UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form10-K
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| ☑ | Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 | ☐ | Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 |
| For the fiscal year ended | December 31, 20202022 | | For the transition period from to |
Commission File Number 1-9210
Occidental Petroleum Corporation
(Exact name of registrant as specified in its charter)
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| State or other jurisdiction of incorporation or organization | | Delaware |
| I.R.S. Employer Identification No. | | 95-4035997 |
| Address of principal executive offices | | 5 Greenway Plaza, Suite 110 | Houston, | Texas |
| Zip Code | | 77046 |
| Registrant’s telephone number, including area code | | (713) | 215-7000 |
Securities registered pursuant to Section 12(b) of the Act:
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| Title of Each Class | Trading Symbol | Name of Each Exchange on Which Registered |
| Common Stock, $0.20 par value | OXY | New York Stock Exchange |
| Warrants to Purchase Common Stock, $0.20 par value | OXY WS | New York Stock Exchange |
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes ☑ No ☐
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 ☐ No ☑
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
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| Large Accelerated Filer | ☑ | Accelerated Filer | ☐ | Emerging Growth Company | ☐ |
| Non-Accelerated Filer | ☐ | Smaller Reporting Company | ☐ | | |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control 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 ☑
The aggregate market value of the registrant’s Common Stock held by nonaffiliates of the registrant was approximately $17.0$53.0 billion computed by reference to the closing price on the New York Stock Exchange of $18.30$58.88 per share of Common Stock on June 30, 2020.2022.
AtAs of January 31, 2021,2023, there were 931,554,718900,072,447 shares of Common Stock outstanding, par value $0.20 per share.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s definitive Proxy Statement, relating to its 20212022 Annual Meeting of Stockholders, are incorporated by reference into Part III of this Form 10-K.
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| TABLE OF CONTENTS | PAGE |
| Part I | | |
| Items 1 and 2. | | |
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| Human Capital Resources | |
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| Item 1A. | | |
| Item 1B. | | |
| Item 3. | | |
| Item 4. | Mine Safety Disclosures | |
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| Part II | | |
| Item 5. | | |
Item 6. | | |
| Item 7. | | |
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| Item 7A. | | |
| Item 8. | | |
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| Item 9. | | |
| Item 9A. | | |
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| Item 9B. | | |
| Item 9C. | Disclosure Regarding Foreign Jurisdictions that Prevented Inspections | |
| Part III | | |
| Item 10. | | |
| Item 11. | | |
| Item 12. | | |
| Item 13. | | |
| Item 14. | | |
| Part IV | | |
| Item 15. | | |
| Item 16. | | |
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| ABBREVIATIONS USED WITHIN THIS DOCUMENT |
| AAPG | American Association of Petroleum Geologists |
| AOC | Administrative Order on Consent |
| Anadarko | Anadarko Petroleum Corporation and its consolidated subsidiaries |
| Anadarko Acquisition | A transaction pursuant to the Agreement and Plan of Merger dated May 9, 2019, in which Occidental acquired all of the outstanding shares of Anadarko on August 8, 2019, and in which a wholly owned subsidiary of Occidental merged with and into Anadarko |
| Andes | Andes Petroleum Ecuador Ltd. |
| ARO | asset retirement obligations |
| Bcf | billions of cubic feet |
| Bcf/d | billions of cubic feet per day |
| Berkshire Hathaway | Berkshire Hathaway Inc. |
| BLM | U.S. Bureau of Land Management
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| the Board | Occidental Board of Directors |
| Boe | barrels of oil equivalent |
| BOEM | U.S. Bureau of Ocean Energy Management |
| CCUS | carbon capture, utilization and storage |
| CERCLA | Comprehensive Environmental Response, Compensation, and Liability Act |
CO2 | carbon dioxide |
| COGCC | Colorado Oil and Gas Conservation Commission |
| Common Stock Warrants | a distribution of warrants to holders of Occidental common stock |
| CROCE | cash returns on capital employed |
| CROCEI | cash return on capital employed incentive |
| DAC | direct air capture |
| DASS | Diamond Alkali Superfund Site |
| DD&A | depreciation, depletion and amortization |
| DEL | Dolphin Energy Limited |
| DIB | diversity, inclusion and belonging |
| DOJ | U.S. Department of Justice |
| DSCC | Diamond Alkali Chemicals Company |
| EDC | ethylene dichloride |
| EOR | enhanced oil recovery |
| EPA | U.S. Environmental Protection Agency |
| EPS | earnings per share |
| ERG | Employee Resource Group |
| Exchange Act | Securities Exchange Act of 1934 |
| GAAP | Generally accepted accounting principles |
| GHG | greenhouse gas |
| HSE | health, safety and environmental |
| Kerr-McGee | Kerr-McGee Corporation and certain of its subsidiaries |
| LIBOR | London Interbank Offered Rate |
| LIFO | last-in, first-out |
| OCI | other comprehensive income |
| Maxus | Maxus Energy Corporation |
| Mbbl | thousands of barrels |
| Mbbl/d | thousands of barrels per day |
| Mboe | thousands of barrels equivalent |
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| ABBREVIATIONS USED WITHIN THIS DOCUMENT |
| Mboe/d | thousands of barrels equivalent per day |
| Mcf | thousand cubic feet |
| MMbbl | millions of barrels |
| MMbtu | million British thermal units |
| MMcf | millions of cubic feet |
| NAV | net asset value |
| NEPA | National Environmental Policy Act
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| NGL | natural gas liquids |
| NPL | National Priorities List |
| NYMEX | New York Mercantile Exchange |
| NYSE | New York Stock Exchange |
| Occidental | Occidental Petroleum Corporation, a Delaware corporation and one or more entities in which it owns a controlling interest (subsidiaries) |
| OEPC | Occidental Exploration and Production Company |
| OLCV | Occidental’s low-carbon ventures businesses |
| OPEC | Organization of the Petroleum Exporting Countries |
| Options | stock options |
| OTC | Over-the-Counter |
| OU | Operable Unit |
| OxyChem | Occidental Chemical Corporation, and its consolidated subsidiaries |
| the Plan | stockholder-approved 2015 Long-Term Incentive Plan, as amended and restated, for certain employees and directors |
| PP&E | property, plant & equipment |
| PSC | production sharing contracts |
| PUD | proved undeveloped |
| PVC | polyvinyl chloride |
| RCF | revolving credit facility |
| Reserves Committee | Corporate Reserves Review Committee |
| ROD | Record of Decision |
| RSUs | restricted stock units |
| Ryder Scott | Ryder Scott Company, L.P. |
| S&P 500 | Standard & Poor’s 500 Stock Index |
| SEC | U.S. Securities and Exchange Commission |
| SOFR | Secured Overnight Financing Rate |
| Sonatrach | The national oil and gas company of Algeria |
| STEP | Strategic Technical Excellence Program |
| the Trust | Maxus Liquidating Trust |
| TSRI | total shareholder return incentive |
| UAE | United Arab Emirates |
| VCM | Vinyl chloride monomer |
| WES | Western Midstream Partners, LP |
| WTI | West Texas Intermediate |
| Zero Coupons | Zero Coupon senior notes due 2036 |
| 2022 Form 10-K | Occidental’s Annual Report on Form 10-K for the year ended December 31, 2022 |
Part I
ITEMS 1 AND 2. BUSINESS AND PROPERTIES
In this report,Form 10-K, “Occidental”, “we”, “our” and “our”“the Company” refers to Occidental Petroleum Corporation, a Delaware corporation incorporated in 1986, or Occidental and one or more entities in which it owns a controlling interest (subsidiaries). Occidental conducts its operations through its various subsidiaries and affiliates. Occidental’s executive offices are located at 5 Greenway Plaza, Suite 110, Houston, Texas 77046; telephone (713) 215-7000.
Occidental’s principal businesses consist of three reporting segments: oil and gas, chemical and midstream and marketing. The oil and gas segment explores for, develops and produces oil and condensate, natural gas liquids (NGL)(which includes condensate), NGL and natural gas. The chemical segment (OxyChem) mainlyprimarily manufactures and markets basic chemicals and vinyls. The midstream and marketing segment purchases, markets, gathers, processes, transports and stores oil, condensate, NGL, natural gas, carbon dioxide (COCO2) and power. It also trades aroundoptimizes its assets, including transportation and storage capacity, and invests in entities that conduct similar activities, such as Western Midstream Partners, L.P. (WES).WES.
The midstream and marketing segment also includes Oxy Low Carbon Ventures (OLCV).OLCV. OLCV seeks to leverage Occidental’s legacy of carbon management expertise that is derivedto develop CCUS projects, including the commercialization of DAC technology, and invests in other low-carbon technologies intended to reduce GHG emissions from its enhanced oil recovery (EOR) operations and strategically partner with other industries to develop carbon capture, utilization and storage facilities that are expected to source anthropogenic CO2 and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducinghelp reduce their emissions.
On August 8, 2019, pursuant to the Agreement and Plan of Merger dated May 9, 2019, Occidental acquired all of the outstanding shares of Anadarko Petroleum Corporation (Anadarko), through a transaction in which a wholly owned subsidiary of Occidental merged with and into Anadarko (the Acquisition). The Acquisition added to Occidental's oil and gas portfolio, primarily in the Permian Basin, DJ Basin, Gulf of Mexico and Algeria, and an interest in WES.
For further information regarding Occidental’s segments, geographic areas of operation and current developments, see the Management’s Discussion and Analysis of Financial Condition and Results of Operations section under Part II, Item 7, of this Form 10-K and Note 18 - Industry Segments and Geographic Areas in the Notes to Consolidated Financial Statements.
Occidental’s culture of diversity, inclusion and belonging aspires to create an environment where differences are appreciated, all employees are included and everyone feels that they belong. As part of our commitment to support this culture, we conducted a robust survey across our organization. The results were reviewed with our Board of Directors and are a basis for our company’sis built upon the following core values.
Occidental’s human capital resources extend across several regions. Occidental has attracted a diverse work force of exceptional talent, including employees from many nations. This diversity enriches our culture, our employees' experience on the job and contributes to an innovative and effective business model that encourages local communities to thrive. Diversity, inclusion and belonging power our innovation and spirit of excellence, as well as our knowledge and results. Embedding diversity, inclusion and belonging into our culture enhances Occidental’s collaboration, performance and growth and helps uphold our organizational values. Occidental’s culture of diversity, inclusion and belonging is designed to create an environment where our employees’ differences are celebrated and encouraged. Occidental’s management works to leverage its employees’ various backgrounds, unique experiences and points of view to spark innovation, empower growth, outperform expectations and maximize results. Diversity is who we are, inclusion is how we work and belonging is how we thrive. Occidental’s recruiting, training and career development programs are designed to help every employee realize his or her full potential.
The below table approximates regional distribution of Occidental’s employees:
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| | North America | | Middle East | | Latin America | | Other (a) | | Total (b) |
| Union | | 500 | | 800 | | 50 | | — | | | 1,350 |
| Non-Union | | 7,750 | | 2,500 | | 100 | | 100 | | 10,450 |
| Total | | 8,250 | | 3,300 | | 150 | | 100 | | 11,800 |
(a)Other headcount includes North Africa, Europe and Asia.
(b)Includes approximately 2,900 employees in the Chemical segment.
Occidental is dedicated to attracting and retaining top talent and Occidental is regularly evaluating and updating its human capital resources to enable its employees to live well and work well. Occidental offers education resources, programs, time away benefits and insurance to support multiple factors of health including physical, financial, social and mental. Occidental’s ultimate goal is to give employees the tools and resources they need to succeed both personally and professionally and foster a safe and collaborative work environment.
Occidental’s employees are key to its ability to safely adapt to an evolving business environment; one of Occidental’s top priorities is safety for all. In industries where Occidental operates one of the key performance indicators of a successful company is a low injury incidence rate. Occidental’s injury rate for 2020 was historically low. Management’s compensation is impacted by the number of health and safety incidents, which was most recently reflected in management’s 2020 annual bonus determination.
Occidental’s employees are evaluated relative to Occidental’s core values. These core values are as follows:values:
■Lead with Passion
■Outperform Expectations
■Deliver Results Responsibly
■Unleash Opportunities
■Commit to Good
Occidental’s human capital resources and programs are managed by its Human Resources department, with support from business leaders across the company. Occidental’s senior management team plays a key role in setting and monitoring Occidental’s culture, values and broader human capital management practices, with oversight by Occidental’s Board of Directors, the Sustainability and Shareholder Engagement Committee of the Board and the Environmental, Health & Safety Committee of the Board. The Sustainability and Shareholder Engagement Committee periodically receives briefings on Occidental’s human capital strategy and the Environmental, Health & Safety Committee receives briefings on employee and contractor health and safety statistics and related matters, including workforce health and safety initiatives. Senior management and the Board also engage regularly on workforce-related topics.
To enhance senior leadership’s engagement with employees, Occidental hosts quarterly executive virtual conversations where Occidental’s President and CEO, Vicki Hollub, and other executive officers review recent financial and operational performance as well as topics pertinent to employees. Occidental’s CEO also answers employee questions during these conversations. The quarterly executive virtual conversations form one piece of Occidental’s employee outreach and engagement, which consists of newsletters, focus groups and employee resource groups, among other channels and tools.
DIVERSITY, INCLUSION AND BELONGING
The intent of Occidental’s DIB culture is to create an environment where employees’ differences are appreciated, celebrated and encouraged. Occidental conducted a robust survey across the organization, the results of which were reviewed by the Board and became a basis for Occidental’s core values.
The Company’s human capital resources extend across several regions. Occidental has attracted, and continues to recruit, a diverse workforce of exceptional talent, including employees from many nations. This diversity enriches Occidental’s culture, its employees' experiences on the job and contributes to an innovative and effective business model that encourages local communities to thrive. DIB powers Occidental’s innovation and spirit of excellence, as well as its knowledge and results. Embedding DIB into Occidental’s culture enhances collaboration, performance and growth and helps uphold its organizational values.
The DIB Advisory Board, which is chaired by Occidental’s President and CEO and includes members of senior leadership, provides DIB governance and oversight to ensure that Occidental’s integrated DIB strategy is executed and aligns with the Company’s mission, vision and strategic objectives. The DIB Ambassador Committee, which is chaired by Occidental’s Vice President of Diversity and Inclusion, consists of a diverse group of employee representatives from all
business segments, domestic and international. This committee leads company-wide initiatives to raise DIB awareness through educational resources and programs. Educational sessions are available to the entire workforce for continued growth and development on topics such as inclusive leadership, diversity advocacy, recognizing and addressing micro aggressions, overcoming unconscious bias and psychological safety at work.
Occidental’s senior management, together with the support of Occidental’s DIB Advisory Board and the DIB Ambassador Committee, works to leverage employees’ varied backgrounds, unique experiences and points of view to spark innovation, empower growth, outperform expectations and maximize results.
In October 2022, as part of Occidental’s integrated DIB strategy, the Human Resources department launched eight new Employee Resource Groups. An ERG is a group of employees who actively engage in communicating or gathering around a central purpose, mission, background or activity. ERGs can help advance inclusion and a sense of belonging of employees with a common set of interests and/or goals. The mission and goals of ERGs are fully aligned with Occidental’s expectation to be an employer, partner, and neighbor of choice. Each ERG is inclusive of all employees—everyone can benefit from and participate in an ERG, either as a member or an ally. Occidental’s ERGs are as follows:
•Allyship
•Black Employee Network
•Early Career Network
•FRIEND (Friends, Relatives and Individuals Empowering Neurodiversity)
•Hispanic Network
•Mental Health Matters
•Mosaic (Multicultural) Network
•Out (LGBT+) Network
•Veterans Network
•Women of Oxy Network
TALENT ATTRACTION AND RETENTION
Occidental recruits candidates through job fairs, professional societies and campus recruiting, including expanded recruiting at historically black colleges and universities.
In 2022, Occidental began to return to in-person interviews, and the university relations team worked with universities and their staff to ensure that any in-person interviews and events were conducted safely. In addition, all college internships were in-person with appropriate health and safety precautions as senior leadership continued to monitor federal, state and local guidance and public health data.
In response to employee feedback received by the Human Resources department, to attract and retain talent, Occidental implemented the Balanced Workplace Program in 2022 under which eligible office-based employees may opt to work three days in the office and two days at home each week. The program affords employees more flexibility and promotes increased balance. The Human Resources department solicited feedback from employees participating in the Balanced Workplace Program regarding their experience and to gauge interest in other work arrangements. Following review of such feedback, in June 2022, the Human Resources department began conducting a fully remote pilot program for employees in certain functions.
In 2021, Occidental implemented its global Strategic Technical Excellence Program to recruit, develop and retain highly skilled and valued geoscientists, engineers, scientists and other petrotechnical professionals who will collectively drive innovation, advance performance and inspire the future of energy. STEP is a highly valued program for technical contributors to focus and advance on a technical, non-managerial career path and provides a competitive advantage for Occidental through the optimum application of technology. The Chief Petrotechnical Officer leads all aspects of STEP and reports directly to Occidental’s President and CEO.
Occidental also offers employees development opportunities, competitive compensation and attractive benefits, as discussed further below.
DEVELOPMENT AND TRAINING
Occidental employees have access to extensive development and training opportunities and programs to expand their personal and professional skills and knowledge. Occidental’s approach to education includes:
■Leadership/management training to develop leadership skills at all levels;
■Self-directed learning and development, including web-based and instructor-led training;
■An employee development library;
■Mentoring programs;
■Employee resource groups; and
■Educational assistance to support employees’ continuing education.
In January 2022, Occidental expanded its development and training opportunities and programs from 94 on-demand professional development classes to over 3,000 on-demand classes with over 26,000 types of learning materials (videos, audio books, etc.).
In May 2022, Occidental launched its new domestic mentoring program, EMPower. The purpose of this program is to provide an avenue for enhancing critical business skills, broadening employee networks, and engaging our employees. This program is available for all domestic employees. EMPower is intended to help employees reach their potential through training and empowerment, allowing employees to advance in their careers and develop critical skills.
EMPLOYEE COMPENSATION AND BENEFITS
In addition to prioritizing employee engagement and development, Occidental’s compensation and benefits program is designed to attract and retain the talent necessary to achieve its business strategy. The compensation and benefits program recognizes and rewards strong company and individual performance with competitive base salaries, an annual bonus program, recognition awards, long-term performance incentives and advancement opportunities. In 2022, Occidental awarded a one-time special bonus to recognize the innovative and dedicated work of the company’s employees and resulting strong operational and financial performance. The Company’s compensation and benefits program is routinely reviewed and benchmarked to ensure competitiveness and to provide the benefits that matter most to current and future employees.
Occidental strives to give employees the tools and resources they need to succeed both professionally and personally and to foster a safe and collaborative work environment. To that end, Occidental offers, and regularly evaluates, its comprehensive health, welfare and retirement and savings benefits plans, professional memberships and work/life balance benefits. It also provides programs to enhance and support employees’ overall well-being, including their physical, mental, social and financial health.
In January 2022, Occidental introduced a new benefit service provider that provides a health care concierge service to help families manage and navigate medical, in-home care, housing, and social/emotional support, for their own or their families’ complex care needs. Furthermore, to make the most of employees’ benefits, it is important employees are aware of all that the company has to offer to help employees live well and work well. In the fall of 2022, members of the company’s Employee Benefits department presented a Total Rewards Roadshow and traveled to numerous Occidental sites to connect with employees, answer questions and share valuable information about benefits.
MENTAL HEALTH
Addressing well-being is imperative to ensure that Occidental’s employees stay resilient, healthy and productive. In 2021, Occidental launched the global well-being campaign “Commit to You” to educate employees and leaders about how its benefits can support them under the four pillars of well-being: mental, physical, social and financial.
In 2022, Occidental prioritized the importance of mental health and well-being through manager and employee programs and events. One program, sponsored by OxyHealth and the Mental Health Matters ERG, was a "Talk Saves Lives" conversation with the American Foundation for Suicide Prevention to learn about common risk factors, how to spot warning signs in others, and how to keep employees, loved ones, and those in the community safe. Most recently, on January 1, 2023, the company launched an enhanced mental health benefit through Lyra Health. Lyra Health provides mental and emotional healthcare that is effective, convenient and personalized to all employees globally.
Occidental continues to be a member of One Mind at Work, an employer coalition dedicated to implementing a gold standard for workplace mental health by combating stigma, improving access to treatment and prevention services and fostering a psychologically safe culture. In 2022, Occidental’s CEO and the Chairman of One Mind at Work participated in a video broadcast for employees about breaking down the stigma around mental health challenges at work and what Occidental employees can expect as we transition into an organization where mental health is an accepted and visible part of its well-being.
HEALTH AND SAFETY
The health and safety of Occidental’s workforce and communities is a top priority. In 2022, the Board approved updates to the company’s longstanding Health, Safety and Environmental Principles (as revised, the HSE and Sustainability Principles) that management recommended based on engagement with shareholders, employees and other stakeholders. The HSE and Sustainability Principles reinforce the alignment among Occidental’s core values, goals and strategies, underpin the operational management system, and help to guide Occidentals global workforce. Occidental endeavors to apply these principles to improve workplace and contractor safety, prevent and mitigate incidents, and safeguard people and the environment in the communities where it operates. In addition to complying with applicable HSE laws, regulations, policies and procedures, employees and contractors are empowered and expected to stop any job or activity if they observe conditions that may give rise to a safety or environmental incident, and they are often recognized for doing so.
WORKFORCE COMPOSITION
The below table approximates regional distribution of Occidental’s employees as of December 31, 2022:
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| | North America | | Middle East | | Latin America | | Other (a) | | Total (b) |
| Union | | 416 | | 800 | | | 50 | | — | | | 1,266 |
| Non-Union | | 7,842 | | 2,624 | | 121 | | 120 | | 10,707 |
| Total | | 8,258 | | 3,424 | | 171 | | 120 | | 11,973 |
(a)Other headcount included North Africa, Europe and Asia.
(b)Included approximately 2,800 employees in OxyChem.
The below table approximates the self-reported gender and ethnicity, excluding non-specified ethnicities, of Occidental’s domestic leadership and other employees as of December 31, 2022. Executive and senior officials and managers are considered top leadership while first- and mid-level officials and managers are considered junior leadership. Individual contributors are excluded from the leadership categories but included in all employee percentages.
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| | Male | | Female | | White | | non-White |
| All employees | | 78 | % | | 22 | % | | 66 | % | | 34 | % |
| All leadership | | 78 | % | | 22 | % | | 75 | % | | 25 | % |
| Top leadership | | 83 | % | | 17 | % | | 85 | % | | 15 | % |
| Junior leadership | | 78 | % | | 22 | % | | 75 | % | | 25 | % |
We have also publicly disclosed the Consolidated EEO-1 Report that Occidental submitted in 2022 to the U.S. Equal Employment Opportunity Commission for the 2021 fiscal year, which can be found on the sustainability section of our website.
Occidental’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports are available free of charge on its website, www.oxy.com, as soon as reasonably practicable after Occidental electronically files the material with, or furnishes it to, the Securities and Exchange Commission (SEC).SEC. In addition, copies of Occidental’s annual report will be made available, free of charge, upon written request.
From time to time, Occidental has made and expects in the future to use its website as a channel of distribution of material information regarding the Company. Financial and other material information regarding the Company is routinely posted on Occidental’s website and accessible at www.oxy.com/investors/.
Information contained on Occidental’s website is not part of or incorporated into this reportForm 10-K or any other filings with the SEC.
GENERAL
Occidental’s oil and gas assets are characterized by an advantaged mix of short-cycle and long-cycle high-return development opportunities. Occidental primarily conducts its ongoing exploration and production activities in the United States, the Middle East and North Africa. Within the United States, Occidental has operations primarily in Texas, New Mexico and Colorado, as well as offshore operations in the Gulf of Mexico. Internationally, Occidental primarily conducts operations primarily in the UAE, Oman United Arab Emirates (UAE) and Algeria. Operations in Ghana are classified as held for sale as of December 31, 2020. Refer to the Oil and Gas Acreage section in Supplemental OilOil and Gas Information under Item 8 of this Form 10-K for further disclosure of Occidental’s holdings of developed and undeveloped oil and gas acreage.
COMPETITION
As a producer of oil, condensate, NGL and natural gas, Occidental competes with numerous other domestic and international public, private and government producers. Oil, (which includes condensate), NGL and natural gas are sensitive to prevailing global and local current andmarket conditions, as well as anticipated market conditions. Occidental’s competitive strategy relies on maintaining productionproducing hydrocarbons in a capital efficient manner through developing conventional and unconventional fields, and utilizing primary, secondary (waterflood) and EORtertiary (CO2 and steam flood) recovery techniques in areas where Occidental has a competitive advantage as a result of its successful operations or investments in shared infrastructure. Occidental also competes to develop and produce its worldwide oil and gas reserves safely, sustainably and cost-effectively, maintain a skilled workforce and obtainuse high quality services.service providers. Occidental believes that its core competencies in CO2 separation, transportation, use, recycling and storage in EOR provide a competitive advantage over its peers as the world transitions to a less carbon-intensive economy and seeks to remove CO2 from the atmosphere.
PROVED RESERVES AND SALES VOLUMES
The table below shows Occidental’s year-end oil, NGL and natural gas proved reserves. See the information under Oil and Gas Segment in the Management's Discussion and Analysis section under Part II, Item 7, of this reportForm 10-K for details regarding Occidental’s proved reserves, the reserves estimation process, sales and production volumes, production costs and other reserves-related data.
COMPARATIVE OIL AND GAS PROVED RESERVES AND SALES VOLUMES
Oil and NGL areis in millions of barrels;MMbbl; natural gas is in billions of cubic feet (Bcf); barrels of oil equivalent (Boe) are in millions.Bcf.
| | | 2020 | | 2019 | | 2018 | | | 2022 | | 2021 | | 2020 | |
| | Oil | NGL | Gas | Boe | (a) | Oil | NGL | Gas | Boe | (a) | Oil | NGL | Gas | Boe | (a) | | Oil | NGL | Gas | Boe | (a) | Oil | NGL | Gas | Boe | (a) | Oil | NGL | Gas | Boe | (a) |
Proved Reserves (b) | Proved Reserves (b) | | | Proved Reserves (b) | | |
| United States | United States | 1,144 | | 384 | | 2,446 | | 1,936 | | | 1,570 | | 540 | | 4,128 | | 2,798 | | | 1,186 | | 284 | | 1,445 | | 1,711 | | | United States | 1,639 | | 654 | | 4,073 | | 2,972 | | | 1,466 | | 564 | | 3,419 | | 2,600 | | | 1,144 | | 384 | | 2,446 | | 1,936 | | |
International (c,d) | 331 | | 215 | | 2,573 | | 975 | | | 469 | | 208 | | 2,572 | | 1,106 | | | 397 | | 202 | | 2,650 | | 1,041 | | | |
| International | | International | 274 | | 192 | | 2,277 | | 845 | | | 305 | | 202 | | 2,431 | | 912 | | | 331 | | 215 | | 2,573 | | 975 | | |
| Total | Total | 1,475 | | 599 | | 5,019 | | 2,911 | | | 2,039 | | 748 | | 6,700 | | 3,904 | | | 1,583 | | 486 | | 4,095 | | 2,752 | | | Total | 1,913 | | 846 | | 6,350 | | 3,817 | | | 1,771 | | 766 | | 5,850 | | 3,512 | | | 1,475 | | 599 | | 5,019 | | 2,911 | | |
| Sales Volumes | Sales Volumes | | | Sales Volumes | | |
| United States | United States | 205 | | 81 | | 561 | | 380 | | | 155 | | 52 | | 326 | | 261 | | | 91 | | 25 | | 119 | | 136 | | | United States | 185 | | 83 | | 445 | | 342 | | | 182 | | 79 | | 477 | | 341 | | | 205 | | 81 | | 561 | | 380 | | |
International (c,d) | 59 | | 13 | | 195 | | 104 | | | 64 | | 13 | | 204 | | 111 | | | 62 | | 11 | | 189 | | 104 | | | |
| International | | International | 41 | | 12 | | 164 | | 81 | | | 44 | | 12 | | 172 | | 85 | | | 59 | | 13 | | 195 | | 104 | | |
| Total | Total | 264 | | 94 | | 756 | | 484 | | | 219 | | 65 | | 530 | | 372 | | | 153 | | 36 | | 308 | | 240 | | | Total | 226 | | 95 | | 609 | | 423 | | | 226 | | 91 | | 649 | | 426 | | | 264 | | 94 | | 756 | | 484 | | |
(a)Natural gas volumes are converted to Boe at six thousand cubic feet (Mcf)Mcf of gas per one barrel of oil. Conversion to Boe does not necessarily result in price equivalency.
