worldwide 8 1,804 1,479 1,377 1,564 
1    In May 2019, the company acquired the Pasadena, TX refinery.
2    In March 2020, the company sold its interest in the Pakistan refinery.
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Marketing Operations
The company markets petroleum products under the principal brands of “Chevron,” “Texaco” and “Caltex” throughout many parts of the world. The following table identifies the company’s and its affiliates’ refined products sales volumes, excluding intercompany sales, for the three years ended December 31, 2021.
Refined Products Sales Volumes
Thousands of barrels per day202120202019
United States
Gasoline
655 581667
Jet Fuel
173 139256
Diesel/Gas Oil
179 167191
Residual Fuel Oil
39 3342
Other Petroleum Products1
93 8394
Total United States1,139 1,003 1,250 
International2
Gasoline
321 264289
Jet Fuel
140 143238
Diesel/Gas Oil
471 438427
Residual Fuel Oil
177 184167
Other Petroleum Products1
206 192206
Total International 1,315 1,221 1,327 
Total Worldwide2
2,454 2,224 2,577 
1 Principally naphtha, lubricants, asphalt, and coke.
2 Includes share of affiliates’ sales:
357 348379
 In the United States, the company markets under the Chevron and Texaco brands. At year-end 2021, the company supplied directly or through retailers and marketers approximately 8,200 Chevron- and Texaco-branded service stations, primarily in the southern and western states. Approximately 310 of these outlets are company-owned or -leased stations.
Outside the United States, Chevron supplied directly or through retailers and marketers approximately 5,700 branded service stations, including affiliates. The company markets in Latin America using the Texaco brand. In the Asia-Pacific region and the Middle East, the company uses the Caltex brand. In South Korea, the company operates through its 50 percent-owned affiliate, GSC. In Australia, Chevron markets primarily under the Puma brand via a network of terminals and service stations. Starting in 2022, the company will begin a rebranding project to transition to the Caltex brand in Australia.
Chevron markets commercial aviation fuel to 69 airports worldwide. The company also markets an extensive line of lubricant and coolant products under the product names Havoline, Delo, Ursa, Meropa, Rando, Clarity and Taro in the United States and worldwide under the three brands: Chevron, Texaco and Caltex.
Chemicals Operations
Chevron Oronite Company develops, manufactures and markets performance additives for lubricating oils and fuels and conducts research and development for additive component and blended packages. At the end of 2021, the company manufactured, blended or conducted research at 11 locations around the world. Commercial production from the lubricant additive blending and shipping plant in Ningbo, China was achieved in second quarter 2021.
Chevron owns a 50 percent interest in Chevron Phillips Chemical Company LLC (CPChem). CPChem produces olefins, polyolefins and alpha olefins and is a supplier of aromatics and polyethylene pipe, in addition to participating in the specialty chemical and specialty plastics markets. At the end of 2021, CPChem owned or had joint-venture interests in 28 manufacturing facilities and two research and development centers around the world.
In addition to continued efforts to debottleneck existing ethylene and polyethylene units, CPChem advanced projects at existing facilities to expand its normal alpha olefins business. In May 2021, CPChem announced plans for a second world-scale unit at Old Ocean, Texas to produce on-purpose 1-hexene with expected capacity of 266,000 metric tons per year. In December 2021, CPChem made final investment decision on a new C3 splitter unit at its Cedar Bayou facility in Baytown, Texas that is expected to have the capacity to produce 1 billion pounds of propylene annually. Target start-up for both units is 2023.

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CPChem holds a 51 percent interest in the U.S. Gulf Coast II Petrochemical Project (USGC II) and a 30 percent interest in the Ras Laffan Petrochemical Project (RLPP) in Qatar. CPChem continued engineering on RLPP as well as continued work toward FID on USGC II.
Chevron also maintains a role in the petrochemical business through the operations of GSC, the company’s 50 percent-owned affiliate. GSC manufactures aromatics, including benzene, toluene and xylene. These base chemicals are used to produce a range of products, including adhesives, plastics and textile fibers. GSC also produces polypropylene, which is used to make automotive and home appliance parts, food packaging, laboratory equipment and textiles.
First production from the olefins mixed-feed cracker and associated polyethylene unit within the existing refining and petrochemical facilities in Yeosu, South Korea was achieved in June 2021, ahead of schedule and under budget.    
Renewable Fuels
The company continued to advance lower carbon actions in the downstream business, particularly through development of renewable fuels, which include renewable natural gas (RNG), renewable diesel, sustainable aviation fuel, and renewable base oils and lubricants. The company has two partnerships to produce and market dairy biomethane, with CalBioGas and Brightmark RNG Holdings. In fourth quarter 2021, Brightmark RNG Holdings delivered first RNG. Separately, all CalBioGas farms are now online. In June 2021, the company announced its first branded compressed natural gas (CNG) site as part of its plan to have more than 30 CNG sites in California supplied with RNG by 2025. In October 2021, the company closed its acquisition of an equity interest in American Natural Gas LLC (now Beyond6, LLC) and its network of 60 CNG retail sites, in order to meet customers’ needs beyond California.
Progress has continued at the company’s El Segundo Refinery in California to produce renewable diesel and sustainable aviation fuel through the co-processing of bio-feedstock. In third quarter 2021, the refinery began co-processing about 2,000 barrels per day of bio-feedstock, producing renewable diesel at a diesel hydrotreating unit as well as a batch of sustainable aviation fuel at a fluid catalytic cracking unit. In 2022, the company expects to convert the same diesel hydrotreater at the El Segundo refinery to 100 percent renewable capability, increasing capacity to 10,000 barrels per day of renewable diesel.
The company continues development of renewable base oil through our patented technology and majority ownership in Novvi and has made progress integrating this renewable base oil into Chevron’s lubricant product lines. Chevron developed Havoline Pro-RS, with lifecycle emissions that are 35 percent lower than those of conventional motor oil of equal viscosity. In November 2021, the company made this renewable based lubricant available to professional installers in the United States and Canada, and it is expected to be available to U.S. consumers in early 2022.
Transportation
Pipelines Chevron owns and operates a network of crude oil, natural gas and product pipelines and other infrastructure assets in the United States. In addition, Chevron operates pipelines for its 50 percent-owned CPChem affiliate. The company also has direct and indirect interests in other U.S. and international pipelines. Chevron acquired all of the outstanding common units of Noble Midstream Partners LP not already owned by Chevron or any of its affiliates in May 2021.
Refer to pages 13 and 14 in the Upstream section for information on the West African Gas Pipeline and the Caspian Pipeline Consortium.
Shipping The company’s marine fleet includes both U.S. and foreign flagged vessels. The operated fleet consists of conventional crude tankers, product carriers and LNG carriers. These vessels transport crude oil, LNG, refined products and feedstock in support of the company’s global upstream and downstream businesses. In December 2021, Chevron joined the Sea Cargo Charter, a benchmark initiative for responsible shipping activities, transparent greenhouse gas reporting, and improved decision making in line with the United Nations’ decarbonization targets.
Other Businesses
Chevron Technical Center The company’s technical center provides expertise to drive the application of technology, initiatives to transform Chevron’s digital future, and innovative breakthrough technologies to support the future of energy. The organization conducts research, develops and qualifies technology, and provides technical services and competency development. The disciplines cover earth sciences, reservoir and production engineering, drilling and completions,
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facilities engineering, manufacturing, process technology, catalysis, technical computing and health, environment and safety.
Chevron’s information technology organization integrates computing, telecommunications, data management, cybersecurity and network technology to provide a digital infrastructure to enable Chevron’s global operations and business processes.
Chevron Technology Ventures (CTV) leverages innovative companies and technologies to strengthen Chevron’s core operations and identifies new opportunities with the potential to enhance the way Chevron produces and delivers affordable, reliable, and ever-cleaner energy. CTV has more than two decades of venture investing, with eight funds that have supported more than 100 startups and worked with more than 200 co-investors. In addition to the company’s own managed funds, Chevron also is a limited partner in the following funds: the Oil and Gas Climate Initiative (OGCI) Climate Investments fund, which targets the decarbonization of oil and gas, industry and commercial transportation; the Emerald Ventures fund, which targets energy, water, industrial IT and advanced materials; and the HX Venture fund, which targets Houston, Texas high-growth start-up companies.
Chevron continued its participation as a member of OGCI, a global collaboration focused on the industry’s efforts to take actions to accelerate and participate in a lower carbon future. In 2021, the Climate Investments fund made additional investments and deployed or piloted portfolio technologies with member companies, helping enable methane and CO2 emissions reductions, as well as advancing carbon capture utilization and storage (CCUS) technologies.
Some of the investments the company makes in the areas described above are in new or unproven technologies and business processes; therefore, the ultimate technical or commercial successes of these investments are not certain. Refer to Note 27 Other Financial Information for quantification of the company’s research and development expenses.