(b)The detailed proved reserves information presented in accordance with Item 1202(a)(2) to Regulation S-K under the Securities Exchange Act of 1934 (Exchange Act) is provided in the Supplemental Oil and Gas Information section in Item 8 of this Form 10-K. Proved reserves are stated on a net basis after applicable royalties.
(c)International proved reserves and sales volumes in 2019 have been reclassified to include Occidental’s operations in Algeria.
(d)ExcludesExcluded reserves and sales volumes related to Occidental’s discontinued operations in 2020 and 2019, respectively.operations.
GENERAL
OxyChem owns and operates manufacturing plants at 2221 domestic sites in Alabama, Georgia, Illinois, Kansas, Louisiana, Michigan, New Jersey, New York, Ohio, Tennessee and Texas and at two international sites in Canada and Chile.
COMPETITION
OxyChem competes with numerous other domestic and international chemical producers. OxyChem’s market position was first or second in the United States in 20202022 for the principal basic chemical products it manufacturesmanufactured and marketsmarketed as well as for vinyl chloride monomer (VCM).VCM. OxyChem ranks in the top three producers of polyvinyl chloride (PVC)PVC in the United States. OxyChem’s competitive strategy is to be a low-cost producer of its products in order to compete on price.
OxyChem producesproduced the following products:
| | | | | | | | |
| Principal Products | Major Uses | Annual Capacity |
| Basic Chemicals | | |
| Chlorine | Raw material for ethylene dichloride (EDC),EDC, water treatment and pharmaceuticals | 3.43.2 million tons |
| Caustic soda | Pulp, paper and aluminum production | 3.53.3 million tons |
| Chlorinated organics | Refrigerants(a), silicones and pharmaceuticals | 1.01 billion pounds |
| Potassium chemicals | Fertilizers, batteries, soaps, detergents and specialty glass | 0.4 million tons |
| EDC | Raw material for VCM | 2.1 billion pounds |
| Chlorinated isocyanurates | Swimming pool sanitation and disinfecting products | 131150 million pounds |
| Sodium silicates | Catalysts, soaps, detergents and paint pigments | 0.6 million tons |
| Calcium chloride | Ice melting, dust control, road stabilization and oil field services | 0.7 million tons |
| Vinyls | | |
| VCM | Precursor for PVC | 6.2 billion pounds |
| PVC | Piping, building materials and automotive and medical products | 3.7 billion pounds |
| Ethylene | Raw material for VCM | 1.21.3 billion pounds(b)
|
(a)IncludesIncluded 4CPe, a raw material used in making next generation climate friendly refrigerants with low global warming and zero ozone depletion potential.
(b)Amount is gross production capacity for 50/50 joint venture with Orbia (formerly Mexichem).Orbia.
| | |
| MIDSTREAM AND MARKETING OPERATIONS |
GENERAL
Occidental’s midstream and marketing operations primarily support and enhance its oil and gas and chemical businesses. The midstream and marketing segment strives to maximize realized value by optimizingoptimize the use of its gathering, processing, transportation, storage and terminal commitments and by providingto provide access to domestic and international markets. To generate returns, the segment evaluates opportunities across the value chain and uses its assets to provide services to Occidental subsidiaries, as well as third parties. The midstream and marketing segment operates or contracts for services on gathering systems, gas plants, co-generation facilities and storage facilities and invests in entities that conduct similar activities. The midstream and marketing segment has equity investments inactivities, such as WES and Dolphin Energy Limited.DEL, which are accounted for as equity method investments. WES owns gathering systems, plants and pipelines and earns revenue from fee-based and service-based contracts with Occidental and third parties. Dolphin Energy LimitedDEL owns and operates a pipeline whichthat connects its gas processing and compression plant in Qatar and its receiving facilities in the UAE, and uses its network of Dolphin Energy Limited-ownedDEL-owned and other existing leased pipelines to supply natural gas across the UAE and to Oman. Also includedThe midstream segment includes Al Hosn Gas, a processing facility in the UAE that removes sulfur from natural gas and processes the natural gas and sulfur for sale. The midstream and marketing segment is OLCV.also includes OLCV businesses.
LOW-CARBON BUSINESS
Leveraging Occidental’s carbon management expertise, OLCV primarily focuses on advancing carbon removal and CCUS projects, including developing and commercializing DAC technology. OLCV also invests in third-party entities that are developing technologies that advance other low-carbon initiatives, including NET Power, a clean energy technology company.
COMPETITION
Occidental’s midstream and marketing businesses operate in competitive and highly regulated markets. Occidental competes for capacity and infrastructure for the gathering, processing, transportation, storage and delivery of its products, which are sold at current market prices or on a forward basis to refiners, end users and other market participants. Occidental’s marketing business competes with other market participants on exchange platforms and through other bilateral transactions with direct counterparties. OLCV and its businesses and investees also face a broad range of competitors including state-owned enterprises; multinational companies in the energy, infrastructure, manufacturing, transportation, technology and financial sectors; and startup companies, with nascent markets for low-carbon products and CO2 removal credits that are subject to rapidly changing laws, regulations, policies and reporting and verification mechanisms that can significantly impact the financing, construction and operation of projects and the development of markets.
Occidental’s midstream and marketing operations are conducted in the locations described below as of December 31, 2020:
| | | | | | | | |
| Location | Description | Capacity (a) |
| Gas Plants | |
| Texas, New Mexico and Colorado | Occidental and third-party-operated natural gasgas/CO2 gathering, compression and processing systems and CO2 processing and capturing | 2.72.2 Bcf/d |
Texas, Rocky Mountains Pennsylvania and TexasOther | Equity investment in WES - gas processing facilities | 5.65.0 Bcf/d |
| UAE | Natural gas processing facilities for Al Hosn Gas | 1.3 Bcf/d |
| Pipelines and Gathering Systems | |
| Texas, New Mexico and Colorado | CO2 fields and pipeline systems transporting CO2 to oil and gas producing locations | 2.8 Bcf/d |
| Qatar, UAE and Oman | Equity investment in the Dolphin Energy LimitedDEL natural gas pipeline | 3.2 Bcf/d |
| United States | Equity investment in WES involved in gathering and transportation | 17,02714,712 miles of pipeline |
| Power Generation | |
| Texas and Louisiana | Occidental-operated power and steam generation facilities | 1,218 megawatts of electricity and 1.6 million pounds of steam per hour |
| OLCV | |
| Texas | Occidental-owned solar generation facility | 16.8 megawatts of electricity |
| Texas | Equity investment in a zero-emission natural gas generation demonstration facility | up to 50 megawatts of electricity |
| Canada | Equity investment in direct air capturedeveloping DAC technology, which captures CO2 directly from the atmosphere. The captured CO2 can be permanently sequestered or synthesized into transportation fuels.atmosphere | N/A |
(a)Amounts are gross, including interests held by third parties. Gas capacities are expressed in Bcf/d.
| | |
ENVIRONMENTAL REGULATIONRISK FACTORS |
For environmental regulation information, including associated costs, see the information under Environmental Liabilities and Expenditures in the Management’s Discussion and Analysis of Financial Condition and Results of Operations section under Part II, Item 7, of this Form 10-K and Risk Factors under Part I, Item 1A.
ITEM 1A. RISK FACTORS
Risks related to government regulations and the environment
Governmental actions and political instability may adversely affect Occidental’s businesses and results of operations.
Occidental’s businesses are subject to, and may be adversely affected by, the actions and decisions of many federal, state, local and international governments and political interests. As a result, Occidental faces risks of:
■New or amended laws and regulations, or new or different applications or interpretations of existing laws and regulations, including those related to drilling, manufacturing or production processes (including flaring and well stimulation techniques such as hydraulic fracturing and acidization), pipelines, labor and employment, taxes, royalty rates, permitted production rates, entitlements, import, export and use of raw materials, equipment or products, use or increased use of land, water and other natural resources, air emissions (including restrictions, taxes or fees on emissions of methane, CO2,or other substances), water recycling and disposal, waste minimization and disposal, public and occupational health and safety, the manufacturing of chemicals, asset integrity management, the marketing or export of commodities, security, environmental protection, and climate change-related and sustainability initiatives, all of which may restrict or prohibit activities of Occidental or its contractors or customers, increase Occidental’s costs or reduce demand for Occidental’s products.
■Violation of certain governmental laws and regulations, which may result in strict, joint and several liability and the imposition of significant administrative, civil or criminal fines and penalties and may also result in liability for remedial actions or assessments. Litigation, orders or other proceedings asserting strict, joint and several liability under such laws and regulations may seek to impose significant administrative, civil or criminal fines and penalties, damages or remedial actions or to require significant changes to, or even closure of, facilities or operations;
■Refusal of, or delay in, the extension or grant of exploration, development or production contracts; and
■Development delays and cost overruns due to approval delays for, or denial of, drilling, construction, environmental and other regulatory approvals, permits and authorizations
.
In November 2021, Congress passed and President Biden signed the Infrastructure Investment and Jobs Act. The Infrastructure Investment and Jobs Act reinstated the federal Superfund excise taxes on various chemicals that OxyChem manufactures. These excise taxes could lead to higher costs and impact margins. The Infrastructure Investment and Jobs Act also authorized the U.S. government to award grants for CCUS research, development and demonstration; carbon transport and storage infrastructure and permitting; carbon utilization and market development; and carbon removal. These grant programs were developed during 2022 and the awarding of grants in 2023 or future years could affect the selection and deployment of competing low-carbon technologies and the financing and market acceptance of proposed projects.
In August 2022, Congress passed and President Biden signed the Inflation Reduction Act, which expanded policy support and incentives for deployment of DAC, CCUS, hydrogen and other low-carbon projects, including several enhancements to federal tax credits. The Inflation Reduction Act also established an escalating methane emissions fee that the EPA will impose on certain upstream and midstream oil and gas operations per metric ton of methane emissions above certain thresholds commencing in 2024. The impact of this fee on Occidental will depend on implementing regulations that are expected to be issued in 2023.
In November 2021, the U.S. Department of the Interior released its Report on the Federal Oil and Gas Leasing Program, recommending increasing royalty rates and rents for drilling programs on federal public lands and in federal offshore waters, in addition to prioritizing leasing in areas with known resource potential and in proximity to existing oil and gas infrastructure and avoiding leasing in areas with competing uses such as recreation, wildlife habitat, conservation and historical and cultural resources. If the U.S. Department of the Interior were to issue regulations implementing these recommendations, Occidental’s subsidiaries could incur increased federal royalties and face restrictions on future potential drilling sites or infrastructure on federal lands.
In January 2022, the U.S. District Court for the District of Columbia invalidated the results of the BOEM oil and gas lease sale 257 in the Gulf of Mexico, in which an Occidental subsidiary was the high bidder on 30 additional new blocks located nearby to its existing host platforms, ruling that the BOEM’s environmental analysis of GHG emissions was inadequate under NEPA. The U.S. Department of the Interior, which oversees federal oil and gas development, is currently reviewing the decision. In August 2022, Congress reinstated the lease sale in the IRA, and the Occidental subsidiary received the leases in October 2022. Motions to dismiss are pending in the legal challenge to the lease sale. The BOEM’s authorization to hold lease sales expired in July 2022. The Bureau of Ocean Energy Management has issued a proposed 2023-2028 Five-Year Program which is subject to environmental review and public comment, and must be approved before future lease sales can occur.
In June 2022, advocacy groups filed a petition in the U.S. District Court for the District of Columbia against the BLM seeking to invalidate numerous drilling permits for oil and gas wells on federal lands in New Mexico and Wyoming, and potentially other states, that were approved by the BLM during the Biden Administration, including certain permits obtained by Occidental subsidiaries. The plaintiffs allege that the BLM failed to comply with various statutes, including NEPA, the Endangered Species Act and the Federal Land Policy and Management Act, by not adequately addressing GHG emissions
and climate change in the environmental documents underlying the approvals. Occidental, other producers and multiple trade associations have intervened and the BLM is preparing an administrative record. Similar cases challenge permits issued to other operators with respect to the BLM’s consideration of GHG and other air emissions under NEPA and other statutes.
In January 2023, the White House Council on Environmental Quality issued interim guidance to federal agencies for evaluating GHG emissions under NEPA that applies to certain federal actions such as oil and gas leasing and permitting on federal lands. The interim guidance, which is subject to public comment until March 2023, recommends that agencies quantify a project’s reasonably foreseeable direct and indirect GHG emissions and assign a monetary impact of the GHGs by applying a social cost of carbon selected by the government.
Although the foregoing BOEM proposed Five-Year Program for offshore leasing, the White House Council on Environmental Quality guidance and lawsuits do not affect Occidental’s existing production or planned 2023 drilling and completions activity, restrictions or uncertainty regarding federal lease sales and permits and associated royalty and regulatory requirements could impact the future ability to develop resources efficiently on federal lands and in federal waters.
Significant areas of the Permian Basin in West Texas and Southeast New Mexico are subject to current or proposed land use restrictions under the Endangered Species Act. In August 2022, in response to a lawsuit by advocacy groups, the U.S. Fish and Wildlife Service agreed to decide before the end of June 2023 whether to add the Dunes Sagebrush Lizard to the list of threatened and endangered species. In November 2022, the U.S. Fish and Wildlife Service published a final rule listing the Lesser Prairie Chicken as endangered. Although Occidental has entered into voluntary conservation agreements with respect to these and other species and their associated habitat in the Permian Basin, listing of such species may impose significant operational requirements and costs and increase the potential for litigation and enforcement actions.
In January 2021, the COGCC adopted new regulations that impose siting requirements or “setbacks” on certain oil and gas drilling locations based on the distance of a proposed well pad to occupied structures. Pursuant to the regulations, well pads cannot be located within 500 feet of an occupied structure without the consent of the property owner. As part of the permitting process, the COGCC will consider a series of siting requirements for all drilling locations located between 500 feet and 2,000 feet of an occupied structure. Alternatively, the operator may seek a waiver from each owner and tenant within the designated distance. Occidental has a dedicated, multidisciplinary stakeholder relations team that conducts regulatory and community outreach with respect to its permit applications and operations in Colorado. Under these new regulations and through thoughtful surface location planning, Occidental has obtained COGCC approval for five Oil and Gas Development Plans, inclusive of 12 well pad and facility locations and approximately 150 wells. In addition to the approximately 150 wells approved through the Oil and Gas Development Plan process, during the third quarter of 2022, Occidental became the first oil and gas operator in Colorado to obtain COGCC approval for the first Comprehensive Area Plan under the new COGCC rules. This comprehensive plan will support nine well pads and approximately 140 new wells and will provide for substantial future development in a geographically remote area on Colorado’s eastern plains. Oil and Gas Development Plans associated with the Comprehensive Area Plan will be submitted in 2023. While, as of December 31, 2022, Occidental is permitted, or had permit applications submitted to applicable regulatory agencies, for nearly all planned 2023 drilling and completions activity in the DJ Basin, any significant delays could result in changes to our development program in the DJ Basin and our ability to establish new proved undeveloped locations by meeting the SEC’s “reasonably certain” threshold for adding PUD reserves.
Texas and New Mexico have experienced an increase in seismic activity, with events measuring magnitude 3 or greater in each state. In the fourth quarter of 2021, both states issued new guidelines for operators to prevent or mitigate seismic activity, focused on produced water disposal wells. These guidelines also require operators to implement response plans for activities within agency-designated seismic response areas. These states have curtailed water disposal and suspended permits in seismic response areas, particularly in deep disposal wells. Occidental does not operate deep disposal wells in the seismic response areas established by the state agencies to date, and its shallow disposal wells have been authorized to operate at agency-approved volume limits. Occidental also has central water treatment and recycling facilities that reduce the need for disposal of produced water. While Occidental’s ability to drill and complete wells or to dispose of surplus produced water has not been impacted by these seismic guidelines to date, increased seismicity, or regulatory responses to seismic events, could impact the location, timing and cost of Occidental’s development program and existing operations in seismic response areas.
In 2016, the Toxic Substances Control Act (TSCA) was amended to expand the EPA’s authority to evaluate and regulate new and existing chemicals. The EPA is currently evaluating, or developing regulations with respect to, certain chemicals that OxyChem produces or uses in its chemical manufacturing operations. In April 2022, the EPA issued a proposed rule with respect to one chemical used in OxyChem’s manufacturing operations, but the EPA has not issued final regulations under the 2016 TSCA amendments with respect to any of these chemicals to date. Depending on the scope of any such final regulations, or of future TSCA regulations, OxyChem’s ability to use certain chemicals or to manufacture or sell certain of its products could be restricted and its costs could increase.
In addition, Occidental has experienced and may continue to experience adverse consequences, such as risk of loss or production limitations, because certain of its international operations are located in countries affected by political instability, nationalizations, corruption, armed conflict, terrorism, insurgency, civil unrest, security problems, labor unrest, OPEC production restrictions, equipment import restrictions and sanctions. Exposure to such risks may increase if a greater percentage of Occidental’s future oil and gas production or revenue comes from international sources.
Climate change and further regulation of GHG and other air emissions may adversely affect Occidental’s businesses and results of operations.
Continuing political, social and industry attention to climate change has resulted in both existing and pending international agreements and national, regional and local legislation and regulatory programs to reduce GHG emissions. The Biden Administration has identified climate change as a priority and has described a variety of avenues to prohibit or restrict oil and gas development activities in certain areas. In addition to the governmental actions described above, in February 2021, the Biden Administration established an Interagency Working Group to assign a price to the impact of each metric ton of GHG emissions that federal agencies could use to assess the benefits of more stringent GHG regulations and policy support for low-carbon projects. The Interagency Working Group set an interim value of $51 per metric ton of CO2 emissions at a 3% discount rate, and is expected to issue an updated value in April 2023.
In June 2021, Congress and President Biden reinstated the methane provisions of EPA’s 2012 and 2016 regulations, an action that Occidental supported. In November 2021, the White House Office of Domestic Climate Policy issued a U.S. Methane Emissions Reduction Action Plan that solicited public comment on the EPA’s proposed framework to expand federal regulation of methane and volatile organic compound emissions from a broader set of new upstream and midstream oil and gas operations, as well as various existing operations.
In November 2022, the EPA issued a supplemental proposal that would, through a combination of direct EPA regulation and state implementation plans, expand leak detection and repair programs, require rapid reporting and correction of larger emission sources, require emission controls for new and existing wells and facilities and certain types of activities, require replacement or conversion of certain emitting equipment such as pneumatic controllers, and encourage the use of advanced technologies to detect and measure methane emissions. Provisions applicable to emission sources built or modified after November 2021 would apply upon publication of the final rule, expected in 2023, provisions applicable to existing sources would take effect in 2028, and state plans to implement the rule would be due in 2025. The EPA has also requested public comments on the implementation of the IRA’s methane fee, and on the future expansion of the methane and volatile organic compound regulations to cover additional potential emission sources from abandoned but unplugged wells and certain pipeline and trucking activities. In November 2022, the BLM also proposed regulations to restrict venting and flaring from oil and gas operations on federal lands which are expected to be issued in 2023.
In June 2022, the EPA proposed to amend its GHG Reporting Rule to incorporate additional oil and gas sources and equipment, revise existing emissions estimation methodologies and calculations, and increase data collection, particularly for new or modified emissions sources. The EPA has proposed the amendments to apply to 2023 emissions that must be reported in the first quarter of 2024. These proposed amendments could increase Occidental’s reported estimated emissions from certain sources or types of equipment in its U.S. oil and gas operations. The EPA also proposed changes to the reporting that Occidental submits as a CO2 supplier and for the injection of CO2, as well as a new reporting category for sequestration of CO2 associated with enhanced oil recovery. The IRA also directed the EPA to update its GHG Reporting Rule to require greater use of measurements or empirical data, instead of emissions factors, by the third quarter of 2024.
Several state governments have also established rules aimed at reducing GHG emissions, some including GHG cap and trade programs and others directly regulating equipment that emits GHGs, including methane, and other compounds. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, including refineries and natural gas processing plants, to acquire and surrender emission allowances. Other U.S. states where Occidental operates, including Colorado, New Mexico and Texas, adopted or proposed new regulations, policies or strategies in 2021 and 2022 that increase inspection, recordkeeping, reporting, enforcement and controls on flaring, venting and equipment that emit methane and other compounds at oil and gas facilities. In certain instances, these states anticipate tying the processing and active status of oil and gas permits, including drilling permits, to air emissions and compliance. For example, Colorado has established GHG intensity targets for DJ Basin operators in 2025, 2027 and 2030, which Occidental currently meets.
These and other governmental actions relating to GHG and other air emissions are expected to require Occidental to incur increased operating and maintenance costs including higher rates charged by service providers and costs to purchase, operate and maintain emissions control systems, acquire emission allowances, pay taxes or fees for methane or carbon emissions and comply with new regulatory or reporting requirements; and they could prevent Occidental from conducting oil and gas development activities in certain areas. They could also promote the use of alternative sources of energy and thereby decrease demand for oil, NGL and natural gas and other products that Occidental’s businesses produce, and could also materially impact OLCV’s current or future operations and strategy. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, oil, NGL, natural gas or other products produced by Occidental’s businesses and lower the value of its reserves. Consequently, governmental actions designed to reduce GHG emissions could have an adverse effect on Occidental’s businesses, financial condition, results of operations, cash flows and reserves.
It is difficult to predict the timing, certainty and scope of such government actions and their ultimate effect on Occidental, which could depend on, among other things, the type and extent of GHG emissions reductions required, the availability and price of emission allowances or credits, the availability and price of alternative fuel sources, the energy sectors covered and
Occidental’s ability to recover the costs incurred through its operating agreements or the pricing of its oil, NGL, natural gas and other products and whether service providers are able to pass increased costs through to Occidental.
There also have been efforts in the investment community, including investment advisers, financial institutions and certain sovereign wealth, pension and endowment funds, as well as political actors and other stakeholders, promoting divestment of fossil fuel equities, reducing access to capital markets and pressuring lenders to limit funding or increase the cost of lending to companies engaged in the extraction of fossil fuel reserves. Additionally, institutional lenders who provide financing to oil and gas companies have become more attentive to sustainable lending practices, and some of them may substantially reduce, or elect not to provide, funding for oil and gas companies. Such environmental initiatives aimed at limiting climate change and reducing air emissions could adversely affect Occidental’s business activities, operations and ability to access capital, cause the market value of its securities to decrease or its cost of capital to increase, and adversely affect its reputation. Finally, increasing attention to climate change risks has resulted in an increased possibility of governmental investigations and additional private litigation against Occidental without regard to causation or its contribution to the asserted damage, which could increase its costs or otherwise adversely affect our businesses.
Compliance costs and liabilities associated with health, safety and environmental laws and regulations could have a material adverse effect on Occidental’s or its subsidiaries’ businesses, financial condition and results of operations.
Occidental and its subsidiaries and their respective operations are subject to numerous laws and regulations relating to public and occupational health, safety and environmental protection, including those governing air and GHG emissions, water use and discharges, waste management and protection of wildlife and ecosystems. The requirements of these laws and regulations are becoming increasingly complex, stringent and expensive to implement. Costs of compliance with these laws and regulations are significant and can be unpredictable. These laws sometimes provide for strict liability for events that pose an impact or threat to public health and safety or to the environment, including for funding or performance of remediation and, in some cases, compensation for alleged personal injury, property damage, natural resource damages, punitive damages, civil penalties, injunctive relief and government oversight costs. Strict liability can render Occidental or its subsidiaries liable for damages without regard to their degree of care or fault. Some environmental laws provide for joint and several strict liability for remediation of spills and releases of hazardous substances or materials, and, as a result, Occidental or its subsidiaries could be liable for the actions of others.
Occidental and its subsidiaries use and generate hazardous substances or materials in their respective operations. In addition, many of their current and former properties are, or have been, used for industrial purposes. Accordingly, Occidental or its subsidiaries have been, and could become, subject to significant liabilities relating to the investigation, assessment and remediation of potentially contaminated properties and to claims alleging personal injury or property damage as a result of exposures to, or releases of, hazardous substances or materials. As of the date of this filing, Occidental believes its range of reasonably possibly additional losses of its subsidiaries beyond those amounts currently recorded for environmental remediation could be up to $2.7 billion on a consolidated basis. For additional discussion of some of these matters, see Note 12 – Environmental Liabilities and Expenditures and Note 13 - Lawsuits, Claims, Commitments and Contingencies in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K.
In addition, stricter enforcement or changing interpretations of existing laws and regulations, the enactment of new laws and regulations, the discovery of previously unknown contamination or the imposition of new or increased requirements could require Occidental or its subsidiaries to incur costs or become the basis for new or increased liabilities that could have a material adverse effect on their respective businesses, financial condition and results of operations.
Occidental’s businesses may experience catastrophic events.
The occurrence of severe weather events such as hurricanes, floods, freezes and heat waves, droughts, earthquakes or other acts of nature, pandemics, well blowouts, fires, explosions, pipeline ruptures, chemical releases, oil releases, including maritime releases, releases into navigable waters and groundwater contamination, material or mechanical failure, power outages, industrial accidents, physical or cyber attacks, abnormally pressured or structured formations and other events that cause operations to cease or be curtailed may negatively affect Occidental’s businesses and the communities in which it operates. Coastal operations are particularly susceptible to disruption from severe weather events. Any of these risks could adversely affect Occidental’s ability to conduct operations or result in substantial losses as a result of:
■Damage to and destruction of property and equipment, including property and equipment owned by third-parties which its operations rely upon;
■Damage to natural resources;
■Pollution and other environmental damage, including spillage or mishandling of recovered chemicals or fluids;
■Regulatory investigations, fines and penalties;
■Loss of well location, acreage, expected production and related reserves;
■Suspension or delay of its operations;
■Substantial liability claims; and
■Significant repair and remediation costs that increase its break-even economics.
Third-party insurance may not provide adequate coverage or Occidental or its subsidiaries may be self-insured with respect to the related losses. In addition, under certain circumstances, Occidental or its subsidiaries may be liable for environmental conditions on properties that they currently own, lease or operate that were caused by previous owners or operators of those properties. As a result, Occidental or its subsidiaries may incur substantial liabilities to third parties or governmental entities for environmental matters for which they do not have insurance coverage, which could reduce or eliminate funds available for exploration, development, acquisitions or other investments in their respective businesses, or cause them to incur losses.
The COVID-19 pandemic has adversely affected our business and the ultimateresulting adverse economic conditions have had, and may continue to have, an adverse effect on ourOccidental’s businesses and operations and financial condition will depend on future developments, which are highly uncertain.
The COVID-19 pandemic has adversely affectedcaused, and any resurgence of the global economy,pandemic could again cause, disrupted global supply chains and created significant volatility in the financial markets. In addition, the pandemic has resulted in travel restrictions, business closures and the institution of quarantining and other restrictions on movement in many communities. As a result, there has been a significant reduction in demand for and prices ofCurrent crude oil, NGL and natural gas.gas demand and prices could be negatively impacted by a resurgence of COVID-19 cases, slow vaccine distribution in certain large international economies or the recurrence or tightening of travel restrictions and stay-at-home orders. If the reduced demand for and lower prices of crude oil, NGL and natural gas persist for a prolonged period, ourOccidental’s operations, financial condition, cash flows, level of expenditures and the quantity of estimated proved reserves that may be attributed to ourits properties may be materially and adversely affected. Our operations also may be adversely affected ifOccidental has not experienced any significant portionsdisruptions as a result of our workforce are unable to work effectively, including because of illness, quarantines, government actions or other restrictions in connection with the pandemic. We have implemented workplace restrictions in our officesany new COVID-19 variants, and work sites for health and safety reasons and continueit continues to monitor national, state and local government directives where we have operations and/or offices. Further, our business plan, including our financing and liquidity plan, includes, among other things, planned divestitures. If general economic conditions or conditions in the energy industry persist at current levels for an extended period of time, we may not be able to complete these transactions on favorable terms, in a timely manner or at all. The extent to which the COVID-19 pandemic adversely affects our business,Occidental’s businesses, results of operations and financial condition will depend on future developments, many of which are highly uncertain, including the scope and durationoutside of the pandemic and actions taken by governmental authorities and other third parties in response to the pandemic. The COVID-19 pandemic may also materially adversely affect our operating and financial results in a manner that is not currently known to us or that we do not currently consider to present significant risks to our operations.its control. To the extent the COVID-19 pandemic may continue to adversely affect our business,Occidental’s businesses, results of operations and financial condition, and operating results, it may also have the effect of heightening the other risks described herein.
Risks related to Occidental’s businesses and operations
Volatile global and local commodity pricing strongly affect Occidental’s results of operations.
Occidental’s financial results correlate closely to the prices it obtains for its products, particularly oil and, to a lesser extent, NGL, natural gas and its chemical products and natural gas.products.
Prices for oil, NGL and natural gas fluctuate widely. Historically, the markets for oil, NGL and natural gas have been volatile and may continue to be volatile in the future. If the prices of oil, NGL or natural gas continue to be volatile or decline, Occidental’s operations, financial condition, cash flows, level of expenditures and the quantity of estimated proved reserves that may be attributed to ourits properties may be materially and adversely affected. Prices are set by global and local market forces which are not in Occidental’s control. These factors include, among others:
■Worldwide and domestic supplies of, and demand for, oil, NGL, natural gas and refined products;
■The cost of exploring for, developing, producing, refining and marketing oil, NGL, natural gas and refined products;
■Operational impacts such as production disruptions, technological advances and regional market conditions, including available transportation capacity and infrastructure constraints in producing areas;
■Changes in weather patterns and climate;
■The impacts of the members of the Organization of the Petroleum Exporting Countries (OPEC)OPEC and other non-OPEC member-producing nations that may agree to and maintain production levels;
■The ongoing global impact of the Russia-Ukraine war;
■The worldwide military and political environment, including uncertainty or instability resulting from an escalation or outbreak of armed hostilities or acts of terrorism in the United States or elsewhere;
■The price and availability of and demand for alternative and competing fuels;fuels and emissions reducing technology;
■Technological advances affecting energy consumption and supply;
■Government policies and support and market demand for low-carbon technologies;
■Domestic and foreigninternational governmental regulations and taxes;taxes, including those that restrict the export of hydrocarbons;
■Shareholder activism or activities by non-governmental organizations to restrict the exploration, development and production of oil, NGL and natural gas;
■Additional or increased nationalization and expropriation activities by foreigninternational governments;
■The impact and uncertainty of world health events, including the COVID-19 pandemic;pandemic and the spread of new variants;
■Volatility in commodity markets;
■The effect of energy conservation efforts; and
■Global inventory levels and general economic conditions.
The long-term effects of these and other conditions on the prices of oil, NGL, natural gas and refinedchemical products are uncertain and there can be no assurance that the demand or pricing for Occidental’s products will follow historic patterns or recover meaningfully in
the near-term.near term. Prolonged or substantial decline, or sustained market uncertainty, in these commodity prices may have the following effects on Occidental’s business:
■Adversely affect Occidental’s financial condition, results of operations, liquidity, ability to reduce debt, pay dividendsaccess to and cost of capital, and ability to finance planned capital expenditures, ability topay dividends and repurchase shares and results of operations;shares;
■Reduce the amount of oil, NGL and natural gas that Occidental can produce economically;
■Cause Occidental to delay or postpone some of its capital projects;
■Reduce Occidental’s revenues, operating income or cash flows;
■Reduce the amounts of Occidental’s estimated proved oil, NGL and natural gas reserves;
■Reduce the carrying value of Occidental’s oil and natural gas properties due to recognizing impairments of proved properties, unproved properties and exploration assets;
■Reduce the standardized measure of discounted future net cash flows relating to oil, NGL and natural gas reserves;
■Limit Occidental’s access to, or increase the cost of, sources of capital such as equity and long-term debt; and
■Adversely affect the ability of Occidental’s partners to fund their working interest capital requirements.
Generally, Occidental’s historical practice has been to remain exposed to the market prices of commodities. In 2019, Occidental entered into 2020 Brent-priced 3-way collars combined with 2021 call options on the same volumeAs of December 31, 2022, there were no active commodity hedges in place. Management may choose to manage its near-term exposure to cash flow variability from oil price risksput hedges in 2020. The 2021 call options were sold to enhance the upside retentionplace in 2020. In 2020, management elected to hedge a portion of Occidental’s expected 2021 natural gas production to enhance cash flow stability. In the future management may continue to hedge some of the risk offor oil, NGL and natural gas price fluctuations.commodities. Commodity price risk management activities may prevent usOccidental from fully benefiting from price increases and may expose usit to regulatory, counterparty credit and other risks.
The prices obtained for Occidental’s chemical products correlate to the healthstrength of the United States and global economies, as well as chemical industry expansion and contraction cycles. Occidental also depends on feedstocks and energy to produce chemicals, which are commodities subject to significant price fluctuations.
Occidental may experience delays, cost overruns, losses or other unrealized expectations in development efforts and exploration activities.
Oil, NGL and natural gas exploration and production activities are subject to numerous risks beyond ourOccidental’s control, including the risk that drilling will not result in commercially viable oil, NGL and natural gas production. In its development and exploration activities, Occidental bears the risks of:
■Equipment failures;
■Construction delays;
■Escalating costs or competition for services, materials, supplies or labor;
■Increasing prices as a result of broad inflation
■Property or border disputes;
■Disappointing drilling results or reservoir performance;
■Title problems and other associated risks that may affect its ability to profitably grow production, replace reserves and achieve its targeted returns;
■Actions by third-party operators of ourits properties;
■DelaysPermit delays and costs of drilling wells on lands subject to complex development terms and circumstances; and
■Oil, NGL and natural gas gathering, transportation and processing availability, restrictions or limitations.
Exploration is inherently risky and is subject to delays, misinterpretation of geologic or engineering data, unexpected geologic conditions or finding reserves of disappointing quality or quantity, which may result in significant losses.
Governmental actionsClaims, litigation, government investigations and political instabilityother proceedings may adversely affect Occidental’s business, consolidated financial position, results of operations.operations and cash flows.
Occidental’s businesses areOccidental is subject to the actionsactual and decisions of many federal, state, localthreatened claims, litigation, reviews, investigations, and foreignother proceedings, including proceedings by governments and political interests. Asregulatory authorities, involving a result, Occidental faces risks of:
■New or amended laws and regulations, or new or different applications or interpretationswide range of existing laws and regulations,issues, including those related toregarding our drilling, manufacturing or production processes, (including flaring, well stimulation techniquescommercial disputes, environmental compliance, public health and safety and taxes. The outcomes of these matters are inherently unpredictable and subject to significant uncertainties. Determining legal reserves or possible losses from such as hydraulic fracturingmatters involves judgment and acidization), pipelines, labormay not reflect the full range of uncertainties and employment, taxes, royalty rates, permitted production rates, entitlements, import, exportunpredictable outcomes. Until the final resolution of such matters, Occidental may be exposed to losses in excess of the amount recorded, and usesuch amounts could be material. Should any of raw materials, equipmentour estimates and assumptions change or products, useprove to have been incorrect, it could have a material adverse effect on Occidental’s business, consolidated financial position, results of operations and cash flows.
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Disruptions in the political, regulatory, economic, and social environments of the countries in which Occidental operates could adversely affect its reputation, financial condition, results of operations and cash flows.
Occidental’s non-US operations accounted for approximately 15% of its consolidated revenue in 2022, 16% in 2021 and 19% in 2020. Instability and unforeseen changes in any of the markets in which Occidental operates could result in business disruptions or increased use of land, water and other natural resources, safety,operational challenges that may adversely affect the manufacturing of chemicals, asset integrity management, the marketing or export of commodities, security and environmental protection, all of which may restrict or prohibit activities of Occidental or its contractors, increase Occidental’s costs or reduce demand for Occidental’s products. In addition, violationproducts and services, or its reputation, financial condition, results of certain governmental laws and regulations may result in strict, joint and several liability andoperations or cash flows. These factors include, but are not limited to, the imposition of significant civil and criminal fines and penalties;
■Refusal of, or delay in, the extension or grant of exploration, development or production contracts; and
■Development delays and cost overruns due to approval delays for, or denial of, drilling, construction, environmental and other regulatory approvals, permits and authorizations.following:
The following are examples■ Uncertain or volatile political, social, and economic conditions;
■ Social unrest, acts of actionsterrorism, war, or other armed conflict;
■ Public health crises and decisions recently taken by federalother catastrophic events, such as the COVID-19 pandemic;
■ Confiscatory taxation or other adverse tax policies;
■ Theft of, or lack of sufficient legal protection for, proprietary technology and state governments that impact Occidental’s businesses:other intellectual property;
In January 2021, the Colorado Oil■ Unexpected changes in legal and Gas Conservation Commission (COGCC) adopted new regulations that impose sitingregulatory requirements, including changes in interpretation or “setbacks” on certain oil and gas drilling locations basedenforcement of existing laws;
■ Restrictions on the distancerepatriation of a proposed well pad to occupied structures. Pursuant to the regulations, well pads cannot be located within 500 feet of an occupied structure without the consent of the property owner. As part of the permitting process, the COGCC will consider a series of siting requirements for all drilling locations located between 500 feetincome or capital;
■ Currency exchange controls;
■ Inflation; and 2,000 feet of an occupied structure. Alternatively, the operator may seek a waiver from each owner
■ Currency exchange, rate fluctuations and tenant within the designated distance. While Occidental is currently evaluating the impact of these regulations on its business, at this time, Occidental does not anticipate significant near-term changes to our development program in the DJ Basin based on these regulations. However, as a result, certain of Occidental’s proved undeveloped (PUD) reserves have been derecognized as they no longer meet the regulatory certainty criteria to be considered proved reserves. Occidental’s ability to reestablish previously derecognized PUD reserves, as well as establishing new PUD locations, will depend upon Occidental establishing a history of obtaining drilling permits under the new regulations and thus meeting the SEC’s “reasonably certain” threshold for adding PUD reserves. Occidental currently believes it will be able to successfully navigate the new setback guidelines.
An executive order was issued in January 2021, Tackling the Climate Crisis at Home and Abroad, that mandated an indefinite pause on new oil and gas leasing on federal lands, onshore and offshore, while a comprehensive review of oil and gas permitting and leasing process is conducted by the U.S. Department of the Interior. In conducting this review, the Secretary of the Interior is required to consider whether to adjust royalties associated with oil and gas resources extracted from public lands and offshore waters to account for corresponding climate costs.
In addition, effective January 20, 2021, the Department of the Interior issued an order temporarily elevating the decision-making approval previously delegated to the Department of the Interior’s agencies and bureaus, including the Bureau of Ocean Energy Management (BOEM) and the Bureau of Land Management (BLM), to issue any onshore and offshore fossil fuel authorization for, including but not limited to a lease, amendment to a lease, affirmative extension of a lease, contract or other agreement or permit to drill to the leadership of the Department of the Interior. Occidental is continuing to evaluate the overall impact of these new regulatory issuances on its oil and gas operations on federal leases.
In addition, Occidental has experienced and may continue to experience adverse consequences, such as risk of loss or production limitations, because certain of its international operations are located in countries affected by political instability, nationalizations, corruption, armed conflict, terrorism, insurgency, civil unrest, security problems, labor unrest, OPEC production restrictions, equipment import restrictions and sanctions. Exposure to such risks may increase if a greater percentage of Occidental’s future oil and gas production or revenue comes from international sources.devaluations.
Occidental’s oil and gas business operates in highly competitive environments, which affect, among other things, its ability to make acquisitions to growsource production and replace reserves.
Results of operations, reserves replacement and growth inthe level of oil and gas production depend, in part, on Occidental’s ability to profitably acquire additional reserves. Occidental has many competitors (including national oil companies), some of which: (i) are larger and better funded; (ii) may be willing to accept greater risks; (iii) have greater access to capital; (iv) have substantially larger staffs; or (v) have special competencies. Competition for access to reserves may make it more difficult to find attractive investment opportunities or require delay of reserve replacement efforts. Further, during periods of low product prices, any cash conservation efforts may delay production growth and reserve replacement efforts. Also, there is substantial competition for capital available for investment in the oil and natural gas industry. OurOccidental’s failure to acquire properties, potentially grow production, replace reserves and attract and retain qualified personnel could have a material adverse effect on ourits cash flows and results of operations.
In addition, Occidental’s acquisition activities carry risks that it may: (i) not fully realize anticipated benefits due to less-than-expected reserves or production or changed circumstances, such as declines in oil, NGL and natural gas prices; (ii) bear unexpected integration costs or experience other integration difficulties; (iii) experience share price declines based on the market’s evaluation of the activity; or (iv) be subject to liabilities that are greater than anticipated.
Occidental’s oil and gas reserves are estimates based on professional judgments and may be subject to revision.
Reported oil and gas reserves are an estimate based on periodic review of reservoir characteristics and recoverability, including production decline rates, operating performance and economic feasibility at the prevailingprescribed weighted average commodity prices, assumptions concerning future oil and natural gas prices, future operating costs and capital expenditures, workover and remedial costs, assumed effects of regulation by governmental agencies, the quantity, quality and interpretation of relevant data, taxes and availability of funds. The procedures and methods for estimating the reserves by ourOccidental’s internal engineers were reviewed by independent petroleum consultants; however, there are inherent uncertainties in estimating reserves. Actual production, revenues, expenditures, oil, NGL and natural gas prices and taxes with respect to ourOccidental’s reserves may vary from estimates and the variance may be material. Additional regulation around GHG emissions and future costs related to a less carbon-intensive economy could result in a shortened oil and gas reservoir reserve life as the underlying reserves become uneconomical. If Occidental were required to make significant negative reserve revisions, its results of operations and stock price could be adversely affected.
In addition, the discounted cash flows included in this Form 10-K should not be construed as the fair value of the reserves attributable to ourOccidental’s properties. The estimated discounted future net cash flows from proved reserves are based on an unweighted arithmetic average of the first-day-of-the-month price for each month within the year in accordance with SEC regulations. Actual future prices and costs may differ materially from SEC regulation-compliant prices and costs used for purposes of estimating future discounted net cash flows from proved reserves. Also, actual future net cash flows may differ from these discounted net cash flows due to the amount and timing of actual production, availability of financing for capital expenditures necessary to develop ourOccidental’s undeveloped reserves, supply and demand for oil, NGL and natural gas, increases or decreases in consumption of oil, NGL and natural gas and changes in governmental regulations or taxation.
Climate change and further regulation of greenhouse gas emissions may adversely affect Occidental’s operations or results.
Continuing political and social attention to the issue of climate change has resulted in both existing and pending international agreements and national, regional and local legislation and regulatory programs to reduce greenhouse gas emissions. In December 2009, the Environmental Protection Agency (EPA) determined that emissions of carbon dioxide, methane and other greenhouse gases endanger public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic changes. Based on these findings, the EPA began adopting and implementing regulations to restrict emissions of greenhouse gases under existing provisions of the Clean Air Act. The current administration has identified climate change as a priority and has issued new executive orders and regulatory actions prohibiting or restricting oil and gas development activities in certain areas. As an example in January 2021, the actions undertaken by the Department of the Interior to temporarily elevate the decision-making approval process for new fossil fuel leases or permits. In addition, the United States has re-entered the Paris Agreement, which requires countries to periodically review and represent a progression in greenhouse gas emission reduction goals and an executive order was issued, Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis. In the future, the United States may choose to adhere to other international agreements targeting greenhouse gas reductions and there may be new executive orders, regulatory actions and/or legislation targeting greenhouse gas emissions or prohibiting or restricting oil and gas development activities.
However, in the current absence of federal legislation to significantly reduce emissions of greenhouse gases to date, many state governments have established rules aimed at reducing greenhouse gas emissions, some including greenhouse gas cap and trade programs. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, including refineries and natural gas processing plants, to acquire and surrender emission allowances.
These and other government actions relating to greenhouse gas emissions could require Occidental to incur increased operating and maintenance costs including higher rates charged by service providers, costs to purchase and operate emissions control systems, to acquire emission allowances, pay carbon taxes, or comply with new regulatory or reporting requirements or prevent Occidental from conducting oil and gas development activities in certain areas, or they could promote the use of alternative sources of energy and thereby decrease demand for oil, NGL and natural gas and other products that Occidental’s businesses produce. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, oil, NGL, natural gas or other products produced by Occidental’s businesses and lower the value of its reserves. Consequently, government actions designed to reduce emissions of greenhouse gases could have an adverse effect on Occidental’s business, financial condition, results of operations, cash flows and reserves.
It is difficult to predict the timing and certainty of such government actions and their ultimate effect on Occidental, which could depend on, among other things, the type and extent of greenhouse gas reductions required, the availability and price of emission allowances or credits, the availability and price of alternative fuel sources, the energy sectors covered and Occidental’s ability to recover the costs incurred through its operating agreements or the pricing of its oil, NGL, natural gas and other products and whether service providers are able to pass increased costs through to Occidental.
There also have been efforts in the investment community, including investment advisers and certain sovereign wealth, pension and endowment funds, as well as other stakeholders, promoting divestment of fossil fuel equities and pressuring lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Such environmental activism and
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Occidental’s future results could be adversely affected if it is unable to execute new business strategies effectively.
Occidental’s results of operations depend on the extent to which it can execute new business strategies effectively relative to both the societal transition to a less carbon-intensive economy and laws, regulations and governmental and private actions regarding the environment and climate change. Occidental’s strategies seek to advance its goals of achieving net-zero emissions (i) from its operations and energy use before 2040, with an ambition to do so before 2035, and (ii) from its total carbon inventory, including the use of its sold products, with an ambition to do so before 2050. Occidental’s strategies and goals are subject to business, economic and competitive uncertainties and contingencies, many of which are beyond its control. Additionally, Occidental may be forced to develop or implement new technologies at substantial costs to achieve its strategies. Effective execution of these goals may require substantial new capital, which might not be available to Occidental in the amounts or at the times expected. In addition, raising such capital may increase its leverage or overall costs of doing business. These uncertainties and costs could cause Occidental to not be able to fully implement or realize the anticipated results and benefits of its business strategies.
Certain of Occidental’s emissions goals are dependent upon the successful implementation of new and existing technologies on an industrial scale. These technologies are in various stages of development or implementation and may require more capital, or take longer to develop, than currently expected. Further, these carbon management technologies are in competition with technologies being developed by other companies. The carbon management solutions are not well established and, while Occidental believes it has access to the technologies and the expertise necessary to develop these solutions on an industrial scale, Occidental may not ultimately succeed in achieving its GHG emissions reduction and net-zero goals.
Occidental’s strategy to include carbon management in its product line is also dependent upon demand for carbon sequestration and related CO2 removal credits, offsets or other attributes. If this market does not develop, or if the regulatory environment does not support carbon management activities, Occidental may not be successful in entering this industry.
Occidental’s aspirations, goals and initiatives aimed at limitingrelated to carbon management and overall sustainability expose it to numerous risks.
Occidental continues to develop new technologies and strategies to position it to meet its emissions reduction and net-zero goals. Occidental’s efforts to research, establish, accomplish and accurately report on our emissions goals, targets and strategies expose it to numerous operational, reputational, financial, legal and other risks. Occidental’s ability to reach our target emissions is subject to a multitude of factors and conditions, many of which are out of its control. Examples of such factors include evolving government regulation and voluntary protocols for reporting or verification of emissions, capture or sequestration, the pace of changes in technology, the successful development and deployment of existing or new technologies and business solutions on a commercial scale, the availability, timing and cost of equipment, manufactured goods and services, and the availability of requisite financing and federal and state incentive programs.
In addition, historical, current and forward-looking sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve and assumptions that are subject to change in the future. There are multiple proposed or recently adopted changes to various GHG reporting regulations and protocols, including from the EPA, as noted earlier, as well as the SEC, the GHG Protocol and certain countries and states, as well as for additional controls, fees or taxes on emissions. In March 2022, for example, the SEC proposed climate disclosure rules that would require public companies to significantly increase disclosure of GHG emissions and strategies, targets, costs and risks associated with climate change and reducing air pollution could adversely affectthe energy transition. While Occidental has reported voluntarily on its net-zero pathway and associated goals and targets, as well as GHG emissions estimates, the proposed rules would require both significant additional disclosure and integration of such disclosure directly into financial reporting processes. Occidental and numerous other stakeholders submitted comments to the SEC on the proposed rules. The SEC is expected to issue final rules in 2023. Given the potential significance of these changes for estimation, reporting and verification of GHG emissions, establishing and reporting on goals targets, and estimating and disclosing costs of emissions reduction and the energy transition, Occidental may be required or elect to modify or update reported emissions and its current set of GHG goals and targets to reflect such new or changed regulations and protocols, although we currently expect to retain our business activities, operationsoverarching net-zero goals and to continue to implement emissions reduction plans that we believe will complement our investments in DAC, CCUS and other low-carbon technologies and infrastructure.
Occidental may face increased scrutiny from the investment community, customers, other stakeholders and the media related to its emissions reduction and net-zero goals and strategies. If Occidental’s emissions goals and strategies to achieve them do not meet evolving investor or other stakeholder expectations or standards, Occidental’s reputation, ability to access capital. Such initiativesattract and retain employees and attractiveness as an investment, business partner, supplier or acquirer could cause the market value of our securitiesbe negatively impacted. Similarly, Occidental’s failure or perceived failure to decrease, our cost of capitalfulfill its emissions goals and targets, to increase and adversely affect our reputation. Finally, increasing attentioncomply with ethical, health, safety, environmental, social, governance or other standards, regulations, or expectations, or to climate change risks has resulted in an increased possibility of governmental investigations and additional private litigation against Occidental without regard to causation or our contribution to the asserted damage, which could increase our costs or otherwise adversely affect our business. Occidental has been named in certain private litigation relatingsatisfy various reporting standards with respect to these matters.matters effectively could have the same negative impacts and further expose Occidental to government enforcement actions and private litigation. Even if Occidental achieves its goals, targets and objectives, it may not realize all of the benefits that it expected at the time the goals were established.
Occidental has previously recorded impairments of its proved and unproved oil and gas properties and will continue to assess further impairments in the future.
We haveOccidental has recorded impairments of ourits proved and unproved oil and gas properties resulting from prolonged declines in oil and gas prices and may record such impairments in the future. Past impairments includeincluded pre-tax impairment and related charges to both proved and unproved oil and gas properties and a lower of cost or net realizable value adjustment for crude inventory. In 2020, Occidental recognized a pre-tax impairment to its oil and gas proved and unproved properties of $9.2 billion. If there is a worseningan adverse downturn of the macroeconomic conditions and if such worsened conditiondownturn is expected to or does persist for a prolonged period of time, Occidental’s oil and gas properties may be subject to further testing for impairment, which could result in additional non-cash asset impairments. Such impairments could be material to the financial statements.
Future costs associated with reducing emissions and carbon impacts, as well as impacts resulting from other risk factors described herein, could lead to impairments in the future, if such costs significantly increase Occidental’s businesses may experience catastrophic events.
The occurrence of events such as hurricanes, floods, droughts, earthquakes or other acts of nature, well blowouts, pandemics, fires, explosions, pipeline ruptures, chemical releases, oil releases, including maritime releases, releases into navigable waters and groundwater contamination, material or mechanical failure, industrial accidents, physical attacks, abnormally pressured or structured formations and other events that cause operations to cease or be curtailed may negatively affect Occidental’s businesses and the communities in which it operates. Coastal operations are particularly susceptible to disruption from extreme weather events. Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to us as a result of:
■Damage to and destruction of property and equipment, including property and equipment owned by third-parties which our operations rely upon;
■Damage to natural resources;
■Pollution and other environmental damage, including spillage or mishandling of recovered chemicals or fluids;
■Regulatory investigations and penalties;
■Loss of well location, acreage, expected production and related reserves;
■Suspension or delay of our operations;
■Substantial liability claims; and
■Repair and remediation costs.
Third-party insurance may not provide adequate coverage or Occidental may be self-insured with respect to the related losses. In addition, under certain circumstances, we may be liable for environmental damage caused by previous owners or operators of properties that we own, lease or operate. As a result, we may incur substantial liabilities to third parties or governmental entities for environmental matters for which we do not have insurance coverage, which could reduce or eliminate funds available for exploration, development or acquisitions or cause us to incur losses.breakeven economics.
Occidental uses CO2 for its EOR operations. Occidental’s production from these operations may decline if Occidental is not able to obtain sufficient amounts of CO2.
Occidental’s CO2 EOR operations are critical to Occidental’s long-term strategy. Oil production from Occidental’s CO2 EOR projects depends largely on having access to sufficient amounts of naturally occurring or anthropogenic (human-made) CO2. Occidental’s ability to produce oil from its CO2 EOR projects would be hindered if the supply of CO2 was limited due to, among other things, problems with current CO2 producing wells and facilities, including compression equipment, catastrophic pipeline failure or the ability to economically purchase naturally occurring or anthropogenic CO2. This could have a material adverse effect on Occidental’s financial condition, results of operations or cash flows. Future oil production from its CO2 EOR operations is dependent on the timing, volumes and location of CO2 injectionsinjection and, in particular, Occidental’s ability to obtain sufficient volumes of CO2. Market conditions may cause the delay or cancellation of the development of naturally occurring CO2 sources or construction of plants that produce anthropogenic CO2 as a byproduct that can be purchased, thus limiting the amount of CO2 available for use in Occidental’s CO2 EOR operations.
Occidental is exposed to cyber-related risks.
The oil and gas industry is increasingly dependent on digital and industrial control technologies to conduct certain exploration, development and production activities. Occidental relies on digital and industrial control systems, related
infrastructure, technologies and networks to run its business and to control and manage its oil and gas, chemicals, marketing and pipeline operations. Use of the internet, cloud services, mobile communication systems and other public networks exposes Occidental’s business and that of other third parties with whom Occidental does business to cyber attacks. Cyber attacks on businesses have escalated in recent years.