Chevron New Energies The new energies organization was formed in 2021 and is designed to advance the company’s strategy by bringing together dedicated resources focused on growing new lower carbon businesses that have the potential to scale. Its initial focus will include commercialization opportunities in hydrogen, CCUS, and carbon offsets. These businesses are expected to support the company’s efforts to reduce its greenhouse gas emissions and are also expected to become high-growth opportunities with the potential to generate accretive returns.
Environmental Protection The company designs, operates and maintains its facilities to avoid potential spills or leaks and to minimize the impact of those that may occur. Chevron requires its facilities and operations to have operating standards and processes and emergency response plans that address significant risks identified through site-specific risk and impact assessments. Chevron also requires that sufficient resources be available to execute these plans. In the unlikely event that a major spill or leak occurs, Chevron also maintains a Worldwide Emergency Response Team comprised of employees who are trained in various aspects of emergency response, including post-incident remediation.
To complement the company’s capabilities, Chevron maintains active membership in international oil spill response cooperatives, including the Marine Spill Response Corporation, which operates in U.S. territorial waters, and Oil Spill Response, Ltd., which operates globally. The company is a founding member of the Marine Well Containment Company, whose primary mission is to expediently deploy containment equipment and systems to capture and contain crude oil in the unlikely event of a future loss of control of a deepwater well in the Gulf of Mexico. In addition, the company is a member of the Subsea Well Response Project, which has the objective to further develop the industry’s capability to contain and shut in subsea well control incidents in different regions of the world.
The company is committed to lowering the carbon intensity of its traditional oil and gas operations, in addition to complying with the greenhouse gas-related laws and regulations to which it is subject. Refer to Item 1A. Risk Factors on pages 20 through 25 for further discussion of greenhouse gas regulation and climate change and the associated risks to Chevron’s business.
Refer to Management’s Discussion and Analysis of Financial Condition and Results of Operations on page 49 for additional information on environmental matters and their impact on Chevron, and on the company’s 2021 environmental expenditures. Refer to page 49 and Note 24 Other Contingencies and Commitments for a discussion of environmental remediation provisions and year-end reserves.

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Item 1A. Risk Factors
As a global energy company, Chevron is subject to a variety of risks that could materially impact the company’s results of operations and financial condition.
BUSINESS AND OPERATIONAL RISK FACTORS
Impacts of the continuation or further resurgences of the COVID-19 pandemic may have an adverse and potentially material adverse effect on Chevron’s financial and operating results The economic, business, and oil and gas industry impacts from the COVID-19 pandemic and the disruption to capital markets have been and continue to be far reaching. While the oil and gas industry witnessed a substantial recovery of commodity prices and demand for products during 2021, 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 further resurgences of the COVID-19 virus and its variants, 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 company’s suppliers continue to be impacted by the COVID-19 pandemic and access to materials, supplies, and contract labor has been strained. This strain on the financial health of the company’s suppliers could put 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 and its variants 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.
In addition, the continuation or further resurgences of the pandemic could precipitate or aggravate the other risk factors identified in this Form 10-K, which in turn could 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.
Chevron is exposed to the effects of changing commodity prices Chevron is primarily in a commodities business that has a history of price volatility. The single largest variable that affects the company’s results of operations is the price of crude oil, which can be influenced by general economic conditions, industry production and inventory levels, technology advancements, production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries or other producers, weather-related damage and disruptions due to other natural or human causes beyond our control (including without limitation due to the COVID-19 pandemic), competing fuel prices, geopolitical risks, the pace of energy transition, and governmental regulations and policies regarding the development of oil and gas reserves. Chevron evaluates the risk of changing commodity prices as a core part of its business planning process. An investment in the company carries significant exposure to fluctuations in global crude oil prices.
Extended periods of low prices for crude oil can have a material adverse impact on the company’s results of operations, financial condition and liquidity. Among other things, the company’s upstream earnings, cash flows, and capital and exploratory expenditure programs could be negatively affected, as could its production and proved reserves. Upstream assets may also become impaired. Downstream earnings could be negatively affected because they depend upon the supply and demand for refined products and the associated margins on refined product sales. A significant or sustained decline in liquidity could adversely affect the company’s credit ratings, potentially increase financing costs and reduce access to capital markets. The company may be unable to realize anticipated cost savings, expenditure reductions and asset sales that are intended to compensate for such downturns, and such downturns may also slow the pace and scale at which we are able to invest in new business lines such as the lower carbon businesses associated with our Chevron New Energies
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organization. In some cases, liabilities associated with divested assets may return to the company when an acquirer of those assets subsequently declares bankruptcy. In addition, extended periods of low commodity prices can have a material adverse impact on the results of operations, financial condition and liquidity of the company’s suppliers, vendors, partners and equity affiliates upon which the company’s own results of operations and financial condition depends.
The scope of Chevron’s business will decline if the company does not successfully develop resources The company is in an extractive business; therefore, if it is not successful in replacing the crude oil and natural gas it produces with good prospects for future organic opportunities or through acquisitions, the company’s business will decline. Creating and maintaining an inventory of projects depends on many factors, including obtaining and renewing rights to explore, develop and produce hydrocarbons; drilling success; reservoir optimization; ability to bring long-lead-time, capital-intensive projects to completion on budget and on schedule; and efficient and profitable operation of mature properties.
The company’s operations could be disrupted by natural or human causes beyond its control Chevron operates in both urban areas and remote and sometimes inhospitable regions. The company’s operations are therefore subject to disruption from natural or human causes beyond its control, including risks from hurricanes, severe storms, floods, heat waves, other forms of severe weather, wildfires, ambient temperature increases, sea level rise, war, accidents, civil unrest, political events, fires, earthquakes, system failures, cyber threats, terrorist acts and epidemic or pandemic diseases such as the COVID-19 pandemic, some of which may be impacted by climate change and any of which could result in suspension of operations or harm to people or the natural environment.
Chevron’s risk management systems are designed to assess potential physical and other risks to its operations and assets and to plan for their resiliency. While capital investment reviews and decisions incorporate potential ranges of physical risks such as storm severity and frequency, sea level rise, air and water temperature, precipitation, fresh water access, wind speed, and earthquake severity, among other factors, it is difficult to predict with certainty the timing, frequency or severity of such events, any of which could have a material adverse effect on the company's results of operations or financial condition.
Cyberattacks targeting Chevron’s process control networks or other digital infrastructure could have a material adverse impact on the company’s business and results of operations There are numerous and evolving risks to Chevron’s cybersecurity and privacy from cyber threat actors, including criminal hackers, state-sponsored intrusions, industrial espionage and employee malfeasance. These cyber threat actors, whether internal or external to Chevron, are becoming more sophisticated and coordinated in their attempts to access the company’s information technology (IT) systems and data, including the IT systems of cloud providers and other third parties with whom the company conducts business through, without limitation, malicious software; data privacy breaches by employees, insiders or others with authorized access; cyber or phishing-attacks; ransomware; attempts to gain unauthorized access to our data and systems; and other electronic security breaches. Although Chevron devotes significant resources to prevent unwanted intrusions and to protect its systems and data, whether such data is housed internally or by external third parties, the company has experienced and will continue to experience cyber incidents of varying degrees in the conduct of its business. Cyber threat actors could compromise the company’s process control networks or other critical systems and infrastructure, resulting in disruptions to its business operations, injury to people, harm to the environment or its assets, disruptions in access to its financial reporting systems, or loss, misuse or corruption of its critical data and proprietary information, including without limitation its intellectual property and business information and that of its employees, customers, partners and other third parties. Any of the foregoing can be exacerbated by a delay or failure to detect a cyber incident or the full extent of such incident. Further, the company has exposure to cyber incidents and the negative impacts of such incidents related to its critical data and proprietary information housed on third-party IT systems, including the cloud. Additionally, authorized third-party IT systems or software can be compromised and used to gain access or introduce malware to Chevron's IT systems that can materially impact the company’s business. Regardless of the precise method or form, cyber events could result in significant financial losses, legal or regulatory violations, reputational harm, and legal liability and could ultimately have a material adverse effect on the company’s business and results of operations.
The company’s operations have inherent risks and hazards that require significant and continuous oversight Chevron’s results depend on its ability to identify and mitigate the risks and hazards inherent to operating in the crude oil and natural gas industry. The company seeks to minimize these operational risks by carefully designing and building its facilities and conducting its operations in a safe and reliable manner. However, failure to manage these risks effectively could impair our ability to operate and result in unexpected incidents, including releases, explosions or mechanical failures resulting in personal injury, loss of life, environmental damage, loss of revenues, legal liability and/or disruption to operations. Chevron has implemented and maintains a system of corporate policies, processes and systems, behaviors and compliance
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mechanisms to manage safety, health, environmental, reliability and efficiency risks; to verify compliance with applicable laws and policies; and to respond to and learn from unexpected incidents. In certain situations where Chevron is not the operator, the company may have limited influence and control over third parties, which may limit its ability to manage and control such risks.