Information and industrial control technology system failures, network disruptions and breaches of data security could disrupt our operations by causing delays, impeding processing of transactions and reporting financial results, resulting inleading to the unintentional disclosure of company, partner, customer or employee information or could damage our reputation. A cyber attack involving our information or industrial control systems and related infrastructure, or that of our business associates, could negatively impact our operations in a variety of ways, including, but not limited to, the following:
■Unauthorized access to seismic data, reserves information, strategic information or other sensitive or proprietary information could have a negative impact on ourOccidental’s ability to compete for oil and natural gas resources;
■Data corruption, communication or systems interruption or other operational disruption during drilling activities could result in delays and failure to reach the intended target or cause a drilling incident;
■Data corruption, communication or systems interruption or operational disruptions of production-related infrastructure could result in a loss of production or accidental discharge;
■A cyber attack on our chemicalOxyChem’s operations could result in a disruption of the manufacturing and marketing of ourits products or a potential environmentalHSE hazard;
■A cyber attack on a vendor or service provider could result in supply chain disruptions, which could delay or halt our construction and development projects;
■A cyber attack on third-party gathering, pipeline, processing, terminal or other infrastructure systems could delay or prevent usOccidental from producing, transporting, processing and marketing ourits production;
■A cyber attack involving commodities exchanges or financial institutions could slow or halt commodities trading, thus preventing usOccidental from marketing ourits production or engaging in hedging activities;
■A cyber attack that halts activities at a power generation facility or refinery using natural gas as feedstock could have a significant impact on the natural gas market;
■A cyber attack on a communications network or power grid could cause operational disruption;
■A cyber attack on ourOccidental’s automated and surveillance systems could cause a loss in production and potential environmentalHSE hazards;
■A deliberate corruption of ourOccidental’s financial or operating data could result in events of non-compliance which could then lead to regulatory fines or penalties; and
■A cyber attack resulting in the loss or disclosure of, or damage to, ourOccidental’s or any of ourits customer’s or supplier’s data or confidential information could harm ourits business by damaging ourits reputation, subjecting usOccidental to
potential financial or legal liability and requiring usit to incur significant costs, including costs to repair or restore ourits systems and data or to take other remedial steps.
Even thoughAlthough Occidental has implemented controls and multiple layers of security that it believes are reasonable to mitigate the risks of a cyber attack, that it believes are reasonable, there can be no assurance that such cyber security measures will be sufficient to prevent security breaches of its systems from occurring, and if a breach occurs, it may remain undetected for an extended period of time. Further, Occidental has no control over the comparable systems of the third parties with whom it does business. While Occidental has experienced cyber attacks in the past, Occidental has not suffered any material losses. However, if in the future Occidental’s cyber security measures are compromised or prove insufficient, the potential consequences to Occidental’s businesses and the communities in which it operates could be significant. As cyber attacks continue to evolve in magnitude and sophistication, Occidental may be required to expend additional resources in order to continue to enhance Occidental’sits cyber security measures and to investigate and remediate any digital and operational systems, related infrastructure, technologies and network security vulnerabilities, which would increase ourits costs. A system failure or data security breach, or a series of such failures or breaches, could have a material adverse effect on ourOccidental’s financial condition, results of operations or cash flows.
Occidental’s oil and gas reserve additions may not continue at the same rate and a failure to replace reserves may negatively affect Occidental’s business.
Producing oil and natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Unless Occidental conducts successful exploration or development activities, acquires properties containing proved reserves, or both, proved reserves will generally decline and negatively impact our business. The value of ourOccidental’s securities and ourits ability to raise capital will be adversely impacted if we areit is not able to replace reserves that are depleted by production or replace our declining production with new production.production by successfully allocating annual capital to maintain our reserves and production base. Occidental expects infill development projects, extensions, discoveries and improved recovery extensions and discoveries to continue as main sources for reserve additions but factors such as geology, government regulations and permits, the effectiveness of development plans and the ability to make the necessary capital investments or acquire capital are partially or fully outside management’s control and could cause results to differ materially from expectations.
Occidental’s operations and financial results could be significantly negatively impacted by its offshore operations.
Occidental is vulnerable to risks associated with our offshore operations that could negatively impact ourits operations and financial results. Certain Occidental conductssubsidiaries conduct offshore operations primarily in the Gulf of Mexico and Ghana. Occidental’stheir operations and financial results could be significantly impacted by conditions in some of these areas and are also vulnerable to certain unique risks associated with operating offshore, including thoseconditions relating to the following:
■Hurricanes and other adverse weather conditions;
■Geological complexities and water depths associated with such operations;
■Limited number of partners available to participate in projects;
■Oilfield service costs and availability;
■Compliance with environmental, safetyHSE and other laws and regulations;
■Terrorist attacks or piracy;
■Remediation and other costs and regulatory changes resulting from oil spills, emissions or releases of hazardous substances or materials;
■Failure of equipment or facilities; and
■Response capabilities for personnel, equipment or environmental incidents.
In addition, certain Occidental conductssubsidiaries conduct some of itstheir exploration in deep waters (greater than 1,000 feet) where operations, support services and decommissioning activities are more difficult and costly than in shallower waters. The deep waters in the Gulf of Mexico, as well as international deepwaterdeep-water locations, lack the physical and oilfield service infrastructure present in shallower waters. As a result, deepwaterdeep-water operations may require significant time between a discovery and the time that Occidental can market its production, thereby increasing the risk involved with these operations.
Additional domestic and international deepwater drilling laws, regulations and other restrictions, delaysAnadarko’s Tronox settlement may not be deductible for income tax purposes; Occidental may be required to repay the tax refund Anadarko received in 2016 related to the processing and approvaldeduction of drilling permits and exploration, development, oil spill response and decommissioning plans and other offshore-related developmentsthe Tronox settlement payment, which may have a material adverse effect on Occidental’s business, financial condition or results of operations.operations, liquidity and financial condition.
In April 2014, Anadarko and Kerr-McGee entered into a settlement agreement for $5.2 billion, resolving, among other things, all claims that were or could have been asserted in connection with the May 2009 lawsuit filed by Tronox against Anadarko and Kerr-McGee in the U.S. Bankruptcy Court for the Southern District of New York. After the settlement became effective in January 2015, Anadarko paid $5.2 billion and deducted this payment on its 2015 federal income tax return. Due
BOEMto the deduction, Anadarko had a net operating loss carryback for 2015, which resulted in a tentative tax refund of $881 million in 2016.
The IRS audited Anadarko’s tax position regarding the deductibility of the payment and in September 2018 issued a statutory notice of deficiency rejecting Anadarko’s refund claim. Anadarko disagreed and filed a petition with the BureauU.S. Tax Court to dispute the disallowance in November 2018. In December 2022, the parties filed competing motions for partial summary judgment. The motions are not fully briefed. Trial is set for May 2023. Occidental expects to continue pursuing resolution. In accordance with Accounting Standards Codification (ASC) Topic 740’s guidance on the accounting for uncertain tax positions, as of Safety and Environmental Enforcement (BSEE) have imposed more stringent permitting procedures and regulatory safety and performance requirements for new wellsDecember 31, 2022, Occidental had recorded no tax benefit on the tentative cash tax refund. If the payment is ultimately determined not to be drilled in federal waters. In addition, these governmental agencies are continuingdeductible, Occidental would be required to evaluate, develop and implement new, more restrictive regulatory requirements,repay the tentative refund received plus interest totaling approximately $1.8 billion as of December 31, 2022, which could result in additional costs, delays, restrictions or obligations with respect to oil explorationhave a material adverse effect on our liquidity and production operations conducted offshore. For example, the BOEM has considered, and may adopt, supplemental bonding proceduresconsolidated balance sheets. Occidental’s Consolidated Financial Statements include an uncertain tax position for the decommissioningapproximate repayment of offshore wells, platforms, pipelines$1.4 billion ($1.4 billion federal and other facilities, which may be material. Compliance with these more stringent regulatory requirements and with existing environmental and oil spill regulations, together with any uncertainties or inconsistencies$28 million in decisions and rulingsstate taxes) plus accrued interest of approximately $415 million. This amount is not covered by governmental agencies, delaysinsurance. For additional information on income taxes, see Note 10 - Income Taxes in the processing and approvalNotes to Consolidated Financial Statements in Part II Item 8 of drilling permits or exploration, development, oil spill response and decommissioning plans and possible additional regulatory initiatives could result in difficult and more costly actions and adversely affect or delay new drilling and ongoing development efforts.this Form 10-K.
Occidental’s indebtedness may make it more vulnerable to economic downturns and adverse developments in its business. Further downgradesbusinesses. Downgrades in Occidental’s credit ratings or future increases in interest rates may negatively impact Occidental’s cost of capital, and ability to access the capital markets.
Occidental’s level of indebtedness could increase Occidental’sits vulnerability to adverse changes in general economic and industry conditions, economic downturns and adverse developments in its business and/businesses or limit Occidental’s flexibility in planning for or reacting to changes in its business and the industries in which it operates. From time to time, Occidental has relied on access to the capital markets for funding, including in connection with the Acquisition. There can be no assurance that additional debt or equity financing will be available to Occidental in the future on acceptable terms, or at all.funding. Occidental’s ability to obtain additional financing or refinancing will be subject to a number of factors, including general economic and market conditions, Occidental’s performance, investor sentiment and its ability to meet existing debt compliance requirements. If Occidental is unable to generate sufficient funds from its operations to satisfy its capital requirements, including its existing debt obligations, or to raise additional capital on acceptable terms, Occidental’s business could be adversely affected. As of December 31, 2020,the date of this filing, Occidental’s long-term debt was rated BBBB+ by Fitch Ratings, Ba2Ba1 by Moody’s Investors Service and BB-BB+ by Standard and Poor’s.
One of Occidental’s subsidiaries acts as the general partner of WES, a publicly traded master limited partnership, which may involve potential legal liability.
One of Occidental’s subsidiaries acts as the general partner of WES, a publicly traded master limited partnership. Its general partner interest in WES may increase the possibility that it could be subject to claims of breach of duties owed to WES, including claims of conflict of interest. Any additional downgrade in the credit rating of Occidentalsuch claims could negatively impact its cost of, and ability to access, capital and to effectively execute aspects of its strategy and may require Occidental to provide cash collateral, letters of credit or other forms of security under certain contractual agreements, which would increase Occidental’s operating costs and reduce liquidity. As a result, further downgrades in Occidental’s credit ratingsany liability resulting from such claims could have a material adverse impact on Occidental’s financial condition, operating results or liquidity.
Further, a portion of Occidental’s indebtedness bears interest at variable interest rates, some of which is tied to the London Interbank Offered Rate (LIBOR). In July 2017, the United Kingdom Financial Conduct Authority, which regulates LIBOR, announced that it intends to stop compelling banks to submit rates for the calculation of LIBOR after the end of 2021. In early December 2020, the administrator for LIBOR proposed, subject to market consultation, to end the publication of one week and two month USD LIBOR after December 2021 and remaining USD LIBOR tenors in mid-2023. At the same time, major U.S. bank regulators called upon banks to cease entering into new contracts that use USD LIBOR as a reference rate by the end of 2021 at the latest. The Alternative Reference Rates Committee, a group of market participants convened under the auspices of the U.S. Federal Reserve Board and other U.S. regulators, has recommended the Secured Overnight Financing Rate (SOFR), calculated based on repurchase agreements backed by treasury securities, as its recommended alternative benchmark rate to replace USD LIBOR.
However, at this time, it is not known whether or when SOFR or other proposed alternative reference rates will attain market traction as replacements for LIBOR, and the proposal to cease publication of major USD LIBOR tenors by mid-2023 is not yet final. It is not possible to predict the effect of these changes, other reforms or the establishment of alternative reference rates in the United Kingdom, the United States or elsewhere. These reforms and other pressures will likely cause LIBOR to disappear entirely or to perform differently than in the past. The consequences of these developments cannot be entirely predicted but may include an increase in the cost of Occidental’s variable rate indebtedness, including floating rate notes and interest rate swaps, which may have an adverse effect on Occidental’s financial condition, operating results or cash flows.
Anadarko’s Tronox settlement may not be deductible for income tax purposes; Occidental may be required to repay the tax refund Anadarko received in 2016 related to the deduction of the Tronox settlement payment, which may have a material adverse effect on Occidental’s results of operations, liquidity and financial condition.
In April 2014, Anadarko and Kerr-McGee Corporation and certain of its subsidiaries (collectively, Kerr-McGee) entered into a settlement agreement for $5.2 billion, resolving all claims that were or could have been asserted in connection with the May 2009 lawsuit filed by Tronox against Anadarko and Kerr-McGee in the U.S. Bankruptcy Court for the Southern District of New York. After the settlement became effective in January 2015, Anadarko paid $5.2 billion and deducted this payment on its 2015 federal income tax return. Due to the deduction, Anadarko had a net operating loss carryback for 2015, which resulted in a tentative tax refund of $881 million in 2016.
The IRS has audited Anadarko’s tax position regarding the deductibility of the payment and in September 2018 issued a statutory notice of deficiency rejecting Anadarko’s refund claim. Anadarko disagreed and filed a petition with the U.S. Tax Court to dispute the disallowance in November 2018. The case was in the IRS appeals process until the second quarter of 2020; however, it has since been returned to the U.S. Tax Court where Occidental expects to continue pursuing resolution. In accordance with Accounting Standards Codification (ASC) Topic 740’s guidance on the accounting for uncertain tax positions, as of December 31, 2020, Occidental has recorded no tax benefit on the tentative cash tax refund. If the payment is ultimately determined not to be deductible, Occidental would be required to repay the tentative refund received plus interest totaling approximately $1.2 billion as of December 31, 2020, which could have a material adverse effect on our liquidity and consolidated balance sheets. Occidental’s consolidated financial statements include an uncertain tax position for the tentative cash tax refund ($898 million in federal taxes and $27 million in state taxes) plus accrued interest of approximately $255 million. This amount is not covered by insurance. For additional information on income taxes, see Note 11 - Lawsuits, Claims, Commitments and Contingencies in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K.
Occidental may not be able to complete its planned divestitures of certain assets on favorable terms or at all.
Since the Acquisition, Occidental has realized $8.2 billion of after-tax net proceeds from significant asset divestitures. The completion of any future divestitures will be subject to customary closing conditions, and certain of the divestitures may be conditioned on the receipt of required government and regulatory approvals. Occidental may not be able to complete its planned divestitures on favorable terms, in a timely manner or at all. Any difficulties with respect to the completion of the planned divestitures could have a material adverse effect on Occidental’s business, financial condition, results of operations, cash flows and/or stock price. See Note 4 - Divestitures and Other Transactions in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for information about the Total transaction.
Occidental’s future results could be adversely affected if it is unable to execute new business strategies effectively.
Occidental’s results of operations depend on the extent to which it can execute new business strategies effectively. Occidental’s strategies, which include reaching net-zero emissions with its operations before 2040, are subject to business, economic and competitive uncertainties and contingencies, many of which are beyond its control. Additionally, Occidental may be forced to develop or implement new technologies at substantial costs to achieve its strategies. These uncertainties and costs could cause Occidental to not be able to fully implement or realize the anticipated results and benefits of its business strategies.
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.
ITEM 3. LEGAL PROCEEDINGS
Occidental has elected to use a $1 million threshold for disclosing certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party and potential monetary sanctions are involved. Occidental believes proceedings under this threshold are not material to Occidental's business and financial condition. In January 2023, the U.S. District Court for the District of New Mexico entered a consent decree under which two Occidental subsidiaries settled a previously-reported citizen suit alleging violations of certain federal air quality regulations, which the subsidiaries deny, by paying a civil penalty of $500,000 to the U.S. Department of the Treasury and depositing an additional $500,000 with the U.S. District Court for the District of New Mexico to fund a supplemental environmental project in lieu of penalties, among other terms. For information regarding other legal proceedings, see the information under Lawsuits, Claims, Commitments and Contingencies in the Management’s Discussion and Analysis section of this Form 10-K and in Note 1113 - Lawsuits, Claims, Commitments and Contingencies in the Notes to Consolidated Financial Statements.Statements in Part II Item 8 of this Form 10-K.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
| | |
INFORMATION ABOUT OUR EXECUTIVE OFFICERS |
Each executive officer holds his or her office from the date of election by the Board of Directors until the first board meeting held after the next Annual Meeting of Stockholders or until his or her removal or departure or a successor is duly elected, if earlier.
The following table sets forth the executive officers of Occidental as of February 26, 2021:27, 2023:
| | | | | | | | |
Name Current Title | Age atas of February 26, 202127, 2023 | Positions with Occidental and Employment History |
|
Marcia E. Backus
Senior Vice President,
General Counsel and Chief Compliance Officer
| 66 | Senior Vice President, General Counsel and Chief Compliance Officer since December 2016; Senior Vice President, General Counsel, Chief Compliance Officer and Corporate Secretary, 2015-2016; Vice President, General Counsel and Corporate Secretary, 2014-2015; Vice President and General Counsel, 2013-2014; Vinson & Elkins: Partner, 1990-2013. |
Peter J. Bennett Vice President | 5355 | Vice President since 2016 and President, Commercial Development U.S. Onshore Resources and Carbon Management since October 2020; President and General Manager of Permian Resources and the Rockies, 2020; Senior Vice President, Permian Resources, 2018-2020; President and General Manager - Permian Resources New Mexico, 2017-2018; Chief Transformation Officer, 2016-2017; Vice President Operations Planning & Portfolio Management, 2016; Vice President Operations Portfolio & Integrated Planning, 2015-2016; Vice President Operations Planning & Optimization, 2014-2015.2016-2017. |
Christopher O. Champion Vice President, Chief Accounting Officer and Controller | 5153 | Vice President, Chief Accounting Officer and Controller since August 2019; Anadarko Petroleum Corporation: Senior Vice President, Chief Accounting Officer and Controller, 2017-2019;2017-2019, Vice President, Chief Accounting Officer and Controller, 2015-2017; KPMG LLP: Audit Partner, 2003-2015.2015-2017. |
Kenneth Dillon Senior Vice President | 6163 | Senior Vice President since December 2016; President -– International Oil and Gas Operations since June 2016; Senior Vice President - Operations and Major Projects, 2014-2016; Senior Vice President - Major Projects, 2012-2014.2016. |
Vicki Hollub President and Chief Executive Officer | 6163 | President, Chief Executive Officer and Director since April 2016; President, Chief Operating Officer and Director, 2015-2016; Senior Executive Vice President and President, Oxy Oil and Gas, 2015; Executive Vice President and President Oxy Oil and Gas - Americas, 2014-2015; Vice President and Executive Vice President, U.S. Operations, Oxy Oil and Gas, 2013-2014.2016. |
Richard A. Jackson Senior Vice President | 4547 | Senior Vice President since November 2020; President Operations U.S. Onshore Resources and Carbon Management since October 2020; President and General Manager, EOR and Oxy Low Carbon Ventures, LLC, 2020; President Low Carbon Venture,Ventures, 2019-2020; Senior Vice President, Operation Support, 2018-2019; Vice President, Investor Relations, 2017-2018; President and General Manager Permian Resources Delaware Basin, 2014-2017;2014-2017. |
Sylvia J. Kerrigan Senior Vice President and Chief Legal Officer | 57 | Senior Vice President and Chief Legal Officer since October 2022; Executive Director of Drilling Americas, 2011-2014.the Kay Bailey Hutchison Energy Center for Business, Law and Policy at The University of Texas, 2017-2022; Executive Vice President, General Counsel and Corporate Secretary of Marathon Oil Corporation, 2009-2017. |
Robert L. Peterson Senior Vice President and Chief Financial Officer | 5052 | Senior Vice President and Chief Financial Officer since April 2020; Senior Vice President, Permian EOR, 2019-2020; Vice President Permian Strategy, 2018-2019; Director Permian Business Area, 2017-2018; President OxyChem, 2014-2017. |
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OXY 20202022 FORM 10-K | 1521 |
Part II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
| | |
| MARKET INFORMATION, HOLDERS AND DIVIDEND POLICY |
Occidental’s common stock is listed and traded on the New York Stock ExchangeNYSE under the ticker symbol “OXY.” The common stock was held by approximately 28,20024,400 stockholders of record atas of January 31, 2021,2023, which does not include beneficial owners for whom Cede and Co. or others act as nominees.
Occidental’s current annualizedOccidental declared dividends of $0.52 per share for the year ended December 31, 2022. In February 2023, the Board of Directors declared a regular quarterly dividend rate is $0.04of $0.18 per share.share on common stock, an increase of five cents from the previous quarter, payable in April 2023. The declaration of future dividends is a business decision made by the Board of Directors from time to time and will depend on Occidental’s financial condition and other factors deemed relevant by the Board.Board of Directors.
| | |
| SHARE REPURCHASE ACTIVITIES |
Occidental’s share repurchase activities for the year ended December 31, 2020,2022, were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Total
Number
of Shares Purchased | (a) | Average
Price
Paid
per Share | | Total Number of Shares Purchased as Part of Publicly Announced
Plans or Programs | | Maximum Number of Shares that May Yet Be Purchased Under the
Plans or Programs |
| First Quarter 2020 | | — | | | | | $ | — | | | — | | | | | |
| Second Quarter 2020 | | 157,808 | | | | | $ | 24.40 | | | — | | | | | |
| Third Quarter 2020 | | — | | | | | $ | — | | | — | | | | | |
| October 1 - 31, 2020 | | — | | | | | $ | — | | | — | | | | | |
| November 1 - 30, 2020 | | 164,077 | | | | | $ | 12.70 | | | — | | | | | |
| December 1 - 31, 2020 | | 313,698 | | | | | $ | 17.65 | | | — | | | | | |
| Fourth Quarter 2020 | | 477,775 | | | | | $ | 15.95 | | | — | | | | | |
| Total 2020 | | 635,583 | | | | | $ | 18.05 | | | — | | | | 44,206,787 | | (b) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Total
Number
of Shares Purchased | (a) | Average
Price
Paid
per Share | | Total Number of Shares Purchased as Part of Publicly Announced
Plans or Programs | | Maximum Value of Shares that May Yet Be Purchased Under the
Plans or Programs | (b) |
| First Quarter 2022 | | 730,746 | | | | $ | 50.05 | | | — | | | $ | 3,000 | | |
| Second Quarter 2022 | | 11,679,732 | | | | 58.38 | | | 11,190,640 | | | | 2,350 | | |
| Third Quarter 2022 | | 28,571,576 | | | | 63.02 | | | 28,409,099 | | | | 562 | | |
| October 1 - 31, 2022 | | 2,330,221 | | | | 67.35 | | | 2,205,352 | | | | 414 | | |
| November 1 - 30, 2022 | | 5,993,013 | | | | 70.68 | | | 5,859,478 | | | | — | | |
| December 1 - 31, 2022 | | — | | | | — | | | — | | | | — | | |
| Fourth Quarter 2022 | | 8,323,234 | | | | 69.75 | | | 8,064,830 | | | | — | | |
| Total 2022 | | 49,305,288 | | | | 62.86 | | | 47,664,569 | | | | — | | |
(a)All 2020Included purchases wereof 1,640,719 shares from the trustee of Occidental’sOccidental's defined contribution savings plan.plan that are not part of publicly announced plans or programs.
(b)RepresentsRepresented the total numbervalue remaining in Occidental's share repurchase plan. In February 2022, Occidental announced an authorization to repurchase up to $3.0 billion of Occidental's shares remaining at year end under Occidental’sof common stock. The plan was completed in the fourth quarter of 2022. In February 2023, the Board authorized a new share repurchase program of 185 million shares. The program was initially announced in 2005. The program does not obligate Occidentalup to acquire any specific number$3.0 billion of Occidental’s shares and may be discontinued at any time.of common stock.
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1622 | OXY 20202022 FORM 10-K |
The following graph compares the yearly percentage change in Occidental’s cumulative total return on its common stock with the cumulative total return of the Standard & Poor’sS&P 500, Stock Index (S&P 500), which includes Occidental, with that of Occidental’s peer group over the five-year period ended December 31, 2020.2022. The graph assumes that $100 was invested at the beginning of the five-year period shown in the graph below and that all dividends were reinvested in: (i) Occidental common stock, (ii) the stock of the companies in the S&P 500 and (iii) each of the peer group companies’ common stock weighted by their relative market capitalization within the peer group and that all dividends were reinvested. The cumulative total return of the peer group companies’ common stock includes the cumulative total return of Occidental’s common stock.group.
Occidental’s peer group consists of BP p.l.c., Chevron Corporation, ConocoPhillips, EOG Resources, Inc., ExxonMobil Corporation, Royal Dutch Shell, plc, Total S.A. and Occidental.TotalEnergies.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Fiscal Year Ended December 31, | 2015 | | 2016 | | 2017 | | 2018 | | 2019 | | 2020 |
| Occidental | $ | 100 | | | $ | 110 | | | $ | 119 | | | $ | 104 | | | $ | 75 | | | $ | 35 | |
| Peer Group | $ | 100 | | | $ | 125 | | | $ | 139 | | | $ | 127 | | | $ | 136 | | | $ | 90 | |
| S&P 500 | $ | 100 | | | $ | 112 | | | $ | 136 | | | $ | 130 | | | $ | 171 | | | $ | 203 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Fiscal Year Ended December 31, | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | 2022 |
| Occidental | $ | 100 | | | $ | 87 | | | $ | 62 | | | $ | 29 | | | $ | 49 | | | $ | 107 | |
| Peer Group | $ | 100 | | | $ | 92 | | | $ | 98 | | | $ | 65 | | | $ | 96 | | | $ | 149 | |
| S&P 500 | $ | 100 | | | $ | 96 | | | $ | 126 | | | $ | 149 | | | $ | 191 | | | $ | 157 | |
The information provided in this Performance Graph shall not be deemed “soliciting material” or “filed” with the SEC or subject to Regulation 14A or 14C under the Exchange Act, other than as provided in Item 201 to Regulation S-K under the Exchange Act, or subject to the liabilities of Section 18 of the Exchange Act and shall not be deemed incorporated by reference into any filing under the Securities Act of 1933 or the Exchange Act except to the extent Occidental specifically requests that it be treated as soliciting material or specifically incorporates it by reference.
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OXY 20202022 FORM 10-K | 1723 |
ITEM 6. SELECTED FINANCIAL DATA
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions, except per-share amounts | 2020 | | 2019 (a) | | 2018 | | 2017 | | 2016 |
RESULTS OF OPERATIONS (b) | | | | | | | | | |
| Net sales | $ | 17,809 | | | $ | 20,911 | | | $ | 17,824 | | | $ | 12,508 | | | $ | 10,090 | |
| Income (loss) from continuing operations | $ | (13,533) | | | $ | (507) | | | $ | 4,131 | | | $ | 1,311 | | | $ | (1,002) | |
| Net income (loss) attributable to common stockholders | $ | (15,675) | | | $ | (985) | | | $ | 4,131 | | | $ | 1,311 | | | $ | (574) | |
| Net income (loss) from continuing operations attributable to common stockholders - basic per common share | $ | (15.65) | | | $ | (1.20) | | | $ | 5.40 | | | $ | 1.71 | | | $ | (1.31) | |
| Net income (loss) attributable to common stockholders - basic per common share | $ | (17.06) | | | $ | (1.22) | | | $ | 5.40 | | | $ | 1.71 | | | $ | (0.75) | |
| Net income (loss) attributable to common stockholders - diluted per common share | $ | (17.06) | | | $ | (1.22) | | | $ | 5.39 | | | $ | 1.70 | | | $ | (0.75) | |
| | | | | | | | | |
FINANCIAL POSITION (b) | | | | | | | | | |
| Total assets | $ | 80,064 | | | $ | 107,190 | | | $ | 42,159 | | | $ | 42,026 | | | $ | 43,109 | |
| Long-term debt, net | $ | 35,745 | | | $ | 38,537 | | | $ | 10,201 | | | $ | 9,328 | | | $ | 9,819 | |
| Stockholders’ equity | $ | 18,573 | | | $ | 34,232 | | | $ | 21,330 | | | $ | 20,572 | | | $ | 21,497 | |
| | | | | | | | | |
MARKET CAPITALIZATION (c) | $ | 16,124 | | | $ | 36,846 | | | $ | 45,998 | | | $ | 56,357 | | | $ | 54,437 | |
| | | | | | | | | |
| CASH FLOW FROM CONTINUING OPERATIONS | | | | | | | | | |
| Operating: | | | | | | | | | |
| Cash flow from continuing operations | $ | 3,842 | | | $ | 7,336 | | | $ | 7,669 | | | $ | 4,861 | | | $ | 2,520 | |
| Investing: | | | | | | | | | |
| Capital expenditures | $ | (2,535) | | | $ | (6,367) | | | $ | (4,975) | | | $ | (3,599) | | | $ | (2,717) | |
| Payments for purchases of assets and businesses | $ | (114) | | | $ | (28,088) | | | $ | (928) | | | $ | (1,064) | | | $ | (2,044) | |
| Sales of assets, net | $ | 2,281 | | | $ | 6,143 | | | $ | 2,824 | | | $ | 1,403 | | | $ | 302 | |
| Cash provided (used) by all other investing activities, net | $ | (410) | | | $ | (540) | | | $ | (127) | | | $ | 181 | | | $ | (284) | |
| Financing: | | | | | | | | | |
| Cash dividends paid | $ | (1,845) | | | $ | (2,624) | | | $ | (2,374) | | | $ | (2,346) | | | $ | (2,309) | |
| Purchases of treasury stock | $ | (12) | | | $ | (237) | | | $ | (1,248) | | | $ | (25) | | | $ | (22) | |
| Proceeds from long-term debt, net - Occidental | $ | 6,936 | | | $ | 21,557 | | | $ | 978 | | | $ | — | | | $ | 4,203 | |
| Payment of long-term debt, net - Occidental | $ | (8,916) | | | $ | (6,959) | | | $ | (500) | | | $ | — | | | $ | (2,710) | |
| Proceeds from issuance of common and preferred stock | $ | 134 | | | $ | 10,028 | | | $ | 33 | | | $ | 28 | | | $ | 36 | |
| Cash provided (used) by all other financing activities, net | $ | (805) | | | $ | 431 | | | $ | 9 | | | $ | — | | | $ | — | |
| | | | | | | | | |
| DIVIDENDS PER COMMON SHARE | $ | 0.82 | | | $ | 3.14 | | | $ | 3.10 | | | $ | 3.06 | | | $ | 3.02 | |
| | | | | | | | | |
| WEIGHTED-AVERAGE BASIC SHARES OUTSTANDING | 919 | | | 810 | | | 762 | | | 765 | | | 764 | |
(a)Summary financial information included the impact of the Acquisition, see Note 3 - The Acquisition in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K. Summary results of operations from the date of the Acquisition to December 31, 2019 included the results of WES, a previously consolidated subsidiary. See Note 1 - Summary of Significant Accounting Policies in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K.
(b)See the MD&A section of this report and the Notes to Consolidated Financial Statements for information regarding acquisitions and dispositions, discontinued operations and other charges affecting comparability.
(c)Market capitalization is calculated by multiplying the year-end total shares of common stock issued, less shares held as treasury stock, by the year-end closing stock price.
| | | | | | | | |
| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (MD&A)
The following discussion should be read together with the Consolidated Financial Statements and the Notes to Consolidated Financial Statements, which are included in this Form 10-K in Item 8 and the information set forth in Risk Factors under Part 1, Item 1A. The following sections include a discussion of results for fiscal 2022 compared to fiscal 2021 as well as certain 2020 results. The comparative results for fiscal 2021 with fiscal 2020 generally have not been included in this Form 10-K, but may be found in “Part II - Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.
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| INDEX | PAGE |
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| Income Taxes | |
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Commitments and Obligations | |
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| 24 | OXY 20202022 FORM 10-K | 19 |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
| | |
| CURRENT BUSINESS OUTLOOK AND STRATEGY |
GENERAL
Occidental’s operations, financial condition, cash flows and levels of expenditures are highly dependent on oil prices and, to a lesser extent, NGL and natural gas prices, the Midland-to-Gulf-Coast oil spreads, chemical product prices and inflationary pressures in the macro-economic environment. In 2022, as compared to 2021, the average annual price per barrel of WTI crude increased to $94.23 from $67.91 and the prices it receives foraverage annual Brent price per barrel increased to $98.83 from $70.78. The return of oil demand to its chemical products. The worldwide economy has been severely impacted bypre-pandemic levels, the ongoing effectsglobal impact of the COVID-19 pandemic, which began duringRussia-Ukraine war and the first quarterlimited increase in supply in 2022 have resulted in an increase in benchmark oil prices year-over-year. Occidental does not operate or own assets in either Russia or Ukraine. It is expected that the price of 2020. Inoil will be volatile for the first quarter, travel restrictions and stay-at-home orders were implemented for muchforeseeable future given the current geopolitical risks, the ongoing global impact of the worldRussia-Ukraine war, and uncertainty around the global economy, oil demand in China as it emerges from its zero-COVID policy, production levels in OPEC and non-OPEC oil producing countries and further releases from or additions to limit the spreadUS Strategic Petroleum Reserve.
Occidental works to manage inflation impacts by capitalizing on operational efficiencies, locking in pricing on longer term contracts and working closely with vendors to secure the supply of COVID-19. Though certain restrictions have been lifted, some areas have recently reinstated stay at home orders andcritical materials. As of December 31, 2022, substantially all of Occidental's outstanding debt is fixed rate.
STRATEGY
Occidental is focused on delivering a unique shareholder value proposition with its portfolio of oil and gas, demand remains below pre-pandemic levels. On April 12, 2020, certain memberschemicals and midstream and marketing assets and its ongoing development of the OPECcarbon management and 10 non-OPEC partner countries (OPEC+) agreedstorage solutions and GHG emissions reduction efforts. Occidental conducts its operations with a priority on HSE, sustainability and social responsibility. Occidental aims to production cuts intended to mitigate the oil supply and demand imbalance to stabilize prices. On January 5, 2021, OPEC+ agreed to extend the cutsmaximize shareholder returns through March 2021. These production cuts coupled with declining U.S. production helped mitigate the supply and demand imbalance. While the spot WTI oil price has recovered to above $60.00/Bbl as of the date of this filing, the average daily WTI oil price fell from $57.03/Bbl in 2019 to $39.40/Bbl in 2020 or 31 percent. We expect that the oil supply and demand balance and consequently oil prices in the near-term will continue to be influenced by the duration and severity of the COVID-19 pandemic; the effectiveness and pace of the distribution of the recently approved vaccines; and OPEC+ and U.S. production levels.
LIQUIDITY
In response to the dramatic drop in oil prices and the current macroeconomic environment, Occidental has taken significant measures to increase its near and mid-term liquidity and address near-term debt maturities. Specifically, during 2020 Occidental:a combination of:
■Reduced its 2020Returning capital budget to $2.6 billion fromshareholders, while redeeming a rangeportion of $5.2 billionpreferred equity to $5.4 billion, a midpoint reduction of approximately 50%;continue improving Occidental’s financial position;
■Made significant cuts toEnhancing its 2020 operatingexisting asset base with new investments in its core cash-generative oil and corporate costs. On an annualized basis, Occidental has realized $1.5 billion of overhead savingsgas and over $900 million in operating cost savings, of whichchemical businesses as well as emerging low-carbon businesses with a majority is expected to remain permanent in future years;focus on its net-zero pathway;
■Reduced the quarterly common stock dividendAdvancing technologies and business solutions to $0.01 per share from $0.79 per share, effective July 2020, which on an annualized basis, will reduce its common stock dividend outlay by approximately $2.9 billion;
■Elected to pay the preferred stock dividend paid in the second and third quarters of 2020 in the form of shares of common stock, in lieu of cash, preserving $400 million of liquidity. Occidental elected to pay the dividend paid in the fourth quarter in cash. The Board of Directors will continue to assess market conditions and Occidental's financial condition onhelp drive a quarterly basis to determine whether the preferred stock dividend will be paid in shares of stock, in cash or a combination of shares of common stock and cash;
■Entered into a new receivable securitization facility that provides additional liquidity of up to $400 million;
■Issued $7.0 billion in senior unsecured notes (the Senior Notes Offerings) during 2020 to extend certain debt maturities in 2021-2023 to 2025-2031;
■Since the Acquisition, completed significant asset divestitures for net proceeds of approximately $8.2 billion;
■Used the net proceeds from asset sales, cash on hand and Senior Notes Offerings to retire or tender $6.0 billion of 2021, $2.7 billion of 2022 and $264 million of 2023 maturities;sustainable low-carbon future; and
■Exchanged approximately 27.9 million WES common units to retire a $260 million note payable to WES due 2038.Further reducing long-term financial leverage.
In 2019,OPERATIONAL EXCELLENCE AND CAPITAL EFFICIENCY
Occidental's operational priorities for 2022 were to maximize operational efficiencies by investing $4.5 billion in high return assets to generate long-term sustainable free cash flow that will provide cash flow stability throughout the commodity cycle. Occidental
entered into three-way oil collarset new operational records and
call derivative instrumentsefficiency benchmarks in the Permian, Rockies, Gulf of Mexico, Oman and UAE. OxyChem generated record earnings, beating its previous record set in 2021. With the increase in commodity prices and Occidental’s focus on its operational efficiencies, Occidental’s higher cash flow allowed it to reduce its
exposure to commodity price riskleverage and
increase the predictability of near-term cash flows. The majority of the collars settled in 2020 with the receipt of cash of $960 million. The remaining $52 million settled in 2021. See Note9 - Derivatives in the Notes to Consolidated Financial Statements in Part II, Item 8 of this Form 10-K. Occidental believes the actions outlined above enhanceadvance its liquidity position to fund its operations. Occidental will continue to evaluate the economic environment, as well as the commodity price environment, and may make further adjustments to its future levels of expenditures and operating and corporate costs. However, the ultimate impact of the COVID-19 pandemic on Occidental's results of operations, cash flows and financial position are unknown, and those impacts could be material. Additionally, actions taken in response to the current macro-environment may result in the long-term reduction of its capital expenditure and production profile.shareholder return framework.
DEBT AND INTEREST RATE SWAPS
With the completion of the liquidity measures above,Strong cash flow in 2022 allowed Occidental to continue its deleveraging efforts. In 2022, Occidental reduced its debt principal by more than $10.5 billion, leaving less than $18.0 billion outstanding as of the dateDecember 31, 2022, and meeting its near-term debt reduction goal. As of this filing,December 31, 2022, Occidental hashad debt maturities of approximately $371$22 million in 2021, $2.12023, $1.1 billion in 20222024 and $0.9$1.2 billion in 2025. The current maturity of $22 million was paid in January 2023, leaving no debt maturing in 2023.
Occidental’s $2.3 billion$673 million Zero Coupon senior notes due 2036 (Zero Coupons)Coupons can be put to Occidental in October of each year, in whole or in part, for the then accreted value of the outstanding Zero Coupons. An immaterial amount was put
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
to Occidental in 2020. The Zero Coupons can next be put to Occidental in October 2021,2023, which, if put in whole, would require a payment of approximately $1.0 billion$344 million at such date. Occidental currently has the intent and ability to meet this obligation, including, if necessary, using amounts available under the revolving credit facility (RCF)RCF should the put right be exercised.
InterestIn the year ended December 31, 2022, Occidental settled all outstanding interest rate swaps with a notional value$255 million in cash and the application of $750$144 million and fair value of $894 million,collateral, leaving none outstanding as of December 31, 2020, have mandatory termination dates in September 2021. Interest rate swaps with a notional value of $725 million and fair value of $876 million, as of December 31, 2020, have mandatory termination dates in September 2022 and 2023. The interest rate swaps fair value, and cash required to settle them on their termination dates, will continue to fluctuate with changes in interest rates through the mandatory termination dates.2022.
As of December 31, 2020, Occidental had approximately $2.0 billion of cash and cash equivalents on hand.
DEBT RATINGS
As of the date of this filing, $5.0 billion of borrowing capacity under its existing RCF, which matures in 2023. Occidental continues to pursue divestitures of certain assets and intends to use the net proceeds from asset sales and excess free cash flow to repay its nearer-term debt maturities, but the expected timing and final proceeds from such asset sales are uncertain. Occidental currently expects its cash on hand and funds available under its RCF to be sufficient to meet its debt maturities, operating expenditures and other obligations for the next 12 months from the date of this filing. However, given the inherent uncertainty associated with the duration and severity of the COVID-19 pandemic and its resulting impact on oil demand, Occidental may need to raise capital to fund its operations and refinance debt maturities.
DEBT RATINGS
In connection with the Senior Notes Offerings, Occidental's long-term debt credit ratings were reviewed by the three major rating agencies. As of December 31, 2020, Occidental’s long-term debt was rated BBBB+ by Fitch Ratings, Ba2Ba1 by Moody’s Investors Service and BB-BB+ by Standard and Poor’s. Occidental believes the deleveraging performed to date may lead to future ratings upgrades, but cannot determine the timing of any potential ratings change. Any additional downgrade in credit ratings could impact Occidental's ability to access capital markets and increase its cost of capital. In addition, given that Occidental’s current debt ratings are non-investment grade debt rating may require Occidental may be requested, and in some cases required,or its subsidiaries to provide collateralfinancial assurance in the form of cash, letters of credit, surety bonds or other acceptable support as financial assurance of its performance and payment obligations under certain contractual arrangements such as pipeline transportation contracts, environmental remediation obligations, oil and gas purchase contracts and certain derivative instruments.
As of the date of this filing, Occidental has provided required financial assurances through a combination of cash, letters of credit and surety bonds and has not issued any letters of credit under the RCF or other committed facilities. For additional information, see Risk Factors in Part I, Item 1A of this Form 10-K.arrangements.
IMPACT OF COVID-19 PANDEMIC TO GLOBAL OPERATIONS
Occidental is focused on protecting the health and safety of its employees and contractors during the COVID-19 pandemic. Occidental has implemented workplace restrictions in our offices and work sites for health and safety reasons. Occidental has not incurred material costs as a result of new protocols and procedures. Occidental continues to monitor national, state and local government directives where Occidental has operations and/or offices. While Occidental has not incurred any significant disruptions to its day-to-day operations as a result of any workplace restrictions related to the COVID-19 pandemic to date, the extent to which the COVID-19 pandemic adversely affects our business, results of operations and financial condition will depend on future developments, which are highly uncertain.
RECENT GOVERNMENTAL RULE MAKING AND EXECUTIVE ORDERS
In January 2021, the COGCC adopted new regulations that impose siting requirements or “setbacks” on certain oil and gas drilling locations based on the distance of a proposed well pad to occupied structures. Pursuant to the regulations, well pads cannot be located within 500 feet of an occupied structure without the consent of the property owner. As part of the permitting process, the COGCC will consider a series of siting requirements for all drilling locations located between 500 feet and 2,000 feet of an occupied structure. Alternatively, the operator may seek a waiver from each owner and tenant within the designated distance. While Occidental is currently evaluating the impact of these regulations on its business, at this time, Occidental does not anticipate significant near-term changes to our development program in the DJ Basin based on these regulations. However, as a result certain of Occidental’s PUD reserves have been derecognized as they no longer meet the regulatory certainty criteria to be considered proved reserves. Occidental’s ability to reestablish previously derecognized PUD reserves, as well as establishing new PUD locations will depend upon Occidental establishing a history of obtaining drilling permits under the new regulations and thus meeting the SEC’s “reasonably certain” threshold for adding PUD reserves. Occidental currently believes it will be able to successfully navigate the new setback guidelines.
An executive order was issued in January 2021, Tackling the Climate Crisis at Home and Abroad, that mandated an indefinite pause on new oil and gas leasing on federal lands, onshore and offshore, while a comprehensive review of oil and gas permitting and leasing is conducted by the U.S. Department of the Interior. In conducting this review, the Secretary of the Interior shall consider whether to adjust royalties associated with oil and gas resources extracted from public lands and offshore waters to account for corresponding climate costs.
In addition, effective January 20, 2021, the Department of the Interior issued an order temporarily elevating the decision-making approval previously delegated to the Department of the Interior’s agencies and bureaus, including the BOEM and the BLM, to issue any onshore and offshore fossil fuel authorization for, including but not limited to a lease,
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
SHAREHOLDER RETURN FRAMEWORK
amendmentCapital is returned to shareholders through Occidental’s dividend and share repurchases. Occidental’s current dividend is $0.18 per share per quarter, or $0.72 on an annualized basis. During the fourth quarter of 2022, Occidental completed its $3.0 billion share repurchase program. In February 2023, the Board authorized a lease, affirmative extensionnew share repurchase program of up to $3.0 billion of Occidental’s shares of common stock. Occidental anticipates that a lease, contract or other agreement or permithigher percentage of excess free cash flow is expected to drillbe allocated to shareholder returns in 2023 with the leadershipintention to begin redeeming the preferred stock. Occidental’s preferred stock includes a mandatory redemption provision that obligates Occidental to redeem the preferred at 110% of the Department ofpar value on a dollar-for-dollar basis for every dollar distributed to common shareholders above $4.00 per share, on a trailing 12-month basis.
SUSTAINABILITY AND ENVIRONMENTAL STEWARDSHIP STRATEGY
In 2020, Occidental was the Interior.
Neither of these orders impact existing operations or permits for ongoing operations under valid leases and does not preclude the issuances of leases, permits and other authorizations. Both of these orders align with the new governmental administration’s commitment to addressing climate change, specifically both orders allow for the Department of the Interior to consider potential climate and other impacts associated withfirst U.S. oil and gas activities on public lands or in offshore waters.
Approximately 9%company to announce goals to achieve net-zero GHG emissions for its total emissions inventory including use of Occidental’s onshore net acres are on federal lands while allsold products. These goals include achieving net-zero GHG emissions (i) from its operations and energy use before 2040, with an ambition to do so before 2035, and (ii) from its total carbon inventory, including the use of its Gulf of Mexico leases are in federal waters.
sold products, with an ambition to do so before 2050. In 2020, Occidental is continuing to evaluatealso set various interim targets, including 2025 carbon and methane intensity targets, and Occidental was the overall impact of these new regulatory issuances on itsfirst U.S. oil and gas operationscompany to endorse the World Bank’s initiative for zero routine flaring by 2030. In 2022, the Board of Directors adopted Occidental’s updated HSE and Sustainability Principles, based on federal leases and will reallocate capital to non-federal leases to the extent there are delays in obtaining permitsengagement with shareholders, employees and other authorizations that would alterstakeholders. The Principles reinforce the timing ofalignment among Occidental’s core values, goals and strategies, underpin our operational management system, and help to guide our workforce across our businesses.
Occidental seeks to meet its sustainability and environmental goals through its development and exploration programs on federal leases.
commercialization of technologies that lower both GHG emissions from industrial processes and existing atmospheric concentrations of CO
STRATEGY
. Occidental is focused on deliveringbelieves that carbon removal technologies, including DAC and CCUS, can, with incentives necessary for their development and deployment, provide essential CO2 reductions to assist the world’s transition to a unique shareholder value proposition withless carbon-intensive economy. During 2022, Occidental undertook the following actions, among others, toward advancing its combined integrated asset portfolio, continual enhancements to its organizational capability and commitment to implement innovative carbon management and storage solutions for the reduction of greenhouse gas emissions. Occidental conducts its operations with a focus on sustainability, health, safety and environmental and social responsibility. Capital is employed to operate all assets in a safe and environmentally sound manner. Occidental aims to maximize shareholder returns through a combination of:low-carbon strategy:
■Maximizing capital efficiency to sustain fourth quarter 2020 production levels in order to maximize free cash flow;Achieved zero routine flaring of gas across its U.S. oil and gas operations, 8 years ahead of the World Bank’s 2030 target;
■Prioritizing projects to decrease its carbon footprint and create a business model to help other companies lower theirs;Reduced estimated methane emissions by 33% from the 2020 baseline;
■Reducing financial leverage;Began construction activities for DAC 1 in the Permian;
■Acquired interests in approximately 265,000 net acres of pore space access along the U.S. Gulf Coast; and
■Maintaining a robust liquidity position.Invested approximately $530 million in low-carbon businesses, technologies, and net-zero pathway advancements, including the aforementioned pore space.
The future costs associated with emissions reduction, carbon removal and CCUS to meet its long-term net-zero GHG goals may be substantial and execution of its plans and net-zero pathway depends on securing third-party capital investments. Occidental is pursuing multiple pathways to fund these projects including project financing, long-term carbon removal or CCUS agreements, and identifying business opportunities with stakeholders in carbon-intensive industries
KEY PERFORMANCE INDICATORS
Occidental seeks to meet its strategic goals by continually measuring its success against key performance indicators that drive total stockholder return. In addition to efficient capital allocation and deployment discussed below in “the section titled Oil and Gas Segment - Business Strategy”Strategy, Occidental believes the following are its most significant performance indicators:indicators are:
SAFETY
■Injury Incidence Rate (IIR) and Days Away Restricted Transfer rate (DART) - Occidental’s combined employee and contractor IIR is determined by multiplying the total number of Occupational Safety and Health Administration (OSHA) recordable injuries and illnesses by 200,000 and dividing that result by the total number of hours worked by all employees and contractors. The DART rate is calculated in the same manner as IIR, but uses the number of incidents that resulted in days away from work, job transfer, or restricted job duties instead of the number of recordable injuries or illnesses.
OPERATIONAL
■Annual cost synergies - Post Acquisition, Occidental has focused on an annualized reduction in overhead and operating expense strategies from the historical amounts of Occidental and Anadarko, and exceeded its initial goal of at least $1.1 billion by realizing $2.3 billion in total synergies and additional cost savings on an annualized basis in 2020.
■Total spend per barrel - In 2021,2023, Occidental will continue to focus on controlling total costs from a per-barrel perspective. Total spend per barrel is the sum of capital spending, general and administrative expenses, other operating and non-operating expenses and oil and gas lease operating costs divided by global oil, NGL and natural gas sales volumes.
FINANCIAL
■Cash returns on capital employed (CROCE)CROCE - CROCE is calculated as (i) the cash flows from operating activities, before changes in working capital, plus distributions from WES classified as investing cash flows, divided by (ii) the average of the opening and closing balances of total equity plus total debt.
■ReduceMaintain and improve financial leverage.leverage to a level consistent with investment grade credit metrics.
SUSTAINABILITY AND ENVIRONMENTAL
■Advancing specific Carbon Capture, UseSpecific interim emissions reduction and Sequestration projects;
■Net-zeroemissions intensity targets to advance our goal of net-zero operational and energy use emissions before 2040, with an ambition to achieve before 2035;2035.
■Net-zeroMilestones in specific carbon removal and CCUS projects that advance our net-zero total emissions inventory, including product use of sold products, with an ambition to achieve before 2050; and2050.
■TotalFacilitate deployment of carbon removal, CCUS and other solutions to advance total carbon impact through carbon removal and storage technology and development past 2050.
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
BUSINESS STRATEGY
Occidental’s oil and gas segment focuses on long-term value creation and leadership in sustainability, health, safety and the environment. In each core operating area, Occidental’s operations benefit from scale, technical expertise, decades of high-margin inventory, environmental and safety leadership and commercial and governmental collaboration. These attributes allow Occidental to bring additional production quickly to market, extend the life of older fields at lower costs and provide low-cost returns-driven growth opportunities with advanced technology.
With the completion of the Acquisition, Occidental becameis one of the largest U.S. producers of liquids, which includes oil condensate and NGL, allowing Occidental to maximize cash margins on a Boeper barrel basis. Since the Acquisition, Occidental has focused on its divestiture program to divest of non-core assets to pay down near-term debt maturities, however, theThe advantages that Occidental’s portfolio provides, coupled with unmatchedits advanced subsurface characterization ability and the proven ability to execute, ensures thatposition Occidental is positioned for full-cycle success in the years ahead. The oil and gas segment has realized synergiesmaximizes efficiencies to deliver lower breakeven costs and generate excess free cash flow. Since the Acquisition, Occidental completed the sale of significant non-core assets for net proceeds of approximately $8.2 billion.
Despite the pandemic impacts on commodity prices and the overall economy as discussed above, Occidental’s assets are strategically positioned to provide a future portfolio of projects that are flexible and have short-cycle investment paybacks. Together with Occidental’s technical capabilities, theThe oil and gas segment strives to achieve low development and operating costs to maximize full-cycle value of the assets.
The oil and gas business implements Occidental’s strategy primarily by:
■Operating and developing areas where reserves are known to exist and optimizing capital intensity in core areas, primarily in the Permian Basin, DJ Basin, Gulf of Mexico, UAE, Oman and Algeria;
■Maintaining a disciplined and prudent approach to capital expenditures with a focus on high-return, short-cycle,short and mid-cycle, cash-flow-generating opportunities and an emphasis on creating value and further enhancing Occidental’s existing positions;
■Focusing Occidental’s subsurface characterization and technical activities on unconventional opportunities, primarily in the Permian Basin;Basin and Rockies;
■Using EORsecondary and tertiary recovery techniques such as CO2, water and steam floods in mature fields; and
■Focusing on cost-reduction efficiencies and innovative technologies to reduce carbon emissions.
In 2020,2022, oil and gas capital expenditures were approximately $2.2$3.8 billion and primarily focused on Occidental’s assets in the Permian Basin, DJ Basin, Gulf of Mexico and Oman. In 2023, Occidental plans to spend $4.3 billion to $4.7 billion to develop its oil and gas assets.
OIL AND GAS PRICE ENVIRONMENT
Oil and gas prices are the major variables that drive the industry’s financial performance. The following table presents the average daily West Texas Intermediate (WTI)WTI and Brent prices for oil in dollars per barrel ($/Bbl) and New York Mercantile Exchange (NYMEX)NYMEX natural gas prices for 20202022 and 2019:2021:
| | | 2020 | | 2019 | | % Change | | 2022 | | 2021 | | % Change |
| WTI Oil ($/Bbl) | WTI Oil ($/Bbl) | | $ | 39.40 | | | $ | 57.03 | | | (31) | % | WTI Oil ($/Bbl) | | $ | 94.23 | | | $ | 67.91 | | | 39 | % |
| Brent Oil ($/Bbl) | Brent Oil ($/Bbl) | | $ | 43.21 | | | $ | 64.18 | | | (33) | % | Brent Oil ($/Bbl) | | $ | 98.83 | | | $ | 70.78 | | | 40 | % |
| NYMEX Natural Gas ($/Mcf) | NYMEX Natural Gas ($/Mcf) | | $ | 2.11 | | | $ | 2.67 | | | (21) | % | NYMEX Natural Gas ($/Mcf) | | $ | 6.35 | | | $ | 3.61 | | | 76 | % |
The following table presents Occidental’s average realized prices for continuing operations as a percentage of WTI, Brent and NYMEX for 20202022 and 2019:2021:
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| | 2020 | | 2019 |
| Worldwide oil as a percentage of average WTI | | 95 | % | | 99 | % |
Worldwide oil as a percentage of average Brent (a) | | 87 | % | | 88 | % |
| Worldwide NGL as a percentage of average WTI | | 32 | % | | 30 | % |
Worldwide NGL as a percentage of average Brent (a) | | 29 | % | | 27 | % |
| Domestic natural gas as a percentage of NYMEX | | 56 | % | | 49 | % |
(a)Prior period percentages have been adjusted to reflect the Algeria operations as continuing operations. | | | | | | | | | | | | | | |
| | 2022 | | 2021 |
| Worldwide oil as a percentage of average WTI | | 100 | % | | 97 | % |
| Worldwide oil as a percentage of average Brent | | 95 | % | | 93 | % |
| Worldwide NGL as a percentage of average WTI | | 38 | % | | 44 | % |
| Worldwide NGL as a percentage of average Brent | | 36 | % | | 42 | % |
| Domestic natural gas as a percentage of NYMEX | | 86 | % | | 91 | % |
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
Prices and differentials can vary significantly, even on a short-term basis, making it difficult to predict realized prices with a reliable degree of certainty.