The company does not insure against all potential losses, which could result in significant financial exposure The company does not have commercial insurance or third-party indemnities to fully cover all operational risks or potential liability in the event of a significant incident or series of incidents causing catastrophic loss. As a result, the company is, to a substantial extent, self-insured for such events. The company relies on existing liquidity, financial resources and borrowing capacity to meet short-term obligations that would arise from such an event or series of events. The occurrence of a significant incident, series of events, or unforeseen liability for which the company is self-insured, not fully insured or for which insurance recovery is significantly delayed could have a material adverse effect on the company’s results of operations or financial condition.
LEGAL, REGULATORY AND ESG-RELATED RISK FACTORS
Chevron’s business subjects the company to liability risks from litigation or government action The company produces, transports, refines and markets potentially hazardous materials, and it purchases, handles and disposes of other potentially hazardous materials in the course of its business. Chevron's operations also produce byproducts, which may be considered pollutants. Often these operations are conducted through joint ventures over which the company may have limited influence and control. Any of these activities could result in liability or significant delays in operations arising from private litigation or government action. For example, liability or delays could result from an accidental, unlawful discharge or from new conclusions about the effects of the company’s operations on human health or the environment. In addition, to the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to the company’s causation of or contribution to the asserted damage, or to other mitigating factors.
For information concerning some of the litigation in which the company is involved, see Note 16 Litigation.
Political instability and significant changes in the legal and regulatory environment could harm Chevron’s business The company’s operations, particularly exploration and production, can be affected by changing political, regulatory and economic environments in the various countries in which it operates. As has occurred in the past, actions could be taken by governments to increase public ownership of the company’s partially or wholly owned businesses, to force contract renegotiations, or to impose additional taxes or royalties. In certain locations, governments have proposed or imposed restrictions on the company’s operations, trade, currency exchange controls, burdensome taxes, and public disclosure requirements that might harm the company’s competitiveness or relations with other governments or third parties. In other countries, political conditions have existed that may threaten the safety of employees and the company’s continued presence in those countries, and internal unrest, acts of violence or strained relations between a government and the company or other governments may adversely affect the company’s operations. Those developments have, at times, significantly affected the company’s operations and results and are carefully considered by management when evaluating the level of current and future activity in such countries. Further, Chevron is required to comply with sanctions and other trade laws and regulations of the United States and other jurisdictions where we operate which, depending upon their scope, could adversely impact the company’s operations and financial results in certain countries. In addition, litigation or changes in national, state or local environmental regulations or laws, including those designed to stop or impede the development or production of oil and gas, such as those related to the use of hydraulic fracturing or bans on drilling, or any law or regulation that impacts the demand for our products, could adversely affect the company’s current or anticipated future operations and profitability.
Legislative or regulatory changes in tax laws may expose Chevron to additional tax liabilities Changes in tax laws and regulations around the world are regularly enacted due to political or economic factors beyond the company’s control. Chevron’s taxes in the jurisdictions where the company conducts business activities have been and may be adversely affected by changes in tax laws or regulations. Furthermore, Chevron’s tax returns are subject to audit by taxing authorities around the world. There is no assurance that taxing authorities or courts will agree with the positions that Chevron has reflected on the company’s tax returns, in which case interest and penalties could be imposed that may have a material adverse effect on the company’s results of operations or financial condition.
For information concerning the company’s tax liabilities, see Note 17 Taxes and Note 24 Other Contingencies and Commitments.

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Legislation, regulation, and other government actions and shifting customer preferences and other private efforts related to greenhouse gas (GHG) emissions and climate change could continue to increase Chevron’s operational costs and reduce demand for Chevron’s hydrocarbon and other products, resulting in a material adverse effect on the company’s results of operations and financial condition Chevron has experienced and may be further challenged by increases in the impacts of international and domestic legislation, regulation, or other government actions relating to GHG emissions (e.g., carbon dioxide and methane) and climate change. International agreements and national, regional, and state legislation and regulatory measures that aim to directly or indirectly limit or reduce GHG emissions are in various stages of implementation. The company is currently subject to implemented programs in certain jurisdictions such as the U.S. Renewable Fuel Standard program, the European Union Emissions Trading System, and the California cap-and-trade program and low carbon fuel standard obligations. Further, the Paris Agreement went into effect in November 2016, and a number of countries in which we operate may adopt additional policies to meet their Paris Agreement goals. Globally, multiple jurisdictions are considering adopting or are in the process of implementing laws or regulations to directly regulate GHG emissions through similar or other mechanisms, such as a carbon tax, a cap-and-trade program, or performance standards, or to indirectly advance reduction of GHG emissions through restrictive permitting, trade tariffs, minimum renewable usage requirements, increased GHG reporting and climate-related disclosure requirements, or tax advantages or other incentives to promote the use of alternative energy, fuel sources or lower-carbon technologies. GHG emissions that may be directly regulated through such efforts include, among others, those associated with the company’s exploration and production of hydrocarbons; the upgrading of production from oil sands into synthetic oil; power generation; the conversion of crude oil and natural gas into refined hydrocarbon products; the processing, liquefaction, and regasification of natural gas; the transportation of crude oil, natural gas, and related products; and customers’ use of the company’s hydrocarbon products. Indirect regulation of GHG emissions could include, among other things, bans or restrictions on technologies or products that use the company’s hydrocarbon products. Many of these actions, as well as customers’ preferences and use of the company’s products or substitute products, and actions taken by the company’s competitors in response to legislation and regulations, are beyond the company’s control. 
Similar to any significant changes in the regulatory environment, GHG emissions and climate change-related legislation, regulation, or other government actions may curtail profitability in the oil and gas sector, or render the extraction of the company’s hydrocarbon resources economically infeasible. In particular, GHG emissions-related legislation, regulations, and other government actions and shifting customer preferences and other private efforts aimed at reducing GHG emissions may result in increased and substantial capital, compliance, operating, and maintenance costs and could, among other things, reduce demand for hydrocarbons and the company’s hydrocarbon-based products; increase demand for lower carbon products and alternative energy sources; make the company’s products more expensive; adversely affect the economic feasibility of the company’s resources; impact or limit our business plans; and adversely affect the company’s sales volumes, revenues, margins and reputation. The ultimate effect of international agreements; national, regional, and state legislation and regulation; and government and private actions related to GHG emissions and climate change on the company’s financial performance, and the timing of these effects, will depend on a number of factors. Such factors include, among others, the sectors covered, the GHG emissions reductions required, the extent to which Chevron would be entitled to receive emission allowance allocations or would need to purchase compliance instruments on the open market or through auctions, the price and availability of emission allowances and credits and the extent to which the company is able to recover the costs incurred through the pricing of the company’s products in the competitive marketplace. Further, the ultimate impact of GHG emissions and climate change-related agreements, legislation, regulation, and government actions on the company’s financial performance is highly uncertain because the company is unable to predict with certainty, for a multitude of individual jurisdictions, the outcome of political decision-making processes, including the actual laws and regulations enacted, the variables and tradeoffs that inevitably occur in connection with such processes, and market conditions.
Increasing attention to environmental, social, and governance (ESG) matters may impact our business Increasing attention to ESG matters, including those related to climate change and sustainability, increasing societal, investor and legislative pressure on companies to address ESG matters, and potential customer use of substitutes to Chevron’s products may result in increased costs, reduced demand for our products, reduced profits, increased investigations and litigation or threats thereof, negative impacts on our stock price and access to capital markets, and damage to our reputation. Increasing attention to climate change, for example, may result in demand shifts for our hydrocarbon products and additional governmental investigations and private litigation, or threats thereof, against the company. For instance, we have received investigative requests and demands from the U.S. Congress for information relating to climate change, methane leak
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detection and repair, and other topics, and further requests and/or demands are possible. At this time, Chevron cannot predict the ultimate impact any Congressional or other investigations may have on the company.
In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters, including climate change and climate-related risks. Such ratings are used by some investors to inform their investment and voting decisions. Also, some stakeholders, including but not limited to sovereign wealth, pension, and endowment funds, have been divesting and promoting divestment of or screening out of fossil fuel equities and urging lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Unfavorable ESG ratings and investment community divestment initiatives, among other actions, may lead to negative investor sentiment toward Chevron and to the diversion of investment to other industries, which could have a negative impact on our stock price and our access to and costs of capital. Additionally, evolving expectations on various ESG matters, including biodiversity, waste and water, may increase costs, require changes in how we operate and lead to negative stakeholder sentiment.
Our aspirations, targets and disclosures related to ESG matters expose us to numerous risks, including risks to our reputation and stock price In October 2021, Chevron announced an aspiration to achieve net zero Scope 1 and 2 emissions in Upstream by 2050. The company also has set nearer-term GHG emission-related targets for zero routine flaring, upstream carbon intensity, portfolio carbon intensity, and refining carbon intensity. These aspirations, targets or objectives reflect our current plans and aspirations and are not guarantees that we will be able to achieve them. Our efforts to accomplish and accurately report on these goals and objectives present numerous operational, regulatory, reputational, financial, legal, and other risks, any of which could have a material negative impact, including on our reputation and stock price.
Our ability to achieve any aspiration, target or objective, including with respect to climate-related initiatives, our new lower carbon strategy outlined in the Management’s Discussion and Analysis of Financial Condition and Results of Operations, pages 32 through 34, and any lower carbon new energy businesses, is subject to numerous risks, many of which are outside of our control. Examples of such risks include: (1) the continuing progress of commercially viable technologies and low- or non-carbon-based energy sources; (2) the granting of necessary permits by governing authorities; (3) the availability of cost-effective, verifiable carbon credits; (4) the availability of suppliers that can meet our sustainability and other standards; (5) evolving regulatory requirements affecting ESG standards or disclosures; (6) evolving standards for tracking and reporting on emissions and emission reductions and removals; (7) customers’ preferences and use of the company’s products or substitute products; and (8) actions taken by the company’s competitors in response to legislation and regulations.
The standards for tracking and reporting on ESG matters are relatively new, have not been harmonized and continue to evolve. Our selection of disclosure frameworks that seek to align with various voluntary reporting standards may change from time to time and may result in a lack of comparative data from period to period. In addition, our processes and controls may not always align with evolving voluntary standards for identifying, measuring, and reporting ESG metrics, our interpretation of reporting standards may differ from those of others, and such standards may change over time, any of which could result in significant revisions to our goals or reported progress in achieving such goals.
Achievement of or efforts to achieve aspirations and targets such as the foregoing and future internal climate-related initiatives may increase costs, require purchase of carbon credits, or limit or impact the company’s business plans and financial results, potentially resulting in the reduction to the economic end-of-life of certain assets, an impairment of the associated net book value, among other material adverse impacts. Our failure or perceived failure to pursue or fulfill such aspirations and targets or to satisfy various reporting standards within the timelines we announce, or at all, could have a negative impact on investor sentiment, ratings outcomes for evaluating the company’s approach to ESG matters, stock price, and cost of capital and expose us to government enforcement actions and private litigation, among other material adverse impacts.
GENERAL RISK FACTORS
Changes in management’s estimates and assumptions may have a material impact on the company’s consolidated financial statements and financial or operational performance in any given period In preparing the company’s periodic reports under the Securities Exchange Act of 1934, including its financial statements, Chevron’s management is required under applicable rules and regulations to make estimates and assumptions as of a specified date. These estimates and assumptions are based on management’s best estimates and experience as of that date and are subject to substantial risk and uncertainty. Materially different results may occur as circumstances change and additional information becomes known.
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Areas requiring significant estimates and assumptions by management include impairments to property, plant and equipment and investments in affiliates; estimates of crude oil and natural gas recoverable reserves; accruals for estimated liabilities, including litigation reserves; and measurement of benefit obligations for pension and other postretirement benefit plans. Changes in estimates or assumptions or the information underlying the assumptions, such as changes in the company’s business plans, general market conditions, the pace of energy transition, or changes in the company’s outlook on commodity prices, could affect reported amounts of assets, liabilities or expenses.
Item 1B. Unresolved Staff Comments
None.
Item 2. Properties
The location and character of the company’s crude oil and natural gas properties and its refining, marketing, transportation, and chemicals facilities are described beginning on page 3 under Item 1. Business. Information required by Subpart 1200 of Regulation S-K (“Disclosure by Registrants Engaged in Oil and Gas Producing Activities”) is also contained in Item 1 and in Tables I through VII on pages 97 through 109 and Note 18 Properties, Plant and Equipment.
Item 3. Legal Proceedings
The following is a description of legal proceedings that involve governmental authorities as a party and the company reasonably believes would result in $1.0 million or more of monetary sanctions, exclusive of interest and costs, 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.
As previously disclosed, the refinery in Pasadena, Texas acquired by Chevron on May 1, 2019 (Pasadena Refining System, Inc. and PRSI Trading LLC) has multiple outstanding Notices of Violation (NOVs) that were issued by the Texas Commission on Environmental Quality related to air emissions at the refinery. The Pasadena refinery is currently negotiating a resolution of the NOVs with the Texas Attorney General. Resolution of these alleged violations is expected to result in the payment of a civil penalty of $1.0 million or more.
As previously disclosed, the California Department of Conservation, California 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 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 seeks a civil penalty of approximately $2.7 million. Chevron has filed an appeal of this order. Chevron is currently in discussions with CalGEM to explore a global settlement to resolve the order and all past and present seeps in the Cymric Field, which would increase the amount of penalty paid.
As previously disclosed, the United States Department of Justice and the United States Environmental Protection Agency notified Noble Energy, Inc., Noble Midstream Partners LP and Noble Midstream Services, LLC of potential penalties for alleged Clean Water Act violations at two facilities in Weld County, Colorado relating to a 2014 flood event and requirements for a Spill Prevention and Countermeasures Plan and Facility Response Plan. The parties have negotiated a resolution of these issues with the agencies, which was approved by the U.S. District Court, District of Colorado on September 28, 2021. Resolution of these alleged violations resulted in the payment of a civil penalty of $1.0 million on October 26, 2021.
Please see information related to other legal proceedings in Note 16 Litigation.
Item 4. Mine Safety Disclosures
Not applicable.
Information about our Executive Officers
Information relating to the company’s executive officers is included under “Information about our Executive Officers” in Part III, Item 10, “Directors, Executive Officers and Corporate Governance” on page 28, and is incorporated herein by reference.

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PART II
Item 5. Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
The company’s common stock is listed on the New York Stock Exchange (trading symbol: CVX). As of February 10, 2022, stockholders of record numbered approximately 109,000. There are no restrictions on the company’s ability to pay dividends. The information on Chevron’s dividends are contained in the Quarterly Results tabulations on page 54.
Chevron Corporation Issuer Purchases of Equity Securities for Quarter Ended December 31, 2021
 
Total NumberAverageTotal Number of SharesApproximate Dollar Values of Shares that
of SharesPrice PaidPurchased as Part of PubliclyMay Yet be Purchased Under the Program
Period
Purchased 1,2
per Share Announced Program
(Billions of dollars) 2
October 1 – October 31, 20211,998,279$109.201,997,367$18.7
November 1 – November 30, 20212,759,499$114.352,757,758$18.4
December 1 – December 31, 20211,861,236$116.381,860,752$18.2
Total October 1 – December 31, 20216,619,014$113.366,615,877
1Includes common shares repurchased from participants in the company's deferred compensation plans for personal income tax withholdings.
2Refer to “Liquidity and Capital Resources” on page 44 for additional detail regarding the company's authorized stock repurchase program.
Item 6. Reserved
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The index to Management’s Discussion and Analysis of Financial Condition and Results of Operations is presented on page 31.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
The company’s discussion of interest rate, foreign currency and commodity price market risk is contained in Management’s Discussion and Analysis of Financial Condition and Results of Operations — “Financial and Derivative Instrument Market Risk,” beginning on page 47 and in Note 10 Financial and Derivative Instruments.
Item 8. Financial Statements and Supplementary Data
The index to Financial Statements and Supplementary Data is presented on page 31.
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None.
Item 9A. 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 the Chief Financial Officer, the effectiveness of the company’s disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934 (Exchange Act)) as of the end of the period covered by this report. Based on this evaluation, management concluded that the company’s disclosure controls and procedures were effective as of December 31, 2021.
(b) Management’s Report on Internal Control Over Financial Reporting The company’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in the Exchange Act Rules 13a-15(f) and 15d-15(f). The company’s management, including the Chief Executive Officer and Chief Financial Officer, conducted an evaluation of the effectiveness of the company’s internal control over financial reporting based on the Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on the results of this evaluation, the company’s management concluded that internal control over financial reporting was effective as of December 31, 2021.
The effectiveness of the company’s internal control over financial reporting as of December 31, 2021, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in its report included herein.
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(c) Changes in Internal Control Over Financial Reporting During the quarter ended December 31, 2021, 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.
Item 9B. Other Information
Rule 10b5-1 Plan Elections
Michael K. Wirth, Chairman of the Board, entered into a pre-arranged stock trading plan in November 2021. Mr. Wirth’s plan provides for the potential exercise of vested stock options and the associated sale of up to 93,000 shares of Chevron common stock between February 2022 and March 2023.
Pierre R. Breber, Vice President and Chief Financial Officer, entered into a pre-arranged stock trading plan in November 2021. Mr. Breber’s plan provides for the potential exercise of vested stock options and the associated sale of up to 18,500 shares of Chevron common stock between February 2022 and January 2023.
Rhonda J. Morris, Vice President and Chief Human Resources Officer, and her spouse each entered into pre-arranged stock trading plans in November 2021. The plans for Ms. Morris and her spouse provide for the potential exercise of vested stock options and the associated sale of up to 17,300 and 11,300 shares of Chevron common stock, respectively, between February 2022 and January 2023.
Colin E. Parfitt, Vice President, Midstream, entered into a pre-arranged stock trading plan in November 2021. Mr. Parfitt’s plan provides for the potential exercise of vested stock options and the associated sale of up to 55,500 shares of Chevron common stock between February 2022 and January 2023.