As a result of the expected prolonged period of lower commodity prices brought on by the COVID-19 pandemic’s impact on oil demand, Occidental tested substantially all of its oil and gas assets for impairment during the second quarter of 2020. Occidental recognized pre-tax impairment charges of $6.4 billion related to continuing operations and $2.2 billion related to discontinued operations for the three months ended June 30, 2020. While oil prices have modestly improved since the second quarter of 2020, if there was a worsening of the macroeconomic conditions caused by the impacts of COVID-19 and if such worsened condition was expected to be prolonged, Occidental’s oil and gas properties may be subject to further testing for impairment, which could result in additional non-cash asset impairments, and such impairments could be material to our financial statements.
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
DOMESTIC INTERESTS
BUSINESS REVIEW
Occidental conducts its domestic operations through land leases, subsurface mineral rights it owns, or a combination of both. Occidental’s domestic oil and gas leases have a primary term ranging from one to 10 years, which is extended through the end of production once it commences. Occidental has leasehold and mineral interests in 9.5 million net acres, of which approximately 52% is leased, 24%47% is owned subsurface mineral rights and 24%1% is owned land with mineral rights.
The following chart shows Approximately $3.6 billion to $4.0 billion of Occidental’s worldwide capital budget is expected to be allocated to its domestic production volumes for the previous three yearsoperations in thousand barrels of oil equivalent (Mboe) per day:
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
2023.
DOMESTIC ASSETS (a)
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| 1. Powder River Basin
2. DJ Basin
3. Permian Basin
4. Gulf of Mexico
|
(a)Map represents geographic outlines of the respective basins.
The Permian Basin
The Permian Basin extends throughout West Texas and southeastSoutheast New Mexico and is one of the largest and most active oil basins in the United States, accounting for more than 36%43% of total United States oil production in 2020.2022. Overall in 2022, Occidental’s production in the Permian Basin was approximately 513 Mboe/d.
Occidental manages its Permian Basin operations through two business units:businesses: Permian Resources, which includes unconventional opportunities, and Permian EOR, which utilizes EOR techniques such as CO2 floodssecondary and waterfloods.tertiary recovery techniques. Occidental hashad a leading position in the Permian Basin, producing approximately 13%8% of the total oil in the basin.basin in 2022. By exploiting the natural synergies between Permian Resources and Permian EOR, Occidental is able to deliver unique short- and long-term advantages, efficiencies and expertise across its Permian Basin operations.
The Permian Resources unconventional oilbusiness is focused on developing and producing unconventional reservoir targets using horizontal drilling technology. The development projects provide very short-cycle investment payback, averaging less than two years, and generate some of the highest margin and returns of any oil and gas projects in the world. These investments contribute cash flow, while increasingprograms are designed to create long-term value from primary development by maximizing the recovery of oil, utilizing sustainable practices and sustainability through higher return on capital employed. providing strong financial returns. Occidental’s unconventional oil and gas operations in Permian Resources include approximately 1.61.4 million net acres. In 2020, new2022, our activities were focused in the core development areas with emphasis on maintaining the industry leading capital intensity through optimized surface infrastructure and customized well design and flowback methods were implemented, which helped lower the overall well cost while improving recovery.designs. Overall, in 2020,2022, Permian Resources produced approximately 435 Mboe/d from approximately 6,000approximately 3,300 gross wells. Additionally in 2020, Permian Resourceswells and added 122 million barrels of oil equivalent (MMboe)387 MMboe to Occidental’s proved reserves for improved recovery additions.through development and extensions of proved areas.
The Permian Basin’s concentration of large conventional reservoirs, favorablestrong CO2 flooding performance and the expansive CO2 transportation and processing infrastructure has resulted in decades of high-value enhanced oil production. With 34 active CO2 floods and over 4050 years of experience, Occidental is the industry leader in Permian Basin CO2 flooding, which can increase ultimate oil recovery by 10% to 25%. Technology improvements, such as the recent trend toward vertical
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
expansion of the CO2 flooded interval into residual oil zone targets, continue to yield more recovery from existing projects. Occidental’s share of production fromprojects, and Permian EOR wasproduced from approximately 140 Mboe/d13,000 gross wells in 2020.2022.
Significant opportunities also remain to gain additional recovery by expanding Occidental’s existing CO2 projects into new portions of reservoirs that have only been water-flooded.waterflooded. Permian EOR has a large inventory of future CO2 projects, which could be developed over the next 20 years or accelerated, depending on market conditions. In addition, OLCV continues making progress towards supplying anthropogenic, or man-made, CO2 for the purpose of carbon capture, utilization and storage in Occidental’s Permian EOR operations.
In 2020,2022, Occidental spent approximately $1.1$2.3 billion of capital in the Permian Basin, of which over 87%approximately 93% was spent on Permian Resources assets. Also in 2020, Occidental divested of certain non-core, largely non-operated acreage in the Permian Basin. In 2021, Occidental expects to allocate approximately 38% of its worldwide capital budget to the Permian Basin.
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Rockies and Other Domestic
In 2022, Occidental produced approximately 277 Mboe/d net in the Rockies and Other Domestic locations. Production in the DJ Basin
Occidental remains Colorado’s top oil and gas producer with interest in approximately 0.7 million net acres in Colorado. Production is derived from 2,5002,000 operated vertical wells and 2,1002,400 operated horizontal wells primarily focused in 460,000 net acres in the Niobrara and Codell formations. The DJ Basin, including the North DJ Basin, comprises approximately 800,000 total net acres and provides competitive economics, low breakeven costs and free cash flow generation.generation through Occidental’s contiguous acreage position and royalty uplift.
Occidental produced approximately 293 Mboe/d inIn the DJ Basin, in 2020. Horizontalhorizontal drilling results in the field continue to be strong, with improved operational efficiencies in drilling and completions. In 2020,2022, Occidental drilled 6568 operated horizontal wells and completed 11754 operated horizontal wells.
Occidental is currently fully permitted for all planned 2021 completions activityfocusing on obtaining the necessary state, local and has received drillingfederal permits for all planned drilling activity through the first half of 2021. New statewide regulations were adoptedrequired to construct facilities and drill and complete wells in the fourth quarter of 2020 and became effective in mid-January 2021. Occidental’s focus for 2021 is continuing to build operational inventory while implementing the new regulations and maintaining social licenses to operate. Occidental additionally continues to have development optionality by flexing resources between the DJ Basin and another emerging high rate-of-return program in the Powder River Basin.
As discussed above, in In January 2021, the COGCC adopted new regulations that impose siting requirements, or “setbacks”“setbacks,” on certain oil and gas drilling locations based on the distance of a proposed well pad to occupied structures. WhileUnder these new regulations and through thoughtful surface location planning, Occidental obtained COGCC approval for five Oil and Gas Development Plans, inclusive of 12 well pad and facility locations and approximately 150 wells. In addition to the approximately 150 wells approved through the Oil and Gas Development Plan process, during the third quarter of 2022, Occidental became the first oil and gas operator in Colorado to obtain COGCC approval for the first Comprehensive Area Plan under the new COGCC rules. This comprehensive plan will support nine well pads and approximately 140 new wells and will provide for substantial future development in a geographically remote area on Colorado’s eastern plains. Oil and Gas Development Plans associated with the Comprehensive Area Plan will be submitted in 2023.
As of December 31, 2022, Occidental is currently evaluatingpermitted, or had permit applications submitted to applicable regulatory agencies, for nearly all planned 2023 drilling and completions activity in the impactDJ Basin. In 2023, Occidental plans to submit state and local permits with the goal of these regulationsbuilding operational inventory and maintaining its social license to operate in Colorado. Occidental has a dedicated stakeholder relations team that conducts regulatory and community outreach with respect to its permit applications and operations in Colorado with a focus on its business; at this time,building trust and fostering open communication with those that live and work near our operations.
Occidental has gained efficiencies in the permitting process and will continue to look for additional opportunities to do so. As discussed above, Occidental does not anticipate significant near-term changes to our development program in the DJ Basin based on these regulations. However, if Occidental is unable to obtain new drilling permits to develop a significant portion of the company’s undeveloped acreage in the DJ Basin, the company’s DJ Basin assets may be subject to testing for impairment, and if deemed to be impaired, such impairment could be material to our financial statements.
Other DomesticOccidental has interest in over 300,000 net acres in the Powder River Basin, mainly located in Converse County and Campbell County, Wyoming. The field contains the Turner, Niobrara, Mowry and Parkman formations that hold both liquids and natural gas. In 2022, Occidental drilled 19 operated horizontal wells and completed 14 horizontal wells in the Powder River Basin. The company plans to run one continuous operated drilling rig in 2023 with targeted completion activity throughout the year.
Occidental holds approximately 5.04.6 million net acres in other domestic locations, which is primarily comprisedconsist of the Powder River Basin, North DJ Basinlegacy acreage and Wyoming. Occidental's sharefee minerals outside of production in other domestic locations was approximately 39 Mboe/d in 2020.Occidental’s core operated areas including parts of Arkansas, Colorado, Louisiana, Texas, West Virginia and Wyoming.
OFFSHORE DOMESTIC ASSETS
Gulf of Mexico
Occidental ownsis the fourth-largest oil and gas producer in the deep-water Gulf of Mexico, operating 10 strategically located deep-water floating platforms, the highest number among all the deep water operators, and producing from 18 active fields while owning a working interest in 182across 252 blocks, inincluding approximately 1.0 million net acres. Occidental’s position is one of the Gulf of Mexico, operates 10 active floating platforms and holds interests in 17 active fields. The Gulf of Mexico produced approximately 130 Mboe/d during 2020. In 2021, Occidental will continue to take advantage of its extensive infrastructure across the Gulf of Mexico to execute its long-term plan for development and exploration. Occidental will operate one floating drillship and one platform rig together with two multi-service vessels to cost effectively develop known resources.
Occidental continues to work with the BSEE and the BOEM to address the additional regulatory requirements to ensure a minimal disruption of activitieslargest portfolios in the Gulf of Mexico.
Occidental further operates two marine shore-bases in Galveston, Texas, and Port Fourchon, Louisiana, as well as two helicopter bases in Louisiana that all provide back up and redundancy to each other to support the Gulf operations. A central logistics base with an integrated training center is located in Broussard, Louisiana, and the Gulf of Mexico operations and development are managed and supported with engineering and technical staff from The Woodlands, Texas, office tower.
In 2022, Occidental increased net production to 147 Mboe/d from approximately 88 gross wells, investing over $450 million in capital, including exploration capital, primarily directed towards drilling activity in its new Horn Mountain West subsea development, Lucius and Holstein facilities, drilling five wells using one floating drill ship, one platform rig and several service rigs. Occidental successfully and safely initiated first production from its new Horn Mountain West field and tied back to the Horn Mountain facility, increasing production at the platform by over 34 Mboe/d from three subsea oil wells,
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
on budget and three months ahead of schedule.In the fourth quarter of 2022, the new Caesar-Tonga Subsea Expansion project was also started several months ahead of schedule, debottlenecking the prolific giant Caesar-Tonga field and thus enabling future field expansion projects. Major subsea-pumping projects supporting the Marco Polo/K2 field and the Marlin/King field were progressed as well as extensive 4D seismic shoots in the Holstein field and elsewhere, setting up a runway of future development opportunities.
Operational excellence and efficiency continued as the prime objective in 2022 and gathered further momentum, reducing overall base production decline rates through the implementation of several successful well stimulations and artificial lift projects.Platform operating efficiencies were significantly improved and machinery uptimes were increased all throughsubordinated focus and condition monitoring initiatives as well as multiple upgrade projects. Continued optimum sequencing of annual platform turn-arounds provided further operational efficiencies, avoiding around two hundred days per year of shut-ins.
During 2022, all necessary regulatory permits for new wells and existing operations were obtained timely without any operational delays.Occidental was further awarded 30 new leases from BOEM’s Lease Sale 257 and was the second most successful bidder.
Occidental’s Gulf of Mexico assets continued to be among the lowest carbon emissions operations in the industry with zero routine flaring and zero cold venting.
The following table shows key areas of continuingongoing development in the Gulf of Mexico, along with the corresponding working interest in those areas.
| | | | | |
| Working Interest |
| Horn Mountain | 100 | % |
| Holstein | 100 | % |
| Marlin | 100 | % |
| Lucius | 6467 | % |
| K2 Complex | 42 | % |
| Caesar Tonga | 34 | % |
| Constellation | 33 | % |
In 2023, Occidental expects to continue development and expansion of its existing assets across the Gulf of Mexico, to safely deliver high-margin production while continuing to add to its drill well inventory on existing leases through expansion and infrastructure led exploration opportunities around existing infrastructure. Occidental plans to conduct development and exploration activities in 2023 using one to two floating drill ships, one platform rig and several other well service vessels and continue to optimize its extensive portfolio of lease working interests.
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INTERNATIONAL INTERESTS
BUSINESS REVIEW
Occidental conducts its ongoing international operations in two sub-regions: the Middle East and North Africa. Its activities include oil, NGL and natural gas production through direct working-interests, PSAs and production sharing contracts (PSC).
Production Sharing Contracts
Occidental’s interest in Oman and Qatar are subject to PSCs. Under such contracts,the PSCs, Occidental records a share of production and reserves to recover certain development and production costs and an additional share for profit. These contracts do not transfer any right of ownership to Occidental and reserves reported from these arrangements are based on
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
Occidental’s economic interest as defined in the contracts. Occidental’s share of production and reserves from these contracts decreases when product prices rise and increases when prices decline. Overall, Occidental’s net economic benefit from these contracts is greater when product prices are higher.
The following chart shows Approximately $0.5 billion of Occidental’s worldwide capital budget is expected to be allocated to its international production volumes for the previous three years:
Note: Operations sold, exited or held for sale include the Ghana assets (held for sale at December 31, 2020 and 2019), the Colombia onshore assets (soldoperations in December 2020) and the Qatar Idd El Shargi Fields (exited in 2019).2023.
MIDDLE EAST / NORTH AFRICA ASSETS
| | | | | |
| 1.Algeria
2.Oman
3.Qatar
4.United Arab EmiratesUAE |
Algeria
In April 2020, subsequent to communications with Algerian government officials, Occidental determined that the sale of the Algeria operations to Total would not be consummated and the decision was made to continue to operate within Algeria. As a result, Occidental reclassified 2019 results to reflect the Algeria operations as continuing operations. OperationsOccidental’s interest in Algeria involveinvolves development and production and development activitiesrights in 18 fields within Blocks 404A404a and 208, which are located in the Berkine Basin in Algeria’s Sahara Desert and are governed by a Production Sharing Agreement (PSA) betweenan agreement amongst Occidental, Sonatrach and other partners. Under this PSA, Occidental is responsible for 24.5% of the development and production costs. The El Merk Central Processing Facility (CPF)central processing facility in Block 208 processedprocesses produced oil, NGL and NGL,natural gas, while the Hassi Berkine South and Ourhoud central processing facilities in Block 404a process produced oil. The rights to produce from the Block 404a fields expire between May 2023 and 2036, and the rights to produce from the Block 208 fields expire in 2032.
In 2022, net production in Algeria was 45 Mbbl/d, two gross development wells were drilled and annual net capital expenditures were $25 million.
In July 2022, Occidental signed a new PSC with Sonatrach and other partners which, upon approval by the Algerian government, will be for a new 25-year term for all of the fields under the current hydrocarbon agreement. With respect to the new PSC, Occidental is responsible for 35% of the development and production costs, and government approval is expected in the first half of 2023.
Oman
In Oman, Occidental is the operator of Block 9, Block 27, Block 53 (Mukhaizna Field), Block 62 and Block 65 and has additional interests in Blocks 30, 51 and 72, which are under the Exploration phase. The working interest and contract expiration year for each of the respective blocks are shown in the table below. Occidental holds 6.0 million gross acres and has 10,000 potential well inventory locations. In 2022, Occidental’s share of production was 65 Mboe/d.
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OXY 20202022 FORM 10-K | 2731 |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
South and Ourhoud CPFs in Block 404A processed produced oil. In 2020, Occidental drilled two development wells and plans to continue drilling operations throughout 2021. Net production in Algeria was 44 Mboe/d in 2020.
Oman | | | | | | | | |
| Working Interest | Block Expiration (Year) |
| Block 9 | 50 | % | 2030 |
| Block 27 | 65 | % | 2035 |
| Block 53 | 47 | % | 2035 |
| Block 62 | 100 | % | 2028 |
| Block 65 | 51 | % | 2037 |
| Blocks 30, 51 and 72 | 100 | % | Exploration Phase |
In Oman,
Occidental is the operator ofhas produced over 754 million gross barrels from Block 9 with a 50% working interest, Block 27 with a 65% working interest,since the beginning of its operation through successful exploration, continuous drilling improvements and EOR projects. The Mukhaizna Field in Block 53 with a 47% working interest and Block 62 with a 100% working interest. Occidental additionally has exploration and production sharing agreements for Blocks 30, 51, 65 and 72. Occidental holds 6.0 million gross acres and has 10,000 potential well inventory locations. In 2020, Occidental’s share of production was 85 Mboe/d.
The Block 9 contract expires in 2030 and the Block 27 contract expires in 2035. Occidental’s share of production for Blocks 9 and 27 was 30 Mboe/d and six Mboe/d in 2020, respectively. The Block 53 (Mukhaizna Field) contract expires in 2035 and is a major world-class pattern steam flood project for EOR that utilizes some of the largest mechanical vapor compressors ever built. Since assuming operations in the Mukhaizna Field in 2005, Occidental has drilled over 3,550close to 3,580 new wells and has increasedproduced over 575 million gross barrels. In 2022, Occidental declared commerciality for Block 65 and invested capital of $362 million across all of the Oman blocks to drill 92 wells and execute facilities projects to support development and EOR activities.
In 2023, Occidental will continue to enhance production by over 15 fold. Occidental’s share of production for Block 53 was 30 Mboe/dadding extended and dual laterals, stimulating wells with the OXY JETTINGTM wellbore stimulation system, and expanding thermal conformance. Occidental will also continue to execute projects in 2020. Subject to a declaration of commerciality, Occidental’s permit for Block 62 will expire in 2028. Occidental’s share of production for Block 62 was 19 Mboe/d in 2020.Oman targeting emissions reductions.
Qatar
In Qatar, Occidental partners in the Dolphin Energy Project, an investment that is comprised of two separate economic interests. Occidental has a 24.5% interest in the upstream operations (Dolphin) to develop and produce NGL, natural gas and condensate from Qatar’s North Field through mid-2032. Occidental also has a 24.5% interest in Dolphin Energy Limited,DEL, which operates a pipeline and is discussed further in the Midstreammidstream and Marketing Segmentmarketing segment section in this Form 10-K under Pipeline. In 2022, Occidental’s net share of production from the Dolphin upstream operations was 4437 Mboe/d in 2020.d.
United Arab EmiratesUAE
In 2011, Occidental acquired a 40% participating interest in the Shah gas field (Al Hosn Gas), joining with the Abu Dhabi National Oil Company, (ADNOC)which expires in a 30-year joint venture agreement.2041. In 2020,2022, Occidental’s net share of production from Al Hosn Gas was 238 MMcf/d227 million cubic feet per day (MMcf/d) of natural gas and 38 Mboe/35 Mbbl/d of NGL and condensate. Al Hosn Gas includes gas processing facilities which are discussed further in the Midstreammidstream and Marketing Segmentmarketing segment section in this Form 10-K under Gas Processing, Gathering and CO2.
In 2019 and 2020, Occidental acquired 9-year exploration concessions and, subject to a declaration of commerciality, 35-year production concessions adjacent to Al Hosn Gas for onshoreOnshore Block 3 and Block 5, which cover an area of approximately 1.5 million acres and 1.0 million acres, respectively.respectively, and are adjacent to Al Hosn Gas. In 2022 and 2021, Occidental conducts a majority of its Middle East business development activities through its office in Abu Dhabi, which also provides various support functions for Occidental’s Middle Eastannounced multi-zone oil and gas operations.discoveries in Onshore Block 3.
In 2023, Occidental plans to complete an expansion project that commenced in 2022 to increase the production capacity of the Al Hosn Gas processing facilities from 1.28 Bcf/d to 1.45 Bcf/d and continue further exploration and appraisal activities in Onshore Block 3 and Block 5.
Ghana - Discontinued Operations
In May 2020, Occidental and Total mutually agreed to execute a waiver of the obligation to purchase and sell the Ghana assets, so that Occidental could begin marketing the sale of the Ghana assets to other third parties. Occidental is currently marketing the Ghana assets. The assets and liabilities for Ghana remain presented as held for sale in discontinued operations at December 31, 2020. Ghana operations include production and development activities located offshore in the West Cape Three Point Block and the Deepwater Tano Block. Occidental’s share of production in 2020 was 30 Mboe/d.
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
LATIN AMERICA ASSETS
Colombia
In December 2020, Occidental completed the sale of its Colombia onshore assets, specifically the operations and working interests in the Llanos Norte, Middle Magdalena and Putumayo Basins. Occidental has retained a presence with exploration blocks offshore Colombia.
PROVED RESERVES
Proved oil, NGL and natural gas reserves were estimated using the unweighted arithmetic average of the first-day-of-the-month price for each month within the year, unless prices were defined by contractual arrangements. Oil, NGL and natural gas prices used for this purpose were based on posted benchmark prices and adjusted for price differentials including gravity, quality and transportation costs.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
The following table shows the 2020, 20192022, 2021 and 20182020 calculated first-day-of-the-month average prices for both WTI and Brent oil prices, as well as the Henry Hub gas prices measured in million British thermal units (MMbtu):MMbtu:
| | | | | | | | | | | | | | | | | | | | |
| | 2020 | | 2019 | | 2018 |
| WTI Oil ($/Bbl) | | $ | 39.57 | | | $ | 55.69 | | | $ | 65.56 | |
| Brent Oil ($/Bbl) | | $ | 43.41 | | | $ | 63.03 | | | $ | 72.20 | |
| Henry Hub Natural Gas ($/MMbtu) | | $ | 1.98 | | | $ | 2.58 | | | $ | 3.10 | |
Mt. Belvieu NGL ($/Bbl) (a) | | $ | 18.74 | | | N/A | | N/A |
(a)Mt. Belvieu pricing was added as an NGL benchmark beginning in 2020. Prior to 2020, WTI oil was used as a benchmark for NGL. | | | | | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 | | 2020 |
| WTI Oil ($/Bbl) | | $ | 93.67 | | | $ | 66.56 | | | $ | 39.57 | |
| Brent Oil ($/Bbl) | | $ | 97.77 | | | $ | 69.24 | | | $ | 43.41 | |
| Henry Hub Natural Gas ($/MMbtu) | | $ | 6.36 | | | $ | 3.60 | | | $ | 1.98 | |
| Mt. Belvieu NGL ($/Bbl) | | $ | 47.81 | | | $ | 44.22 | | | $ | 18.74 | |
Occidental had proved reserves from continuing operations at year-end 20202022 of 2,9113,817 MMboe, compared to the year-end 20192021 amount of 3,9043,512 MMboe. Proved developed (PD) reserves represented approximately 78%71% and 77%75% of Occidental’s total proved reserves at year-end 20202022 and 2019,2021, respectively. The following table shows the breakout of Occidental’s proved reserves from continuing operations by commodity as a percentage of total proved reserves:
| | | 2020 | | 2019 | | 2022 | | 2021 |
| Oil | Oil | | 51 | % | | 52 | % | Oil | | 50 | % | | 50 | % |
| NGL | | NGL | | 22 | % | | 22 | % |
| Natural gas | Natural gas | | 29 | % | | 29 | % | Natural gas | | 28 | % | | 28 | % |
| NGL | | 20 | % | | 19 | % | |
Occidental does not have any reserves from non-traditional sources. For further information regarding Occidental’s proved reserves, see the Supplemental Oil and Gas Information section in Item 8 of this Form 10-K.
CHANGES IN PROVED RESERVES
Occidental’s total proved reserves from continuing operations decreased 993 MMboe in 2020, which was primarily driven by price and other revisions of 484 MMboe and asset divestitures of 241 MMboe. These decreases were partially offset by increases from Occidental’s development program of 212 MMboe. Changes in Occidental’s 2022 reserves were as follows:
| | | | | | | | |
| MMboe | | 20202022 |
| Revisions of previous estimates | | (484)474 | |
| Improved recovery | | 19089 | |
| Extensions and discoveries | | 22176 | |
| Purchases | | 410 | |
| Sales | | (241)(21) | |
| Production | | (484)(423) | |
| Total | | (993)305 | |
Occidental’s ability to add reserves, other than through purchases, depends on the success of infill development, extension, discovery and improved recovery extension and discovery projects, each of which depends on reservoir characteristics, technology improvements and oil and natural gas prices, as well as capital and operating costs. Many of these factors are outside management’s control and may negatively or positively affect Occidental’s reserves.
Revisions of Previous Estimates
Revisions can include upward or downward changes to previous proved reserve estimates for existing fields due to the evaluation or interpretation of geologic, production decline or operating performance data. In addition, product price changes affect proved reserves recorded by Occidental. For example, lower prices may decrease the economically recoverable reserves, particularly for domestic properties, because the reduced margin limits the expected life of the operations. Offsetting this effect, lower prices increase Occidental’s share of proved reserves under PSCs because more oil is required to recover costs. Conversely, when prices rise, Occidental’s share of proved reserves decreases for PSCs and economically recoverable reserves may increase for other operations. Reserve estimation rules require that estimated ultimate recoveries be much more likely to increase or remain constant than to decrease, as changes are made due to increased availability of technical data.
In 2020, Occidental’s revisions of previous estimates of proved reserves were negative 484 MMboe, of which approximately 342 MMboe were negative price revisions. The negative price revisions were primarily associated with the
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OXY 20202022 FORM 10-K | 2933 |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
In 2022, Occidental’s revisions of previous estimates of proved reserves were positive 474 MMboe. These revisions were primarily due to 335 MMboe of positive revisions related to additions associated with infill development projects, mainly in the Permian Basin (283(232 MMboe) and the DJ Basin (74(94 MMboe). An additional 136 MMboe of positive revisions were related price revisions. The positive price revisions were primarily associated with the Permian Basin (147 MMboe), the Gulf of Mexico (8 MMboe) and the DJ Basin (4 MMboe), which were partially offset by positivenegative price revisions of 3629 MMboe on international production sharing contracts.
An additional 197 MMboe of negative revisions were related to management changes in development plans due to lower average commodity prices compared to the prior year and the reallocation of capital to higher return projects. These changes were primarily associated with the Permian Basin (143 MMboe).PSCs.