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Not applicable.
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PART III
Item 10. Directors, Executive Officers and Corporate Governance
Information about our Executive Officers at February 24, 2022
Members of the Corporation’s Executive Committee are the Executive Officers of the Corporation:
NameAgeCurrent and Prior Positions (up to five years)Primary Areas of Responsibility
Michael K. Wirth61Chairman of the Board and Chief Executive Officer (since Feb 2018)
Vice Chairman of the Board (Feb 2017 - Jan 2018) and Executive
   Vice President, Midstream and Development (Jan 2016 - Jan 2018)
Chairman of the Board and
Chief Executive Officer
Joseph C. Geagea62Executive Vice President and Senior Advisor to Chairman and CEO
   (since Aug 2021)
Executive Vice President, Technology, Projects and Services
   (Jun 2015 - Aug 2021)
Advisor to the Chairman and CEO
James W. Johnson62Executive Vice President, Upstream (since Jun 2015)
Worldwide Exploration and Production Activities
Mark A. Nelson58Executive Vice President, Downstream (since Mar 2019)
Vice President, Midstream, Strategy and Policy (Feb 2018 - Feb
   2019)
Vice President, Strategic Planning (Apr 2016 - Jan 2018)
Worldwide Manufacturing, Marketing and Lubricants; Chemicals
Eimear P. Bonner47Vice President (since Aug 2021), Chief Technology Officer and
   President of Chevron Technical Center (since Feb 2021)
General Director of Tengizchevroil (Dec 2018 - Jan 2021)
General Manager of Operations of Tengizchevroil (Nov 2015 - Nov
   2018)
Information Technology; Subsurface; Global Reserves; Wells; Asset Performance and Process Safety; Facilities Designs and Solutions; Capital Projects; Health, Safety and Environment; Downstream Technology
Pierre R. Breber57Vice President and Chief Financial Officer (since Apr 2019)
Executive Vice President, Downstream (Jan 2016 - Mar 2019)
Finance
Rhonda J. Morris56Vice President and Chief Human Resources Officer (since Feb 2019)
Vice President, Human Resources (Oct 2016 - Jan 2019)
Human Resources; Diversity and Inclusion
Colin E. Parfitt57Vice President, Midstream (since Mar 2019)
President, Supply and Trading (Jun 2013 - Feb 2019)
Supply and Trading Activities; Shipping; Pipeline; Power and Energy Management
R. Hewitt Pate59Vice President and General Counsel (since Aug 2009)Law, Governance and Compliance
 
The information about directors required by Item 401(a), (d), (e) and (f) of Regulation S-K and contained under the heading “Election of Directors” in the Notice of the 2022 Annual Meeting of Stockholders and 2022 Proxy Statement, to be filed pursuant to Rule 14a-6(b) under the Exchange Act in connection with the company’s 2022 Annual Meeting (the 2022 Proxy Statement), is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 406 of Regulation S-K and contained under the heading “Corporate Governance — Business Conduct and Ethics Code” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 407(d)(4) and (5) of Regulation S-K and contained under the heading “Corporate Governance — Board Committees” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
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Item 11. Executive Compensation
The information required by Item 402 of Regulation S-K and contained under the headings “Executive Compensation,” “CEO Pay Ratio” and “Director Compensation” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 407(e)(4) of Regulation S-K and contained under the heading “Corporate Governance — Board Committees” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 407(e)(5) of Regulation S-K and contained under the heading “Corporate Governance — Management Compensation Committee Report” in the 2022 Proxy Statement is incorporated herein by reference into this Annual Report on Form 10-K. Pursuant to the rules and regulations of the SEC under the Exchange Act, the information under such caption incorporated by reference from the 2022 Proxy Statement shall not be deemed to be “soliciting material,” or to be “filed” with the Commission, or subject to Regulation 14A or 14C or the liabilities of Section 18 of the Exchange Act, nor shall it be deemed incorporated by reference into any filing under the Securities Act of 1933.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by Item 403 of Regulation S-K and contained under the heading “Stock Ownership Information — Security Ownership of Certain Beneficial Owners and Management” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 201(d) of Regulation S-K and contained under the heading “Equity Compensation Plan Information” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information required by Item 404 of Regulation S-K and contained under the heading “Corporate Governance — Related Person Transactions” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
The information required by Item 407(a) of Regulation S-K and contained under the heading “Corporate Governance — Director Independence” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
Item 14. Principal Accounting Fees and Services
The information required by Item 9(e) of Schedule 14A and contained under the heading “Board Proposal to Ratify PricewaterhouseCoopers LLP as the Independent Registered Public Accounting Firm for 2022” in the 2022 Proxy Statement is incorporated by reference into this Annual Report on Form 10-K.
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Financial Table of Contents

31



Management's Discussion and Analysis of Financial Condition and Results of Operations
Key Financial Results
Millions of dollars, except per-share amounts202120202019
Net Income (Loss) Attributable to Chevron Corporation$15,625 $(5,543)$2,924 
Per Share Amounts:
Net Income (Loss) Attributable to Chevron Corporation
– Basic$8.15 $(2.96)$1.55 
– Diluted$8.14 $(2.96)$1.54 
Dividends$5.31 $5.16 $4.76 
Sales and Other Operating Revenues$155,606 $94,471 $139,865 
Return on:
Capital Employed9.4 %(2.8)%2.0 %
Stockholders’ Equity11.5 %(4.0)%2.0 %
Earnings by Major Operating Area
Millions of dollars202120202019
Upstream
United States$7,319 $(1,608)$(5,094)
International8,499 (825)7,670 
Total Upstream15,818 (2,433)2,576 
Downstream
United States2,389 (571)1,559 
International525 618 922 
Total Downstream2,914 47 2,481 
All Other(3,107)(3,157)(2,133)
Net Income (Loss) Attributable to Chevron Corporation1,2
$15,625 $(5,543)$2,924 
1 Includes foreign currency effects:
$306 $(645)$(304)
2 Income net of tax, also referred to as “earnings” in the discussions that follow.
Refer to the “Results of Operations” section beginning on page 38 for a discussion of financial results by major operating area for the three years ended December 31, 2021.
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, Egypt, Equatorial Guinea, Israel, Kazakhstan, Kurdistan Region of Iraq, 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.
The company’s objective is to deliver higher returns, lower carbon and superior shareholder value in any business environment. 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. Periods of sustained lower commodity 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.
Governments, companies, communities, and other stakeholders are increasingly supporting efforts to address climate change, recognizing that individuals and society benefit from access to affordable, reliable, and ever-cleaner energy. International initiatives and national, regional and state legislation and regulations that aim to directly or indirectly reduce GHG emissions are in various stages of adoption and implementation. These policies, some of which support the global net zero emissions ambitions of the Paris Agreement, can change the amount of energy consumed, the rate of energy-demand growth, the energy mix, and the relative economics of one fuel versus another. Implementation of these policies can be dependent on, and can affect the pace of, technological advancements, the granting of necessary permits by governing authorities, the availability of cost-effective, verifiable carbon credits, the availability of suppliers that can meet sustainability and other standards, evolving regulatory requirements affecting ESG standards or other disclosures, and evolving standards for tracking and reporting on emissions and emission reductions and removals. Beyond the legislative and regulatory landscape, ever changing customer and consumer behavior can also influence energy demand by affecting preferences and use of the company’s products or competitors’ products, now and in the future.
32



Management's Discussion and Analysis of Financial Condition and Results of Operations
Chevron supports the Paris Agreement’s global approach to governments addressing climate change and is committed to taking actions to help lower the carbon intensity of its operations while continuing to meet the need for energy that supports society. Chevron integrates climate change-related issues and the regulatory and other responses to these issues into its strategy and planning, capital investment reviews, and risk management tools and processes, where it believes they are applicable. They are also factored into the company’s long-range supply, demand, and energy price forecasts. These forecasts reflect estimates of long-range effects from climate change-related policy actions, such as renewable fuel penetration and energy efficiency standards, and demand response to oil and natural gas prices. The actual level of expenditure required to comply with new or potential climate change-related laws and regulations and amount of additional investments in new or existing technology or facilities, such as carbon capture and storage, is difficult to predict with certainty and is expected to vary depending on the actual laws and regulations enacted or customer and consumer preference in a jurisdiction, the company’s activities in it, and market conditions. As discussed in more detail below, the company has announced planned capital spend of $10 billion through 2028 in lower carbon investments.
Although the future is uncertain, many published outlooks conclude that fossil fuels will remain a significant part of an energy system that increasingly incorporates lower carbon sources of supply. The company will continue to develop oil and gas resources to meet customers’ demand for energy. At the same time, Chevron believes that the future of energy is lower carbon. The company will continue to maintain flexibility in its portfolio to be responsive to changes in policy, technology, and customer preferences. Chevron aims to grow its traditional oil and gas business, lower the carbon intensity of its operations and grow lower carbon businesses in renewable fuels, hydrogen, carbon capture and offsets. To grow its lower carbon businesses, Chevron plans to target sectors of the economy where emissions are harder to abate or that cannot be easily electrified, while leveraging the company’s capabilities, assets and customer relationships. The company’s traditional oil and gas business may increase or decrease depending upon regulatory or market forces, among other factors.
In 2021, Chevron announced the following aspiration and targets that are aligned with its lower carbon strategy:
2050 Net Zero Upstream Aspiration Chevron aspires to achieve net zero for Upstream production Scope 1 and 2 GHG Emissions on an equity basis by 2050. The company believes accomplishing this aspiration depends on, among other things, partnerships with multiple stakeholders, continuing progress on commercially viable technology, government policy, successful negotiations for carbon capture and storage and nature-based projects, availability of cost-effective, verifiable offsets in the global market, and granting of necessary permits by governing authorities.
2028 Upstream Production GHG Intensity Targets These metrics include Scope 1, direct emissions, and Scope 2, indirect emissions from imported electricity and steam, and are net of emissions from exported electricity and steam. The targeted 2028 reductions from 2016 on an equity ownership basis include a:
40 percent reduction in oil production GHG intensity to 24 kilograms (kg) carbon dioxide equivalent per barrel of oil-equivalent (CO2e/boe),
26 percent reduction in gas production GHG intensity to 24 kg CO2e/boe,
53 percent reduction in methane intensity to 2 kg CO2e/boe, and
66 percent reduction in flaring GHG intensity to 3 kg CO2e/boe.
The company also targets no routine flaring by 2030. We have set 2016 as our baseline to align with the year the Paris Agreement entered into force, and the company plans to update the metrics every five years in line with the Paris Agreement stocktakes. We believe these updates will provide additional transparency on the company’s progress toward its net zero aspiration.
2028 Portfolio Carbon Intensity Target The company also introduced a portfolio carbon intensity (PCI) metric, which is a measure of the carbon intensity across the full value chain of Chevron’s entire business. This metric encompasses the company’s Upstream and Downstream business and includes Scope 1 (direct emissions), Scope 2 (indirect emissions from imported electricity and steam), and certain Scope 3 (primarily emissions from use of sold products) emissions. The company’s PCI target is 71 grams (g) carbon dioxide equivalent (CO e) per megajoules (MJ) by 2028, a greater than five percent reduction from 2016.
Planned Lower-Carbon Capital Spend through 2028 The company increased its planned capital spend to approximately $10 billion through 2028 to advance its lower carbon strategy, which includes approximately $2 billion to lower the carbon intensity of its traditional oil and gas operations, and approximately $8 billion for lower carbon investments in renewable fuels, hydrogen and carbon capture and offsets. We anticipate setting additional capital spending targets as the company
33



Management's Discussion and Analysis of Financial Condition and Results of Operations
progresses toward its 2050 Upstream production Scope 1 and 2 net zero aspiration and further grows its lower carbon business lines.
Refer to “Risk Factors” in Part I, Item 1A, on pages 20 through 25 for further discussion of greenhouse gas regulation and climate change and the associated risks to Chevron’s business, including the risks impacting Chevron’s lower carbon strategy and its aspirations, targets and plans.
Response to Market Conditions and COVID-19 Commodity prices and demand for most of our products have largely recovered from the impacts of COVID-19 in 2020. However, some countries face a resurgence of the virus and its variants (e.g., Delta, Omicron) that could impact demand for some of our products (e.g., jet fuel), workforce availability, timing of project start-ups and materials movement and pose a risk to our business and future financial results.
Chevron’s operations have continued with a combination of on-site and at-home work, while monitoring local vaccine and transmission rates. In refining, the company continued to take steps to maximize diesel and motor gasoline production, given the decline in jet fuel demand.
In TCO, progress continued on FGP/WPMP. Staffing is at targeted levels and at the end of December 2021, over 90 percent of the TCO workforce on-site was fully vaccinated.
The effective tax rate for the company can change substantially during periods of significant earnings volatility. This is mainly due to 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 income tax rate in one period may not be indicative of expected results in future periods. Note 17 Taxes provides the company’s effective income tax rate for the last three years.
Refer to the “Cautionary Statements Relevant to Forward-Looking Information” on page 2 and to “Risk Factors” in Part I, Item 1A, on pages 20 through 25 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 and 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 closely monitors developments in the financial and credit markets, the level of worldwide economic activity, and the implications for the company of movements in prices for crude oil and natural gas. Management takes these developments into account in the conduct of daily operations and for business planning.
Comments related to earnings trends for the company’s major business areas are as follows:
Upstream Earnings for the upstream segment are closely aligned with industry prices for crude oil and natural gas. Crude oil and natural gas prices are subject to external factors over which the company has no control, including product demand connected with global economic conditions, industry production and inventory levels, technology advancements, production quotas or other actions imposed by OPEC+ countries, 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, the pace of energy transition, and changes in tax, environmental 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 and ensure supply chain resiliency and continuity in support of operational goals. Third party costs for capital, exploration, and operating expenses can be subject to external factors beyond the company’s control including, but not limited to: severe weather or civil unrest, delays in construction, global and local supply chain distribution issues, 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 changes in market trends.
34



Management's Discussion and Analysis of Financial Condition and Results of Operations
Prices for goods and services in various sectors have risen over the past year. A key factor behind this trend is the accelerated demand for goods and transportation as companies restock materials and expand working inventories as a hedge against future disruptions. Shifts in the labor market continue to create issues for companies seeking to fill positions. Geographic mismatches between skills required and available labor, reductions in the overall labor supply, and perceptions of working conditions have resulted in tight labor markets.
As U.S. and international drilling activity continues to accelerate, continued upward market pressure is expected for oil and gas industry inputs (such as rigs and well services). The pace of economic growth and shifting spending patterns may lead to more cross-industry competition for resources, which could impact the cost of certain non-oil and gas industry goods and services.
cvx-20211231_g1.jpg
The chart above shows the trend in benchmark prices for Brent crude oil, West Texas Intermediate (WTI) crude oil and U.S. Henry Hub natural gas. The Brent price averaged $71 per barrel for the full-year 2021, compared to $42 in 2020. As of mid-February 2022, the Brent price was $100 per barrel. The WTI price averaged $68 per barrel for the full-year 2021, compared to $39 in 2020. As of mid-February 2022, the WTI price was $95 per barrel. The majority of the company’s equity crude production is priced based on the Brent benchmark.
Crude prices increased in 2021 driven by production curtailment by OPEC+ countries and steadily increasing demand for transportation fuels. The company’s average realization for U.S. crude oil and natural gas liquids in 2021 was $56 per barrel, up 84 percent from 2020. The company’s average realization for international crude oil and natural gas liquids in 2021 was $65 per barrel, up 79 percent from 2020.
Prices 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 $3.85 per thousand cubic feet (MCF) during 2021, compared with $1.98 per MCF during 2020. As of mid-February 2022, the Henry Hub spot price was $3.93 per MCF.
Outside the United States, prices for natural gas depend on a wide range of supply, demand and regulatory circumstances. 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 some sold in the Asian spot LNG market. International natural gas realizations averaged $5.93 per MCF during 2021, compared with $4.59 per MCF during 2020. (See page 42 for the company’s average natural gas realizations for the U.S. and international regions.)
The company’s worldwide net oil-equivalent production in 2021 was a record 3.099 million barrels per day. About 27 percent of the company’s net oil-equivalent production in 2021 occurred in OPEC+ member countries of Angola, Equatorial Guinea, Kazakhstan, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait and Republic of Congo.
The company estimates that its net oil-equivalent production in 2022 will be flat to down 3 percent compared to 2021, assuming a Brent crude oil price of $60 per barrel and excluding the impact of asset sales that may close in 2022. This estimate is subject to many factors and uncertainties, including quotas or other actions that may be imposed by OPEC+; price effects on entitlement volumes; changes in fiscal terms or restrictions on the scope of company operations; delays in construction; reservoir performance; greater-than-expected declines in production from mature fields; start-up or ramp-up of projects; fluctuations in demand for crude oil and natural gas in various markets; weather conditions that may shut in
35



Management's Discussion and Analysis of Financial Condition and Results of Operations
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.
In January 2022, Chevron announced its intent to begin the process of exiting from its nonoperated interests in Myanmar. At December 31, 2021, the carrying value of the company’s assets was approximately $200 million.
cvx-20211231_g2.jpg
Net proved reserves for consolidated companies and affiliated companies totaled 11.3 billion barrels of oil-equivalent at year-end 2021, an increase of 1 percent from year-end 2020. The reserve replacement ratio in 2021 was 112 percent. The 5 and 10 year reserve replacement ratios were 103 percent and 100 percent, respectively. Refer to Table V for a tabulation of the company’s proved net oil and gas reserves by geographic area, at the beginning of 2019 and each year-end from 2019 through 2021, and an accompanying discussion of major changes to proved reserves by geographic area for the three-year period ending December 31, 2021.