Further positive revisions of 5793 MMboe net, were associated with updates based on reservoir performance.performance and 5 MMBoe were associated with management changes in development plans. The remainingpositive revisions were offset by negative revisions associated with various other cost and interest related revisions.revisions (95 MMboe).
Improved Recovery
In 2020,2022, Occidental added proved reserves of 19089 MMboe related to improved recovery, primarily due to additional development drilling, mainly in the Permian BasinEOR, which accounted for approximately two-thirds87% of the improved recovery reserve additions. These properties comprise both unconventional projects and conventional projects, which are characterized by the deployment of EOR development methods, largely employing application of CO2flood, waterflood or steam flood and unconventional projects.flood. These types of conventional EOR development methods can be applied through existing wells, though additional drilling is frequently required to fully optimize the development configuration. Waterflooding is the technique of injecting water into the formation to displace the oil to the offsetting oil production wells. The use of either CO2 or steam flooding depends on the geology of the formation, the evaluation of engineering data, availability and cost of either CO2 or steam and other economic factors. Both techniques work similarly to lower viscosity causing the oil to move more easily to the producing wells. Many of Occidental’s projects, including unconventional projects, rely on improving permeability to increase flow in the wells. In addition, someThe remaining improved recovery comes from drilling infill wells that allow recovery of reserves that would not be recoverable from existing wells. Further positive additions of 32 MMboe in the UAE, 13 MMboe in Oman, 9 MMboe in the DJ Basinwere due to secondary and 9 MMboe in the Gulf of Mexico were similarly the result of development drilling.tertiary projects for certain international assets.
Extensions and Discoveries
Occidental also added proved reserves from extensions and discoveries, which are dependent on successful exploration and exploitation programs. In 2020,2022, extensions and discoveries added 22176 MMboe primarily related to the recognition of proved reserves in the DJPermian Basin Wyoming(155 MMboe) and Oman.Powder River Basin (7 MMboe).
Purchases of Proved Reserves
In 2020,2022, Occidental purchased proved reserves of 410 MMboe primarily consisting of proved reserves in the Permian Basin.
Sales of Proved Reserves
In 2020,2022, Occidental sold 24121 MMboe in proved reserves primarily related to the divestitures of the Colombia onshorecertain non-strategic assets the mineral acres and fee surface acres located in Wyoming, Colorado and Utah and the non-core, largely non-operated acreage in the Permian Basin.
Proved Undeveloped Reserves
Occidental had proved undevelopedPUD reserves at year-end 20202022 of 6451,119 MMboe, compared to the year-end 20192021 amount of 905865 MMboe.
Changes in proved undevelopedPUD reserves were as follows:
| | | | | | | | |
| MMboe | | 20202022 |
| Revisions of previous estimates | | (253)270 | |
| Improved recovery | | 13249 | |
| Extensions and discoveries | | 6107 | |
| Purchases | | 31 | |
| Sales | | (44)(10) | |
| Transfer to proved developed reserves | | (104)(163) | |
| Total | | (260)254 | |
Revisions of previous estimates were a positive 270 MMboe. Approximately 263 MMboe of the positive revisions were related to additions associated with infill development projects in the Permian Basin (170 MMboe) and the DJ Basin (93 MMboe). Additionally, the revisions included positive price revisions of 24 MMboe. The positive price revisions were primarily associated with the Permian Basin. The remaining positive revisions were associated with various updates based on reservoir performance. The positive revisions were offset by negative revisions associated with various other cost and interest related revisions (21 MMboe).
Extensions and discoveries added 107 MMboe primarily related to the recognition of proved reserves in the Permian Basin (100 MMboe). Total improved recovery additions of 13249 MMboe were primarily the result of additional development drillingconventional projects in the Permian Basin (80EOR (44 MMboe), and secondary and tertiary projects in international assets (41 MMboe) and the DJ Basin (7(5 MMboe). The 20202022 additions to proved undeveloped reserves were offset by transfers to proved developed reserves and negative revisions of previous estimates. Transfers to proved developed reserves were a total of 104 MMboe. The transfers were primarily associated with the DJ Basin (53 MMboe) and the Permian Basin (48 MMboe). Revisions of previous estimates were a negative 253 MMboe. Approximately 123 MMboe of the negative revisions were related to management changes in development plans, primarily associated with the Permian Basin (111 MMboe). Additionally, the revisions include preliminary impacts related to the
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3034 | OXY 20202022 FORM 10-K |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
January 2021 COGCC regulation inPUD reserves were partially offset by transfers to proved developed reserves of 163 MMboe. The transfers were primarily associated with the Permian Basin (89 MMboe), the DJ Basin. Further, 77Basin (40 MMboe) and Gulf of Mexico (21 MMboe).
In 2022, Occidental incurred approximately $1.2 billion to convert PUD reserves to proved developed reserves, and in 2022 Occidental converted approximately 19% of its PUD reserves to proved developed, when adjusted for revisions and sales. As of December 31, 2022, Occidental had 1,119 MMboe of negative revisionsPUD reserves of which 73% were associated with updates based on reservoir performancedomestic onshore, 4% with Gulf of Mexico and 55 MMboe23% with international assets. Occidental’s most active development areas are located in the Permian Basin, which represented 54% of negative revisions were associated with price revisions.the PUD reserves as of December 31, 2022. Occidental’s total planned 2023 capital expenditures are between $5.4 billion and $6.2 billion. Overall, Occidental plans to spend approximately $4.6 billion over the next five years to develop its PUD reserves in the Permian Basin.
Proved undevelopedPUD reserves are supported by a five-year detailed field-level development plan, which includes the timing, location and capital commitment of the wells to be drilled. Only proved undevelopedPUD reserves which are reasonably certain to be drilled within five years of booking and are supported by a final investment decision to drill them are included in the development plan. A portion of the proved undevelopedPUD reserves associated with international operations are expected to be developed beyond the five years and are tied to approved long-term development projects.
In 2020, Occidental incurred approximately $0.5 billion to convert proved undeveloped reserves to proved developed reserves. Given the impact of the COVID-19 pandemic on demand and cash flows, Occidental reduced its 2020 capital expenditures from $5.2 billion to $2.6 billion and; accordingly, converted a lower than expected amount of reserves from proved undeveloped reserves to proved developed reserves. In 2020 Occidental converted approximately 17% of its PUDs to proved developed, when adjusted for revisions and sales. As of December 31, 2020,2022, Occidental had 645241 MMboe of PUDs of which 49% were associated with domestic onshore, 8% with Gulf of Mexico and 43% with international assets.
Occidental’s most active development areas are located in the Permian Basin, which represented 36% of the proved undeveloped reserves as of December 31, 2020. Approximately 40% of Occidental’s 2021 capital program of $2.9 billion is allocated to the development program in the Permian Basin. Overall, Occidental plans to spend approximately $1.5 billion over the next five years to develop its proved undeveloped reserves in the Permian Basin.
At December 31, 2020, Occidental had 207 MMboe of pre-2016 proved undevelopedpre-2018 PUD reserves that remained undeveloped. These proved undevelopedPUD reserves relate to approved long-term development plans, 187175 MMboe of which are primarily associated with international development projects with physical limitations in existing gas processing capacity and 2066 MMboe associated with certainof which are related to approved long-term development plans for Permian EOR projects.projects, also with physical limitations in existing gas processing capacity. Occidental remains committed to these projects and continues to actively progress the development of these volumes. In addition to the above, Occidental has 8957 MMboe of proved undevelopedPUD reserves that are scheduled to be developed more than five years from their initial date of booking. These proved undevelopedPUD reserves are primarily related to approved long-term development plans, with physical limitations in existing gas processing capacity, 5141 MMboe of which are associated with other Permian EORinternational development projects and 3116 MMboe associated with international developmentthe Gulf of Mexico projects.
RESERVES EVALUATION AND REVIEW PROCESS
Occidental’s estimates of proved reserves and associated future net cash flows as of December 31, 2020,2022, were made by Occidental’s technical personnel and are the responsibility of management. The estimation of proved reserves is based on the requirement of reasonable certainty of economic producibility and funding commitments by Occidental to develop the reserves. This process involves reservoir engineers, geoscientists, planning engineers and financial analysts. As part of the proved reserves estimation process, all reserve volumes are estimated by a forecast of production rates, operating costs and capital expenditures. Price differentials between benchmark prices (the unweighted arithmetic average of the first-day-of-the-month price for each month within the year) and realized prices and specifics of each operating agreement are then used to estimate the net reserves. Production rate forecasts are derived by a number of methods, including estimates from decline curve analysis, type curvewell profile analysis, computer simulation of the reservoir performance, volumetric analysis and material balance calculations that take into account the volumes of substances replacing the volumes produced and associated reservoir pressure changes supported by various technologies including seismic analysis and computer simulation of the reservoir performance.analysis. These reliable field-tested technologies have demonstrated reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. Operating and capital costs are forecast using the current cost environment applied to expectations of future operating and development activities.
Net proved developed reserves are those volumes that are expected to be recovered through existing wells with existing equipment and operating methods for which the incremental cost of any additional required investment is relatively minor.
Net proved undevelopedPUD reserves are those volumes that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Proved undevelopedPUD reserves are supported by a five-year, detailed, field-level development plan, which includes the timing, location and capital commitment of the wells to be drilled. The development plan is reviewed and approved annually by senior management and technical personnel. Annually, a detailed review is performed by Occidental’s WorldwideCorporate Reserves Group and its technical personnel on a lease-by-lease basis to assess whether proved undevelopedPUD reserves are being converted on a timely basis within five years from the initial disclosure date. Any leases not showing timely transfers from proved undevelopedPUD reserves to proved developed reserves are reviewed by senior management to determine if the remaining reserves will be developed in a timely manner and have sufficient capital committed in the development plan. Only proved undevelopedPUD reserves that are reasonably certain to be drilled within five years of booking and are supported by a final investment decision to drill them are included in the development plan. A portion of the proved undevelopedPUD reserves associated with international operations are expected to be developed beyond the five years and are tied to approved long-term development plans.
The current Senior Vice President, Reserves for Oxy Oil and Gas is responsible for overseeing the preparation of reserve estimates, in compliance with U.S. SEC rules and regulations, including the internal audit and review of Occidental’s oil and gas reserves data. He has over 40 years of experience in the upstream sector of the exploration and production business and has held various assignments in North America, Asia and Europe. He is a three-time past Chair of the Society of Petroleum Engineers Oil and Gas Reserves Committee. He is an American Association of Petroleum Geologists (AAPG)AAPG Certified Petroleum Geologist and currently serves on the AAPG Committee on Resource Evaluation. He is a member of the
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
Society of Petroleum Evaluation Engineers, the Colorado School of Mines Potential Gas Committee and the United Nations Economic Commission for Europe Expert
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
Group on Resource Management. He has Bachelor of Science and Master of Science degrees in geology from Emory University in Atlanta.
Occidental has a Corporate Reserves Review Committee, (Reserves Committee), consisting of senior corporate officers, to review and approve Occidental’s oil and gas reserves. The Reserves Committee reports to the Audit Committee of Occidental’s Board of Directors during the year. Since 2003, Occidental has retained Ryder Scott, Company, L.P. (Ryder Scott), independent petroleum engineering consultants, to review its annual oil and gas reserve estimation processes. For additional reserves information, see Supplemental Oil and Gas Information under Item 8 of this Form 10-K. In 2020,2022, Ryder Scott conducted a process review of the methods and analytical procedures utilized by Occidental’s engineering and geological staff for estimating the proved reserves volumes, preparing the economic evaluations and determining the reserves classifications as of December 31, 2020,2022, in accordance with SEC regulatory standards. Ryder Scott reviewed the specific application of such methods and procedures for selected oil and gas properties considered to be a valid representation of Occidental’s 20202022 year-end total proved reserves portfolio. In 2020,2022, Ryder Scott reviewed approximately 30%42% of Occidental’s proved oil and gas reserves. Since being engaged in 2003, Ryder Scott has reviewed the specific application of Occidental’s reserve estimation methods and procedures for approximately 87%92% of Occidental’s existing proved oil and gas reserves.
Management retained Ryder Scott to provide objective third-party input on its methods and procedures and to gather industry information applicable to Occidental’s reserve estimation and reporting process. Ryder Scott has not been engaged to render an opinion as to the reasonableness of reserves quantities reported by Occidental. Occidental has filed Ryder Scott’s independent report as an exhibit to this Form 10-K.
Based on its reviews, including the data, technical processes and interpretations presented by Occidental, Ryder Scott has concluded that the overall procedures and methodologies Occidental utilized in estimating the proved reserves volumes, documenting the changes in reserves from prior estimates, preparing the economic evaluations and determining the reserves classifications for the reviewed properties are appropriate for the purpose thereof and comply with current SEC regulations.
INDUSTRY OUTLOOK
The oil and gas exploration and production industry is highly competitive, is subject to significant volatility due to various market conditions and operations are highly dependent on oil prices and, to a lesser extent, NGL and natural gas prices. Oil prices increased significantly in 2022. During 2022, as compared to 2021, the average annual $/Bbl of WTI crude increased to $94.23 from $67.91 and the average annual Brent price per barrel increased to $98.83 from $70.78.
Oil prices will continue to be affected by: (i) global supply and demand, which are generally a function of global economic conditions, inventory levels, production or supply chain disruptions, technological advances, regional market conditions and the actions of OPEC, other significant producers and governments; (ii) transportation capacity, infrastructure constraints, and costs in producing areas; (iii) currency exchange rates and inflation rates; and (iv) the effect of changes in these variables on market perceptions. The ongoing global impact of the Russia-Ukraine war and whether the oil industry will be able to sustain a continued supply response have resulted in an increase in benchmark oil prices year-over-year. Occidental does not operate or own assets in either Russia or Ukraine. It is expected that the price of oil will be volatile for the foreseeable future given the current geopolitical risks, the ongoing global impact of the Russia-Ukraine war, the evolving macro-economic environment and supply activity (as a result of COVID-19) from OPEC and non-OPEC oil producing countries and the Biden Administration’s releases from the US Strategic Petroleum Reserve.
NGL prices are related to the supply and demand for the components of products making up these liquids. Some of them more typically correlate to the price of oil while others are affected by natural gas prices as well as the demand for certain chemical products for which they are used as feedstock. In addition, infrastructure constraints magnify the pricing volatility from region to region.
Domestic natural gas prices and local differentials are strongly affected by local supply and demand fundamentals, as well as government regulations, global LNG demand and availability of transportation capacity from producing areas.
We expect that oil prices in the near term will continue to be influenced by the duration and severity of the COVID-19 pandemic and its resulting impact on oil and gas supply and demand.
These and other factors make it difficult to predict the future direction of oil, NGL and domestic gas prices reliably. For purposes of the current capital plan, Occidental will continue to focus on allocating capital to high return assets with the flexibility to adjust based on fluctuations in commodity prices. International gas prices are generally fixed under long-term contracts. Occidental continues to adjust capital expenditures in line with current economic conditions, such as supply chain constraints, rising interest rates, global logistics and high inflation, which has continued to disrupt global supply and demand balances, with the goal of keeping returns well above its cost of capital.
The timing, process and ultimate cost to transition to a less carbon-intensive economy remains largely unknown; various industry forecasts indicate a growing demand for hydrocarbons for the remainder of the current decade. Occidental believes its operational flexibility to achieve low development and operating costs to maximize full-cycle value of its assets and its knowledge and experience in CO2 separation, transportation, use, recycling and storage position its oil and gas segment to support Occidental’s transition to net zero as well as create opportunities in a low-carbon future.
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BUSINESS STRATEGY
OxyChem seeks to be a low-cost producer in order to generate cash flow in excess of its normal capital expenditure requirements and achieve above-cost-of-capital returns. OxyChem concentrates on the chlorovinyls chain, beginning with the co-production of caustic soda and chlorine. Caustic soda and chlorine are marketed to external customers. In addition, chlorine, together with ethylene, is converted through a series of intermediate products into PVC. OxyChem seeks to be a low-cost producer in order to generate cash flow in excess of its normal capital expenditure requirements and achieve above-cost-of-capital returns. OxyChem’s focus on chlorovinyls allows it to maximize the benefits of integration and take advantage of economies of scale. Capital is employed to sustain production capacity and to focus on projects and developments designed to improve the competitiveness of segment assets. Acquisitions and plant development opportunities may be pursued when they are expected to enhance the existing core chlor-alkali and PVC businesses or take advantage of other specific opportunities. The conversion of the Battleground chlor-alkali plant to membrane technology is expected to commence in 2023 with completion expected in 2026. In 2020,2022, capital expenditures for OxyChem totaled $255$322 million.
BUSINESS ENVIRONMENT
In 2020,Although the United States economic contraction, estimated to be 3.5%, wasgrowth lagged significantly lower than the 2.2% growth experienced in 2019, which resulted in lowerbehind that of 2021, demand for domestically produced products remained high, including liquid caustic soda and PVC. PricingLockdowns in China, along with Russia’s invasion of Ukraine increased the demand for U.S. produced products in 2022, as ethylene and energy costs remained advantaged over global pricing. Caustic soda prices were significantly higher in 2022 and PVC rebounded inpricing trended downward during the second half of 20202022, as supply chain constraints, rising interest rates, global logistics and finished higher than the 2019 average duehigh inflation continued to increased domesticdisrupt global supply and demand and lower supply. Caustic soda prices were lower in 2020, partially offset by lower ethylene and energy costs.balances.
BUSINESS REVIEW
BASIC CHEMICALS
TheDespite the slower U.S. economic contraction due to the COVID-19 pandemic resultedgrowth in lower domestic demand as the industry2022, chlor-alkali operating rates decreased by 8%increased compared to 2019. Liquid caustic soda prices2021 as the U.S. maintained its competitive advantage in energy and feedstock costs. Pricing and margins for most products were lower both domestically and globallyhigher in 20202022 due to weakerstrong demand in the pulp and paper and industrialmost market segments, which was partially offset by lower energy prices than in 2019. Stronger chlorine derivative demand in relation to caustic soda resulted in persistent downward pressure on caustic soda pricing.and weather events and other supply disruptions restricted supply.
VINYLS
DuePVC demand softened in 2022 from record highs in 2021 resulting in a 7% decrease in domestic PVC demand. Export demand strengthened in 2022 by 46% compared to 2021. Year over year operating rates were flat in 2022 due to a softening PVC market during the second half of 2022 that was offset by the weather-related events experienced in early 2021. Higher interest rates, lower housing starts, and inflation contributed to the impact oflower domestic PVC demand and US producers shifted available volumes to the COVID-19 pandemic and supply interruptions during a very active hurricane season, industry demand for PVC in 2020 decreased year-over-year by 4%, resulting in 6% lower operating rates. Domestic demand was up 5.4% while export demand was down 22% from 2019. Second half 2020 housing starts, construction and home improvement markets were the main contributors for the strong rebound in domestic demand. US domestic producers grappled with extended production outages resulting in lower PVC availability for export markets. Export volume
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
PVC exports represented 28%27% of total North American production. Industry PVC margins increasedproduction in 2020 due2022 compared to a strong price environment driven by higher than expected demand and limited supply.19% in 2021.
INDUSTRY OUTLOOK
Industry performance will depend on the health of the global economy andeconomy. Response to inflation will continue to control the effectiveness of the vaccine rollouts. Continued recovery from 2020 should result in improvement in the housing, construction, automotive and durable goods markets. The housing and construction as well as automotivesectors during 2023. Automotive markets are expected to strengthen over the next year. Margins alsoimprove as semiconductor supply normalizes and demand responds. Product margins will depend on market supply and demand balances, and feedstock and energy prices. Recoveryprices, supply chain interruptions, labor constraints and rising inflation rates. Further recovery in the petroleum industry should strengthen the demand and pricing of a numbermargins for some of Occidental’s products that are consumed by industry participants. U.S. commodity export markets will continue tocould be impacted by the relative strength of the U.S. dollar.
BASIC CHEMICALS
Demand for basic chemicals is expected to improve in 2021 over 2020 levels. Improvementdecline from the robust levels of 2022. Demand in most market segments is expected with improvement into follow the overall economy.trend of the general economy throughout 2023. Demand for chlorine and derivatives willshould gradually improve with continuedacross the year as international growth inreturns and the domestic housing, general construction and automotive markets.markets begin to stabilize. Demand for alkali products, particularly caustic soda, will improvemay decline moderately with growthlower demand in the pulp and paper, industrial and alumina markets. Chlor-alkali operating rates should improve moderatelyremain relatively flat overall in comparison with higher demand and2022 due to continued competitiveglobally advantaged energy and raw material pricing as compared to global feedstock costs.
VINYLS
Domestic PVC demand is expected to improveremain neutral to lower in 2021 over 2020 levels. Growth in residential2023. Residential construction spending andis expected to be lower in 2023, while new domestic infrastructure projects is forecast to drive domestic growth in 2021. Although overall PVCand recovering global demand is expected to remain strong in North America, operating rates are anticipated to remain relatively flat in 2021 as newoffset the domestic decline. New domestic PVC capacity came online in 2022 but is not expected to enter the market in the second half of the year.have a material impact on PVC production rates.
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| MIDSTREAM AND MARKETING SEGMENT |
BUSINESS STRATEGY
The midstream and marketing segment strives to maximize realized value by optimizing the use of its gathering, processing, transportation, storage and terminal commitments and by providing the oil and gas segment access to domestic and international markets. To generate returns, the segment evaluates opportunities across the value chain and uses its assets to provide services to Occidental’s subsidiaries, as well as third parties. The midstream and marketing segment operates or contracts for services on gathering systems, gas plants, co-generation facilities and storage facilities and invests in entities that conduct similar activities. As of December 31, 2019, Occidental began accounting for its ownership investment in WES under the equity method of accounting. See Note 16 - Investments and Related-Party Transactions in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information. The midstream and marketing segment has equity investments in WES and Dolphin Energy Limited. WES owns gathering systems, plants and pipelines and earns revenue from fee-based and service-based contracts with Occidental and third parties. Dolphin Energy Limited owns and operates a pipeline which connects its gas processing and compression plant in Qatar and its receiving facilities in UAE, and uses its network of Dolphin Energy Limited-owned and other existing leased pipelines to supply natural gas across the UAE and to Oman. Also included in the midstream and marketing segment is OLCV. OLCV seeks to leverage Occidental’s carbon management expertise that is derived from its EOR operations to develop carbon capture, utilization and storage facilities that are expected to source anthropogenic CO2 and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducing emissions.
This segment also seeks to minimize the costs of gas and power used in Occidental’s various businesses. Capital is employed to sustain or expand assets to improve the competitiveness of Occidental’s businesses. In 2020,2022, capital expenditures related to the midstream and marketing segment totaled $50$268 million.
Also included in the midstream and marketing segment is OLCV. OLCV seeks to leverage Occidental’s carbon management expertise through the development of CCUS projects, and invests in emerging low-carbon technologies that are expected to reduce our carbon footprint and enable others to do the same.
BUSINESS ENVIRONMENT
Midstream and marketing segment earnings are affected by the performance of its various businesses, including its marketing, gathering and transportation, gas processing and power-generation assets. The marketing business aggregates, markets and stores Occidental and third-party volumes. Marketing performance is affected primarily by commodity price changes and margins in oil and gas transportation and storage programs. The marketing business results can experience significant volatility depending on commodity price changesprices and the Midland-to-Gulf-Coast oil spreads. The Midland-to-Gulf-Coast oil spreads have decreased from an average of $6.58$0.48 per barrel in 20192021 to $1.43$0.36 per barrel for the year ended December 31, 2020 and averaging $0.59 per barrel in the fourth quarter of 2020.2022. A $0.25 change in the Midland-to-Gulf- CoastMidland-to-Gulf-Coast oil spreads impacts total year operating cash flows by approximately $65 million. In 2020, Permian to Gulf Coast transportation capacity increased as new third-party pipelines were completed. This along with reduction in Permian Basin production, reduced the Midland-to-Gulf-Coast oil spreads. Gas gathering, processing and transportation results are affected by fluctuations in commodity prices and the volumes that are processed and transported through the segment’s plants, as well
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as the margins obtained on related services from investments in which Occidental has an equity interest. The 2020 declines in NGL prices and sulfur prices negatively impacted the gas processing business.
BUSINESS REVIEW
MARKETING
The marketing group markets substantially all of Occidental’s oil, NGL and natural gas production as well as trades aroundand optimizes its assets, including contracted transportation and storage capacity. Occidental’s third-party marketing activities focus on purchasing oil, NGL and natural gas for resale from parties whose oil and gas supply is located near its transportation and storage assets.capacity. These purchases allow Occidental to aggregate volumes to better utilize and optimize its assets. In 2020,2022, compared to the prior year, marketing results were negatively impacted by the declinetiming of crude oil sales, partially offset by higher gas marketing margin from transportation capacity optimization.
DELIVERY AND TRANSPORTATION COMMITMENTS
Occidental has made long-term commitments to certain refineries and other buyers to deliver oil, NGL and natural gas. The total amount contracted to be delivered is approximately 80 MMbbl of oil through 2025, 567 MMbbl of NGL through 2029 and 845 Bcf of gas through 2029. The price for these deliveries is set at the time of delivery of the product.
Occidental has crude pipeline take-or-pay capacity of approximately 850 Mbbl/d to the Gulf Coast, leased crude storage capacity of approximately 10 MMbbl and capacity at the crude terminal of approximately 525 Mbbl/d. Certain of Occidental’s crude pipeline take-or-pay agreements expire in the Midland-to-Gulf-Coast oil spreads.2025 and take-or-pay commitments will reduce by two thirds by 2027.
PIPELINE
Occidental’s pipeline business mainly consists of its 24.5% ownership interest in Dolphin Energy Limited. Dolphin Energy LimitedDEL. DEL owns and operates a 230-mile-long, 48-inch-diameter natural gas pipeline, (Dolphin Pipeline),known as the Dolphin Pipeline, which transports dry natural gas from Qatar to the UAE and Oman. The Dolphin Pipeline has capacity to transport up to 3.2 Bcf/d and currently transports approximately 2.22.0 Bcf/d and up to 2.52.2 Bcf/d in the summer months.
GAS PROCESSING, GATHERING AND CO2
Occidental processes its own and third-party domestic wet gas to extract NGL and other gas byproducts, including CO2 and delivers dry gas to pipelines. Margins primarily result from the difference between inlet costs of wet gas and market prices for NGL.
As of December 31, 2020,2022, Occidental has a 2%owned all of the 2.3% non-voting general partner interest and a 51.8%49.5% of the limited partner interestunits in WES andWES. On a combined basis, with its 2% non-voting limited partner interest in WES Operating, a subsidiary of WES. As of December 31, 2020, on a combined basis, Occidental's total effective economic interest in WES and its subsidiaries is 53.5%. Occidental intends to reduce its limited partner ownership interest in WES to below 50%was 51.7%. See Note 1 - Summary of Significant Accounting Policies in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information regarding
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Occidental’s equity method investment in WES. WES owns gathering systems, plants and pipelines and earns revenue from fee-based and service-based contracts with Occidental and third parties.
Occidental’s 40% participating interest in Al Hosn Gas also includes sour gas processing facilities that are designed to process 1.31.33 Bcf/d of natural gas and separate it into salable gas, condensate, NGL and sulfur. In 2020,2022, the facilitiesproject produced 11,300 tons per day568 MMcf/d of natural gas, 88 Mbbl/d of NGL and condensate, and 10,700 tons/d of sulfur, of which approximately 4,500 tons per day was Occidental’s net share.share was 227 MMcf/d of natural gas, 35 Mbbl/d of NGL and condensate and 4,280 tons/d of sulfur.