Refer to the “Results of Operations” section on pages 39 and 40 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, petrochemicals and renewable fuels. Industry margins are sometimes volatile and can be affected by the global and regional supply-and-demand balance for refined products and petrochemicals, and by changes in the price of crude oil, other refinery and petrochemical feedstocks, and natural gas. Industry margins can also be influenced by inventory levels, geopolitical events, costs of materials and services, refinery or chemical plant capacity utilization, maintenance programs, and disruptions at refineries or chemical plants resulting from unplanned outages due to severe weather, fires or other operational events.
Other factors affecting profitability for downstream operations include the reliability and efficiency of the company’s refining, marketing and petrochemical assets, the effectiveness of its crude oil and product supply functions, and the volatility of tanker-charter rates for the company’s shipping operations, which are driven by the industry’s demand for crude oil and product tankers. Other factors beyond the company’s control include the general level of inflation and energy costs to operate the company’s refining, marketing and petrochemical assets, and changes in tax, environmental, and other applicable laws and regulations.
The company’s most significant marketing areas are the West Coast and Gulf Coast of the United States and Asia Pacific. Chevron operates or has significant ownership interests in refineries in each of these areas. Additionally, the company has a small but growing presence in renewable fuels.
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Management's Discussion and Analysis of Financial Condition and Results of Operations
Refer to the “Results of Operations” section on page 40 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
Key operating developments and other events during 2021 and early 2022 included the following:
Upstream
Angola Chevron’s affiliate, Cabinda Gulf Oil Company Limited (CABGOC), signed an agreement to extend the Block 0 concession for 20 years, through 2050.
Australia Sanctioned the Jansz-Io compression project, a part of the Gorgon development and an important source of natural gas supply to the Gorgon LNG facility.
Brazil Completed the sale of the company's 37.5 percent nonoperated interest in the Papa-Terra oil field.
Equatorial Guinea Announced the start-up and first LNG cargo from the Alen Gas Monetization Project.
Japan Announced the signing of a binding Sale and Purchase Agreement with Hokkaido Gas Co., Ltd. for the delivery of about a half million tons of LNG over a period of five years, starting in 2022.
United States Entered FEED for the Ballymore project, which is being developed as a subsea tieback to the existing Blind Faith facility, in the deepwater Gulf of Mexico.
United States Sanctioned the Whale project in the deepwater Gulf of Mexico.
Downstream
Finland Announced an agreement to acquire Neste Oyj’s Group III base oil business, including its related sales and marketing business, and brand NEXBASETM.
South Korea Chevron’s 50 percent owned affiliate, GS Caltex, started up an olefins mixed-feed cracker and associated polyethylene unit at its Yeosu refinery ahead of schedule and under budget.
United States Announced the commissioning and start-up of the world’s first commercial-scale ISOALKY™ process unit at the Salt Lake City Refinery. This proprietary technology uses ionic liquids to produce a high octane gasoline blending component as a cost-effective alternative to conventional alkylation technologies and offers environmental and process safety advantages.
United States Began producing renewable diesel at the El Segundo, California refinery by co-processing bio-feedstock.
United States Announced establishment of its first branded Compressed Natural Gas (CNG) station, as part of its plan to sell RNG through more than 30 CNG stations in California by 2025.
United States Acquired an equity interest in American Natural Gas LLC (now Beyond6, LLC) and its network of 60 compressed natural gas stations across the United States to grow its RNG value chain.
United States Announced the second expansion of its joint venture, Brightmark RNG Holdings LLC, to own projects across the United States to produce and market dairy biomethane, a RNG. First gas delivery at the Lawnhurst site in New York was announced in November.
United States Announced the launch of Havoline® PRO-RS™ Renewable Full Synthetic Motor Oil made with 25 percent sustainably sourced plant-based oils.
United States Celebrated the opening of the 1,000th ExtraMile Convenience store.
United States Chevron’s 50 percent owned affiliate, CPChem, announced the first commercial sales of their Marlex® Anew™ Circular Polyethylene, which uses advanced recycling technology to process pyrolysis oil, a feedstock made from difficult-to-recycle waste plastics.
United States Announced the signing of definitive transaction agreements to create a joint venture with Bunge North America, Inc., to own and operate soybean processing facilities.
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Management's Discussion and Analysis of Financial Condition and Results of Operations
Other
United States Announced the launch of Chevron’s $300 million Future Energy Fund II focused on technologies that have the potential to enable affordable, reliable, and ever-cleaner energy for all.
United States Announced plans with partners to develop carbon negative bioenergy in Mendota, California.
United States Announced memorandums of understanding with Toyota Motors North America, Inc. to explore a strategic alliance to catalyze and lead the development of commercially viable, large-scale businesses in hydrogen; with Cummins Inc. to explore a strategic alliance to develop commercially viable business opportunities in hydrogen and other alternative energy sources; with Delta Air Lines, Inc. and Google LLC to track sustainable aviation fuel test batch emissions data using cloud-based technology; and with Progress Rail Locomotive Inc., a Caterpillar company, and BNSF Railway Company to demonstrate hydrogen-fueled locomotives.
United States Acquired all of the publicly held common units representing limited partner interests in Noble Midstream Partners LP not already owned by Chevron and its affiliates.
United States Announced a collaboration agreement with Caterpillar Inc. to develop hydrogen demonstration projects in transportation and stationary power applications, including prime power.
United States Announced a letter of intent with Gevo, Inc. to jointly invest in building and operating one or more new facilities that process inedible corn to produce sustainable aviation fuel.
United States Announced agreement on a framework to acquire an equity interest in ACES Delta, LLC that owns the Advanced Clean Energy Storage project. This project aims to produce, store and transport green hydrogen at utility scale.
United States Announced a framework with Enterprise Product Partners L.P. to study and evaluate opportunities for carbon dioxide capture, utilization, and storage from their respective business operations in the U.S. Midcontinent and Gulf Coast.
United States Invested in companies to access lower-carbon technologies, including Baseload Capital AB (low-temperature geothermal and heat power), Starfire Energy (carbon-free ammonia and carbon-free hydrogen), Ocergy, Inc. (floating offshore and wind turbine technology), Mainspring (lower-carbon generators for electric grids), Raygen (solar-hydro plant with storage), Boomitra (soil carbon offset platform), Natel Energy (hydro-power based technology), Raven SR Inc. (modular waste-to-green hydrogen and renewable synthetic fuel facilities), Sapphire Technologies (waste energy recovery systems), Hydrogenious LOHC Technologies (liquid organic hydrogen carriers), gr3n SA (plastics recycling technology), Malta Inc. (thermal energy storage) and Ionomr Innovations Inc. (ion-exchange membranes and polymers).
Common Stock Dividends The 2021 annual dividend was $5.31 per share, making 2021 the 34th consecutive year that the company increased its annual per share dividend payout. In January 2022, the company’s Board of Directors increased its quarterly dividend by $0.08 per share, approximately six percent, to $1.42 per share payable in March 2022.
Common Stock Repurchase Program The company resumed stock repurchases in third quarter 2021 and purchased $1.4 billion of its common stock in 2021 under its stock repurchase program. The company currently expects to repurchase $1.25 billion of its common stock during the first quarter of 2022.
Results of Operations
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.” Earnings are also presented for the U.S. and international geographic areas of the Upstream and Downstream business segments. Refer to Note 14 Operating Segments and Geographic Data for a discussion of the company’s “reportable segments.” This section should also be read in conjunction with the discussion in “Business Environment and Outlook” on pages 32 through 37. Refer to the “Selected Operating Data” table on page 42 for a three-year comparison of production volumes, refined product sales volumes, and refinery inputs. A discussion of variances between 2020 and 2019 can be found in the “Results of Operations” section on pages 37 through 38 of the company’s 2020 Annual Report on Form 10-K filed with the SEC on February 25, 2021.
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Management's Discussion and Analysis of Financial Condition and Results of Operations
cvx-20211231_g3.jpg
U.S. Upstream
Millions of dollars202120202019
Earnings (Loss)$7,319 $(1,608)$(5,094)
U.S. upstream reported earnings of $7.3 billion in 2021, compared with a loss of $1.6 billion in 2020. The increase was due to higher realizations of $6.9 billion, the absence of 2020 impairments and write-offs of $1.2 billion, higher sales volumes of $760 million, and higher asset sales gains of $640 million.
The company’s average realization for U.S. crude oil and natural gas liquids in 2021 was $56.06 per barrel compared with $30.53 in 2020. The average natural gas realization was $3.11 per thousand cubic feet in 2021, compared with $0.98 in 2020.
Net oil-equivalent production in 2021 averaged 1.14 million barrels per day, up 8 percent from 2020. The increase was due to an additional 162,000 barrels per day of production from the Noble Energy acquisition, partially offset by a 63,000 barrels per day decrease related to the Appalachian asset sale.
The net liquids component of oil-equivalent production for 2021 averaged 858,000 barrels per day, up 9 percent from 2020. Net natural gas production averaged 1.69 billion cubic feet per day in 2021, an increase of 5 percent from 2020.
International Upstream
Millions of dollars202120202019
Earnings (Loss)*
$8,499 $(825)$7,670 
*Includes foreign currency effects:
$302 $(285)$(323)
International upstream reported earnings of $8.5 billion in 2021, compared with a loss of $825 million in 2020. The increase was primarily due to higher realizations of $7.6 billion, along with the absence of 2020 impairments and write-offs of $3.6 billion and severance charges of $290 million. Partially offsetting these increases are higher tax charges of $630 million, the absence of 2020 asset sales gains of $550 million, and higher depreciation expenses of $670 million and lower sales volumes of $540 million. Foreign currency effects had a favorable impact on earnings of $587 million between periods.
The company’s average realization for international crude oil and natural gas liquids in 2021 was $64.53 per barrel compared with $36.07 in 2020. The average natural gas realization was $5.93 per thousand cubic feet in 2021 compared with $4.59 in 2020.
International net oil-equivalent production was 1.96 million barrels per day in 2021, down 3 percent from 2020. The decrease was primarily due to the absence of 69,000 barrels per day following expiration of the Rokan concession in
39



Management's Discussion and Analysis of Financial Condition and Results of Operations
Indonesia, unfavorable entitlement effects, normal field declines and the effect of asset sales, partially offset by 113,000 barrels per day associated with the Noble Energy acquisition and lower production curtailments.
The net liquids component of international oil-equivalent production was 956,000 barrels per day in 2021, a decrease of 11 percent from 2020. International net natural gas production of 6.02 billion cubic feet per day in 2021 increased 6 percent from 2020.
U.S. Downstream
Millions of dollars202120202019
Earnings (Loss)$2,389 $(571)$1,559 
U.S. downstream reported earnings of $2.4 billion in 2021, compared with a loss of $571 million in 2020. The increase was primarily due to higher margins on refined product sales of $1.6 billion, higher earnings from 50 percent-owned CPChem of $1.0 billion and higher sales volumes of $470 million, partially offset by higher operating expenses of $150 million.
Total refined product sales of 1.14 million barrels per day in 2021 increased 14 percent from 2020, mainly due to higher gasoline, jet fuel, and diesel demand as travel restrictions associated with the COVID-19 pandemic continue to ease.
International Downstream
Millions of dollars202120202019
Earnings*
$525 $618 $922 
*Includes foreign currency effects:
$185 $(152)$17 
International downstream earned $525 million in 2021, compared with $618 million in 2020. The decrease in earnings was largely due to lower margins on refined product sales of $330 million and higher operating expenses of $100 million, partially offset by a favorable swing in foreign currency effects of $337 million between periods.
Total refined product sales of 1.32 million barrels per day in 2021 were up 8 percent from 2020, mainly due to the second quarter 2020 acquisition of Puma Energy (Australia) Holdings Pty Ltd. and higher diesel and gasoline demand, partially offset by lower jet fuel demand.
All Other
Millions of dollars202120202019
Net charges*
$(3,107)$(3,157)$(2,133)
*Includes foreign currency effects:
$(181)$(208)$
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 2021 decreased $50 million from 2020. The change between periods was mainly due to the absence of 2020 severance, Noble acquisition and mining remediation costs, and lower corporate charges, partially offset by higher employee benefit costs and a loss on early retirement of debt. Foreign currency effects decreased net charges by $27 million between periods.
Consolidated Statement of Income
Comparative amounts for certain income statement categories are shown below. A discussion of variances between 2020 and 2019 can be found in the “Consolidated Statement of Income” section on pages 39 and 40 of the company’s 2020 Annual Report on Form 10-K.
Millions of dollars202120202019 
Sales and other operating revenues$155,606 $94,471 $139,865 
Sales and other operating revenues increased in 2021 mainly due to higher refined product, crude oil, and natural gas prices and sales volumes.
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Management's Discussion and Analysis of Financial Condition and Results of Operations
Millions of dollars202120202019 
Income (loss) from equity affiliates$5,657 $(472)$3,968 
Income from equity affiliates improved in 2021 mainly due to the absence of the full impairment of Petropiar and Petroboscan in Venezuela in 2020, higher upstream-related earnings from Tengizchevroil in Kazakhstan and Angola LNG, and higher downstream-related earnings from CPChem and GS Caltex in Korea.
Refer to Note 15 Investments and Advances for a discussion of Chevron’s investments in affiliated companies.
Millions of dollars202120202019 
Other income$1,202 $693 $2,683 
Other income increased in 2021 mainly due to a favorable swing in foreign currency effects and higher gains on asset sales, partially offset by losses on the early retirement of debt.
Millions of dollars202120202019 
Purchased crude oil and products$89,372 $50,488 $80,113 
Crude oil and product purchases increased in 2021 primarily due to higher crude oil, natural gas, and refined product prices and higher refined product volumes.
Millions of dollars202120202019 
Operating, selling, general and administrative expenses$24,740 $24,536 $25,528 
Operating, selling, general and administrative expenses increased in 2021 primarily due to higher employee benefit and transportation costs partially offset by the absence of 2020 severance accruals.
Millions of dollars202120202019 
Exploration expense$549 $1,537 $770 
Exploration expenses in 2021 decreased primarily due to lower charges for well write-offs.
Millions of dollars202120202019 
Depreciation, depletion and amortization$17,925 $19,508 $29,218 
Depreciation, depletion and amortization expenses decreased in 2021 primarily due to lower impairment charges, partially offset by higher rates and production.
Millions of dollars202120202019 
Taxes other than on income$6,840 $4,499 $4,136 
Taxes other than on income increased in 2021 primarily due to higher regulatory expenses, taxes on production and excise taxes, which was primarily driven by higher refined product sales in Australia.
Millions of dollars202120202019 
Interest and debt expense$712 $697 $798 
Interest and debt expenses increased in 2021 mainly due to interest expense associated with debt acquired in the Noble Energy acquisition.
Millions of dollars202120202019 
Other components of net periodic benefit costs$688 $880 $417 
Other components of net periodic benefit costs decreased in 2021 primarily due to lower interest costs.
Millions of dollars202120202019 
Income tax expense (benefit) $5,950 $(1,892)$2,691 
The increase in income tax expense in 2021 of $7.84 billion is due to the increase in total income before tax for the company of $29.09 billion. The increase in income before taxes for the company is primarily the result of higher upstream realizations, the absence of 2020 impairments and write-offs, and higher downstream margins.
U.S. income before tax increased from a loss of $5.70 billion in 2020 to income of $9.67 billion in 2021. This $15.37 billion increase in income was primarily driven by higher upstream realizations, higher downstream margins and the absence of 2020 impairments and write-offs. The increase in income had a direct impact on the company’s U.S. income tax resulting in an increase to tax expense of $3.18 billion between year-over-year periods, from a tax benefit of $1.58 billion in 2020 to a charge of $1.60 billion in 2021.
41



Management's Discussion and Analysis of Financial Condition and Results of Operations
International income before tax increased from a loss of $1.75 billion in 2020 to income of $11.97 billion in 2021. This $13.72 billion increase in income was primarily driven by higher upstream realizations and the absence of 2020 impairments and write-offs. The increased income primarily drove the $4.66 billion increase in international income tax expense between year-over-year periods, from a tax benefit of $308 million in 2020 to a charge of $4.35 billion in 2021.
Refer also to the discussion of the effective income tax rate in Note 17 Taxes.
Selected Operating Data1,2
202120202019
U.S. Upstream
Net Crude Oil and Natural Gas Liquids Production (MBPD)858790724
Net Natural Gas Production (MMCFPD)3
1,6891,6071,225
Net Oil-Equivalent Production (MBOEPD)1,1391,058929
Sales of Natural Gas (MMCFPD)4,0073,8944,016
Sales of Natural Gas Liquids (MBPD)201208130
Revenues from Net Production
Liquids ($/Bbl)$56.06 $30.53 $48.54 
Natural Gas ($/MCF)$3.11 $0.98 $1.09 
International Upstream
Net Crude Oil and Natural Gas Liquids Production (MBPD)4
9561,0781,141
Net Natural Gas Production (MMCFPD)3
6,0205,6835,932
Net Oil-Equivalent Production (MBOEPD)4
1,9602,0252,129
Sales of Natural Gas (MMCFPD)5,1785,6345,869
Sales of Natural Gas Liquids (MBPD)844634
Revenues from Liftings
Liquids ($/Bbl)$64.53 $36.07 $58.14 
Natural Gas ($/MCF)$5.93 $4.59 $5.83 
Worldwide Upstream
Net Oil-Equivalent Production (MBOEPD)4
United States1,1391,058929
International1,9602,0252,129
Total3,0993,0833,058
U.S. Downstream
Gasoline Sales (MBPD)5
655581667
Other Refined Product Sales (MBPD)484422583
Total Refined Product Sales (MBPD)1,1391,0031,250
Sales of Natural Gas Liquids (MBPD)2925101
Refinery Input (MBPD)6
903