In 2020,2022, compared to the prior year, gas processing, gathering and CO2 results decreasedincreased primarily due to lowerhigher sulfur and NGL prices and sulfur prices, which negatively impacted the gas processing business.prices.
POWER GENERATION FACILITIES
Earnings from power and steam generation facilities are derived from sales to affiliates and third parties.
LOW CARBONLOW-CARBON VENTURES
OLCV was formed to execute on Occidental’s vision to reduce global emissions and provide a more sustainable future through low carbonthe development of low-carbon energy and products. OLCV capitalizes on Occidental’s extensive experience in utilizing CO2 for EOR by investing in technologies, developingits development of CCUS projects and providing services to third parties to facilitate and accelerate the implementation of carbon capture, utilization and storage projects and opportunities for zero-carbon power.their CCUS projects. Moreover, OLCV is fostering newemerging technologies, including DAC and low-carbon power sources, and other business models with the potential to position Occidental as a leader in the production of low-carbon oilenergy and products.
Occidental has developed standards and protocols recognized by the EPA for monitoring, reporting and verifying the amount, safety and permanence of CO2 stored through secure geologic sequestration. The companyOccidental holds the nation’s first two EPA-approved monitoring, reporting and verification plans for geologic sequestration through EOR production.production and obtained a third monitoring, reporting and verification plan in 2021. In 2022, OLCV acquired approximately three hundred thousand acres of pore space. In 2022, Occidental also commenced EPA Class 6 permitting with the intention of developing five sequestration hubs.
OLCV commenced construction on the world’s largest DAC facility in 2022, which is expected to be online in 2025. OLCV is also currently conducting front-end engineering design work and feasibility studies on a number of projects to capture and sequester CO2, either from the atmosphere or from industrial point sources. In 2023, OLCV plans to invest between $100 million and $500 million, dependent upon potential partner participation, to pursue various projects.
The profitability of sequestration projects is dependent upon the costs of developing, building and operating sequestration infrastructure, demand for sequestration services from emitters and the availability of certain tax attributes and credits generated from the capture and storage of CO2.
In August 2022, Congress passed the Inflation Reduction Act that contains, among other provisions, certain tax incentives related to climate change and clean energy. These incentives may attract more third-party investment of OLCV’s projects which may help accelerate certain projects. The ultimate impact of the Inflation Reduction Act on Occidental’s emerging low-carbon businesses and net-zero pathway will depend on a number of factors, interpretations and assumptions as well as additional regulatory guidance.
INDUSTRY OUTLOOK
Midstream and marketing segment results can experience volatility depending on commodity price changes, demand impacting export sales and the Midland-to-Gulf-Coast oil spreadsspreads. Gas gathering, processing and commodity price changes. To a lesser extent, declinestransportation results are affected by fluctuations in commodity prices including NGL and sulfur prices, reduce the results forvolumes that are processed and transported through the gas processing business.segment’s plants, as well as the margins obtained on related services from investments in which Occidental has an equity interest.
Throughout 2022, the U.S. experienced economy-wide cost increases, which could increase the cost of sequestration projects. Occidental saw increased interest from third parties in providing sequestration services during the year. Additionally, grants, credits and other tax-advantaged low-carbon attributes continue to be actively discussed at both state and federal levels. These trends are expected to continue, which Occidental believes will enhance the economics of sequestration projects.
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| SEGMENT RESULTS OF OPERATIONS AND ITEMS AFFECTING COMPARABILITY |
SEGMENT RESULTS OF OPERATIONS
Segment earnings exclude income taxes, interest income, interest expense, environmental remediation expenses, unallocated corporate expenses and discontinued operations, but include gains and losses from divestitures of segment assets and income from the segments’ equity investments. Seasonality is not a primary driver of changes in Occidental’s consolidated quarterly earnings during the year.
The following table sets forth the sales and earnings of each operating segment and corporate items for the years ended December 31:
| | millions, except per share amounts | millions, except per share amounts | | 2020 | | 2019 | | 2018 | millions, except per share amounts | | 2022 | | 2021 | | 2020 |
NET SALES (a) | NET SALES (a) | | NET SALES (a) | |
| Oil and gas | Oil and gas | | $ | 13,066 | | | $ | 13,941 | | | $ | 10,441 | | Oil and gas | | $ | 27,165 | | | $ | 18,941 | | | $ | 13,066 | |
| Chemical | Chemical | | 3,733 | | | 4,102 | | | 4,657 | | Chemical | | 6,757 | | | 5,246 | | | 3,733 | |
| Midstream and marketing | Midstream and marketing | | 1,768 | | | 4,132 | | | 3,656 | | Midstream and marketing | | 4,136 | | | 2,863 | | | 1,768 | |
| Eliminations | Eliminations | | (758) | | | (1,264) | | | (930) | | Eliminations | | (1,424) | | | (1,094) | | | (758) | |
| Total | Total | | $ | 17,809 | | | $ | 20,911 | | | $ | 17,824 | | Total | | $ | 36,634 | | | $ | 25,956 | | | $ | 17,809 | |
| SEGMENT RESULTS AND EARNINGS | SEGMENT RESULTS AND EARNINGS | | SEGMENT RESULTS AND EARNINGS | |
| Domestic | Domestic | | $ | (8,758) | | | $ | 838 | | | $ | 621 | | Domestic | | $ | 10,439 | | | $ | 2,900 | | | $ | (8,758) | |
| International | International | | (742) | | | 1,851 | | | 1,896 | | International | | 2,580 | | | 1,497 | | | (742) | |
| Exploration | Exploration | | (132) | | | (169) | | | (75) | | Exploration | | (216) | | | (252) | | | (132) | |
| Oil and gas | Oil and gas | | (9,632) | | | 2,520 | | | 2,442 | | Oil and gas | | 12,803 | | | 4,145 | | | (9,632) | |
Chemical | Chemical | | 664 | | | 799 | | | 1,159 | | Chemical | | 2,508 | | | 1,544 | | | 664 | |
| Midstream and marketing | Midstream and marketing | | (4,175) | | | 241 | | | 2,802 | | Midstream and marketing | | 273 | | | 257 | | | (4,175) | |
| Total | Total | | $ | (13,143) | | | $ | 3,560 | | | $ | 6,403 | | Total | | $ | 15,584 | | | $ | 5,946 | | | $ | (13,143) | |
| Unallocated corporate items | Unallocated corporate items | | Unallocated corporate items | |
| Interest expense, net | Interest expense, net | | (1,424) | | | (1,002) | | | (356) | | Interest expense, net | | (1,030) | | | (1,614) | | | (1,424) | |
| Income tax benefit (expense) | Income tax benefit (expense) | | 2,172 | | | (861) | | | (1,477) | | Income tax benefit (expense) | | (813) | | | (915) | | | 2,172 | |
| Other | Other | | (1,138) | | | (2,204) | | | (439) | | Other | | (437) | | | (627) | | | (1,138) | |
| Income (loss) from continuing operations | Income (loss) from continuing operations | | $ | (13,533) | | | $ | (507) | | | $ | 4,131 | | Income (loss) from continuing operations | | $ | 13,304 | | | $ | 2,790 | | | $ | (13,533) | |
| Discontinued operations, net | Discontinued operations, net | | (1,298) | | | (15) | | | — | | Discontinued operations, net | | — | | | (468) | | | (1,298) | |
| Net income (loss) | Net income (loss) | | (14,831) | | | (522) | | | 4,131 | | Net income (loss) | | 13,304 | | | 2,322 | | | (14,831) | |
| Less: Net loss attributable to noncontrolling interests | | — | | | (145) | | | — | | |
| | Less: Preferred stock dividends | Less: Preferred stock dividends | | (844) | | | (318) | | | — | | Less: Preferred stock dividends | | (800) | | | (800) | | | (844) | |
| Net income (loss) attributable to common stockholders | Net income (loss) attributable to common stockholders | | $ | (15,675) | | | $ | (985) | | | $ | 4,131 | | Net income (loss) attributable to common stockholders | | $ | 12,504 | | | $ | 1,522 | | | $ | (15,675) | |
| Net income (loss) attributable to common stockholders—basic | Net income (loss) attributable to common stockholders—basic | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.40 | | Net income (loss) attributable to common stockholders—basic | | $ | 13.41 | | | $ | 1.62 | | | $ | (17.06) | |
| Net income (loss) attributable to common stockholders—diluted | Net income (loss) attributable to common stockholders—diluted | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.39 | | Net income (loss) attributable to common stockholders—diluted | | $ | 12.40 | | | $ | 1.58 | | | $ | (17.06) | |
(a)Intersegment sales eliminate upon consolidation and are generally made at prices approximating those that the selling entity would be able to obtain in third-party transactions.
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ITEMS AFFECTING COMPARABILITY
OIL AND GAS SEGMENT
Results of Operations
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Segment Sales | Segment Sales | | $ | 13,066 | | | $ | 13,941 | | | $ | 10,441 | | Segment Sales | | $ | 27,165 | | | $ | 18,941 | | | $ | 13,066 | |
Segment Results (a) | Segment Results (a) | | Segment Results (a) | |
| Domestic | Domestic | | $ | (8,758) | | | $ | 838 | | | $ | 621 | | Domestic | | $ | 10,439 | | | $ | 2,900 | | | $ | (8,758) | |
| International | International | | (742) | | | 1,851 | | | 1,896 | | International | | 2,580 | | | 1,497 | | | (742) | |
| Exploration | Exploration | | (132) | | | (169) | | | (75) | | Exploration | | (216) | | | (252) | | | (132) | |
| Total | Total | | $ | (9,632) | | | $ | 2,520 | | | $ | 2,442 | | Total | | $ | 12,803 | | | $ | 4,145 | | | $ | (9,632) | |
| | Items affecting comparability | Items affecting comparability | | Items affecting comparability | |
Asset impairments and related items - domestic (b) | | $ | (5,904) | | | $ | (288) | | | $ | — | | |
Asset impairments and related items - international (c) | | $ | (1,195) | | | $ | (39) | | | $ | (416) | | |
Asset sale gains (losses), net - domestic (d) | | $ | (1,275) | | | $ | 475 | | | $ | — | | |
Asset sale losses, net - international (e) | | $ | (353) | | | $ | — | | | $ | — | | |
| Oil and natural gas collars mark-to-market gains (losses) | | $ | 1,064 | | | $ | (107) | | | $ | — | | |
Asset sale gains (losses), net - domestic (b) | | Asset sale gains (losses), net - domestic (b) | | $ | 148 | | | $ | 27 | | | $ | (1,275) | |
Asset sale gains (losses), net - international (c) | | Asset sale gains (losses), net - international (c) | | $ | 55 | | | $ | 43 | | | $ | (353) | |
Asset impairments and related items - domestic (d) | | Asset impairments and related items - domestic (d) | | $ | — | | | $ | (282) | | | $ | (5,904) | |
Asset impairments and related items - international (e) | | Asset impairments and related items - international (e) | | $ | — | | | $ | — | | | $ | (1,195) | |
Oil, natural gas and CO2 mark-to-market gains (losses) | | Oil, natural gas and CO2 mark-to-market gains (losses) | | $ | — | | | $ | (280) | | | $ | 1,090 | |
| Rig terminations and other - domestic | Rig terminations and other - domestic | | $ | (59) | | | $ | — | | | $ | — | | Rig terminations and other - domestic | | $ | — | | | $ | — | | | $ | (59) | |
| Rig terminations and other - international | Rig terminations and other - international | | $ | (13) | | | $ | — | | | $ | — | | Rig terminations and other - international | | $ | — | | | $ | — | | | $ | (13) | |
(a)Results included significant items affecting comparability discussed in the footnotes below.
(b)The 20202022 amount included pre-tax impairments$148 million of $4.5 billiongains, primarily related to domestic onshore unproved acreage as well as $1.3 billion primarily related to other domestic onshorethe sale of certain non-strategic assets andin the Gulf of Mexico.Permian Basin. The 20192021 amount included $285$27 million of impairment and related charges associated with domestic undeveloped leases that were set to expire in the near-term, where Occidental had no plans to pursue exploration activities.
(c)Thepost-closing consideration earned from 2020 amount included $1.2 billion of impairment and related charges associated with Occidental’s proved properties in Algeria and Oman. The 2019 amount related to Occidental’s mutually agreed early terminationasset sales as a result of certain Qatar concessions. The 2018 amount consisted of impairmentproduction and related charges associated with certain Qatar concessions.
(d)pricing targets being met. The 2020 amount included a $440 million loss on the sale of Occidental’s mineral and fee surface acres in Wyoming, Colorado and Utah and losses of $820 million related to the sale of non-core, largely non-operated acreage in the Permian Basin.
(c)The 20192022 amount included gain on$55 million related to post-closing consideration earned from 2020 asset sales as a result of certain production and pricing targets being met as well as the closing of the sale of certain assets that were negotiated with the 2020 Colombia divestiture. The 2021 amount primarily included $55 million in post-closing consideration earned from 2020 asset sales as a portionresult of Occidental’s joint venture with ECOPETROL S.A. (Ecopetrol)certain production and a loss on sale of real estate assets.
(e)pricing targets being met. The 2020 amount included a loss on the sale of Occidental’s Colombia assets of $353 million.
(d)The 2021 amount included $282 million of asset impairments primarily related to undeveloped leases that either expired or were set to expire in the near term where Occidental had no plans to pursue exploration activities. The 2020 amount included pre-tax impairments of $4.5 billion primarily related to domestic onshore unproved acreage as well as $1.3 billion primarily related to other domestic onshore assets and the Gulf of Mexico.
(e)The 2020 amount included $1.2 billion of impairment and related charges associated with Occidental’s proved properties in Algeria and Oman.
| | | | | | | | |
| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
Average Realized Prices
The following table sets forth the average realized prices for oil, NGL and natural gas from ongoing operations for each of the three years in the period ended December 31, 2020,2022, and includes a year-over-year change calculation:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 2022 | | Year over Year Change | | 2021 | | Year over Year Change | | 2020 |
| Average Realized Prices | | | | | | | | | | |
Oil ($/Bbl) | | | | | | | | | | |
| United States | | $ | 94.12 | | | 42 | % | | $ | 66.39 | | | 82 | % | | $ | 36.39 | |
| International | | $ | 95.46 | | | 47 | % | | $ | 65.08 | | | 57 | % | | $ | 41.50 | |
| Total worldwide | | $ | 94.36 | | | 43 | % | | $ | 66.14 | | | 77 | % | | $ | 37.34 | |
NGL ($/Bbl) | | | | | | | | | | |
| United States | | $ | 35.69 | | | 17 | % | | $ | 30.62 | | | 156 | % | | $ | 11.98 | |
| International | | $ | 34.09 | | | 30 | % | | $ | 26.13 | | | 61 | % | | $ | 16.22 | |
| Total worldwide | | $ | 35.48 | | | 18 | % | | $ | 30.01 | | | 139 | % | | $ | 12.58 | |
Natural Gas ($/Mcf) | | | | | | | | | | |
| United States | | $ | 5.48 | | | 66 | % | | $ | 3.30 | | | 180 | % | | $ | 1.18 | |
| International | | $ | 1.89 | | | 12 | % | | $ | 1.69 | | | 1 | % | | $ | 1.67 | |
| Total worldwide | | $ | 4.51 | | | 57 | % | | $ | 2.87 | | | 119 | % | | $ | 1.31 | |
Domestic oil and gas results, excluding significant items affecting comparability, increased in 2022 compared to 2021 primarily due to higher realized oil, NGL and natural gas prices and lower DD&A rates, partially offset by higher lease operating costs.
International oil and gas results, excluding significant items affecting comparability, increased in 2022 compared to 2021 primarily due to higher oil prices.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 2020 | | Year over Year Change | | 2019 | | Year over Year Change | | 2018 |
| Average Realized Prices | | | | | | | | | | |
Oil ($/Bbl) | | | | | | | | | | |
| United States | | $ | 36.39 | | | (33) | % | | $ | 54.31 | | | (4) | % | | $ | 56.30 | |
| Latin America | | $ | 38.80 | | | (32) | % | | $ | 57.26 | | | (11) | % | | $ | 64.32 | |
| Middle East/Africa | | $ | 41.52 | | | (33) | % | | $ | 62.03 | | | (8) | % | | $ | 67.69 | |
| Total worldwide | | $ | 37.41 | | | (34) | % | | $ | 56.32 | | | (7) | % | | $ | 60.64 | |
NGL ($/Bbl) | | | | | | | | | | |
| United States | | $ | 11.98 | | | (25) | % | | $ | 16.03 | | | (42) | % | | $ | 27.64 | |
| Middle East/Africa | | $ | 16.22 | | | (26) | % | | $ | 21.85 | | | (6) | % | | $ | 23.20 | |
| Total worldwide | | $ | 12.58 | | | (27) | % | | $ | 17.20 | | | (34) | % | | $ | 26.25 | |
Natural Gas ($/Mcf) | | | | | | | | | | |
| United States | | $ | 1.18 | | | (10) | % | | $ | 1.31 | | | (18) | % | | $ | 1.59 | |
| Latin America | | $ | 5.41 | | | (23) | % | | $ | 7.01 | | | 9 | % | | $ | 6.43 | |
| Total worldwide | | $ | 1.31 | | | (10) | % | | $ | 1.45 | | | (10) | % | | $ | 1.62 | |
The following table presents an analysis of the impacts of changes in average realized prices and sales volumes with regard to Occidental's domestic and international oil and gas revenue:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Increase (Decrease) Related to | | | |
| millions | | Year Ended December 31, 2021 | (a) | Price Realizations | | Net Sales Volumes | | Year Ended December 31, 2022 | (a) |
| United States Revenue | | | | | | | | | |
| Oil | | $ | 12,072 | | | $ | 5,118 | | | $ | 231 | | | $ | 17,421 | | |
| NGL | | 2,203 | | | 332 | | | 96 | | | 2,631 | | |
| Natural gas | | 1,524 | | | 969 | | | (71) | | | 2,422 | | |
| Total | | $ | 15,799 | | | $ | 6,419 | | | $ | 256 | | | $ | 22,474 | | |
| International Revenue | | | | | | | | | |
Oil (b) | | $ | 2,844 | | | $ | 902 | | | $ | 189 | | | $ | 3,935 | | |
| NGL | | 325 | | | 85 | | | 11 | | | 421 | | |
| Natural gas | | 291 | | | 23 | | | (3) | | | 311 | | |
| Total | | $ | 3,460 | | | $ | 1,010 | | | $ | 197 | | | $ | 4,667 | | |
(a) Excludes "other" oil and gas revenue. See Note 2 - Revenue in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for additional information regarding other revenue. (b) Includes the impact of international production sharing contracts.
| | | | | |
3642 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
Domestic oil and gas results, excluding significant items affecting comparability, decreased in 2020 compared to 2019 primarily due to lower realized oil, NGL and natural gas prices, partially offset by higher crude oil, NGL and natural gas sales volumes mostly due to additional production from the Acquisition.
International oil and gas results, excluding significant items affecting comparability, decreased in 2020 compared to 2019 primarily due to a decrease in realized commodity prices as well as lower volumes as a result of exiting Qatar in 2019.
Production
The following table sets forth the production volumes of oil, NGL and natural gas per day from ongoing operations for each of the three years in the period ended December 31, 20202022, and includes a year-over-year change calculation:
| | Production per Day, Ongoing Operations (Mboe/d) | Production per Day, Ongoing Operations (Mboe/d) | | 2020 | | Year over Year Change | | 2019 | | Year over Year Change | | 2018 | Production per Day, Ongoing Operations (Mboe/d) | | 2022 | | Year over Year Change | | 2021 | | Year over Year Change | | 2020 |
| United States | United States | | | | | | | United States | | | | | | |
| Permian Resources | | 435 | | | 23 | % | | 355 | | | 66 | % | | 214 | | |
| Permian EOR | | 140 | | | (9) | % | | 154 | | | — | % | | 154 | | |
| DJ Basin | | 293 | | | 144 | % | | 120 | | | N/A | | — | | |
| Permian | | Permian | | 513 | | | 5 | % | | 487 | | | (15) | % | | 575 | |
| Rockies & Other Domestic | | Rockies & Other Domestic | | 277 | | | (8) | % | | 302 | | | (9) | % | | 332 | |
| Gulf of Mexico | Gulf of Mexico | | 130 | | | 124 | % | | 58 | | | N/A | | — | | Gulf of Mexico | | 147 | | | 2 | % | | 144 | | | 11 | % | | 130 | |
| Other Domestic | | 39 | | | 44 | % | | 27 | | | 575 | % | | 4 | | |
| Total | Total | | 1,037 | | | 45 | % | | 714 | | | 92 | % | | 372 | | Total | | 937 | | | 0 | % | | 933 | | | (10) | % | | 1,037 | |
| Latin America | | 32 | | | (6) | % | | 34 | | | 6 | % | | 32 | | |
| Middle East / Africa | | |
| Algeria | | 44 | | | 83 | % | | 24 | | | N/A | | — | | |
| International | | International | |
| Algeria & Other International | | Algeria & Other International | | 47 | | | 7 | % | | 44 | | | (2) | % | | 45 | |
| Al Hosn Gas | Al Hosn Gas | | 78 | | | (5) | % | | 82 | | | 12 | % | | 73 | | Al Hosn Gas | | 73 | | | (4) | % | | 76 | | | (3) | % | | 78 | |
| Dolphin | Dolphin | | 44 | | | 5 | % | | 42 | | | 5 | % | | 40 | | Dolphin | | 37 | | | (8) | % | | 40 | | | (9) | % | | 44 | |
| Oman | Oman | | 85 | | | (4) | % | | 89 | | | 3 | % | | 86 | | Oman | | 65 | | | (12) | % | | 74 | | | (13) | % | | 85 | |
| Total | Total | | 251 | | | 6 | % | | 237 | | | 19 | % | | 199 | | Total | | 222 | | | (5) | % | | 234 | | | (7) | % | | 252 | |
| Total Production from Ongoing Operations | Total Production from Ongoing Operations | | 1,320 | | | 34 | % | | 985 | | | 63 | % | | 603 | | Total Production from Ongoing Operations | | 1,159 | | | (1) | % | | 1,167 | | | (9) | % | | 1,289 | |
| Operations exited or exiting | | 30 | | | (32) | % | | 44 | | | (20) | % | | 55 | | |
Total Production (Mboe/d) (a) | | 1,350 | | | 31 | % | | 1,029 | | | 56 | % | | 658 | | |
Operations exited (a) | | Operations exited (a) | | — | | | (100) | % | | 16 | | | (72) | % | | 58 | |
Total Production (Mboe/d) (b) | | Total Production (Mboe/d) (b) | | 1,159 | | | (2) | % | | 1,183 | | | (12) | % | | 1,347 | |
(a)Operations exited include the Ghana assets (sold in October 2021) and the Colombia onshore assets (sold in December 2020).
(b)Natural gas volumes have been converted to Boe based on energy content of six Mcf of gas to one barrel of oil. Boe equivalent does not necessarily result in price equivalency. Please refer to the Supplemental Oil and Gas Information (unaudited) section of this Form 10-K for additional information on oil and gas production and sales.
Average daily production volumes from ongoing operations remained materially consistent in 2022 as compared to 2021. Production increased in 2020 compared to 2019 primarilythe Permian Basin due to increased development activity, which was partially offset by a full yeardecrease in production, especially natural gas, in the DJ Basin reflecting reduced capital investment and the impact of rising commodity prices that reduce Occidental's share of production associated with the assets acquired from the Acquisition.under international production sharing contracts.
Lease Operating Expense
The following table sets forth the average lease operating expense per Boe from ongoing operations for each of the three years in the period ended December 31, 2020:2022:
| | | | | | | | | | | | | | | | | | | | |
| | 2020 | | 2019 | | 2018 |
| Average lease operating expense per Boe | | $6.38 | | $9.07 | | $11.52 |
| | | | | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 | | 2020 |
| Average lease operating expense per Boe | | $ | 9.52 | | | $ | 7.58 | | | $ | 6.38 | |
Average lease operating expense per Boe decreasedincreased in 20202022 compared to 20192021 primarily dueas a result of inflationary pressures which led to operational efficiencies related to downholehigher workover, support and maintenance costs in the Permian Basin, Rockies and supports.Other and Gulf of Mexico, as well as higher purchase injectant costs in the Permian Basin.
| | | | | |
OXY 20202022 FORM 10-K | 3743 |
| | | | | | | | |
| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
CHEMICAL SEGMENT
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Segment Sales | Segment Sales | | $ | 3,733 | | | $ | 4,102 | | | $ | 4,657 | | Segment Sales | | $ | 6,757 | | | $ | 5,246 | | | $ | 3,733 | |
| Segment Results | Segment Results | | $ | 664 | | | $ | 799 | | | $ | 1,159 | | Segment Results | | $ | 2,508 | | | $ | 1,544 | | | $ | 664 | |
Chemical segment results decreasedincreased in 20202022 compared to 20192021 due to lowerimproved demand and stronger realized prices across most product lines, including caustic soda, prices and overall lower sales volumes as a result of the COVID-19 pandemic, partially offset by lower natural gashigher raw material costs, and lower plant spending.primarily energy costs.
MIDSTREAM AND MARKETING SEGMENT
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Segment Sales | Segment Sales | | $ | 1,768 | | | $ | 4,132 | | | $ | 3,656 | | Segment Sales | | $ | 4,136 | | | $ | 2,863 | | | $ | 1,768 | |
Segment Results (a) | Segment Results (a) | | $ | (4,175) | | | $ | 241 | | | $ | 2,802 | | Segment Results (a) | | $ | 273 | | | $ | 257 | | | $ | (4,175) | |
| | Items affecting comparability | Items affecting comparability | | Items affecting comparability | |
Asset and equity investment sale gains (losses) (b) | | $ | (46) | | | $ | 114 | | | $ | 907 | | |
Asset impairments and other charges (c) | | $ | (4,194) | | | $ | (1,002) | | | $ | — | | |
Interest rate swaps mark-to-market, net (d) | | $ | — | | | $ | 30 | | | $ | — | | |
Asset sales gains (losses) and others, net (b) | | Asset sales gains (losses) and others, net (b) | | $ | 98 | | | $ | 124 | | | $ | (46) | |
| Derivative gains (losses), net | | Derivative gains (losses), net | | $ | (259) | | | $ | (252) | | | $ | 97 | |
Goodwill impairments and other charges (c) | | Goodwill impairments and other charges (c) | | $ | — | | | $ | (21) | | | $ | (4,194) | |
(a)Results included significant items affecting comparability listeddiscussed in the footnotes below.
(b)The 2022 amount included $62 million relating to a gain on the sale of 10 million limited partner units in WES and a $36 million gain on the sale of a joint venture. The 2021 amount included a $102 million gain from the sale of 11.5 million limited partner units in WES. The 2020 amount represented a loss on the exchange of WES common units to retire a $260 million note. The 2019 amount represented a $114 million gain on the sale of an equity investment in Plains All American Pipeline, L.P. and Plains GP Holdings, L.P. (together, Plains). The 2018 amount represented a gain on sale of non-core domestic midstream assets.
(c)The 2020 amount included a $2.7 billion other-than-temporary impairment of the equity investment in WES and $1.4 billion of impairments related to the write-off of goodwill and a loss from an equity investment related to WES’ write-off of its goodwill. The 2019 amount included a $1 billion charge as a result of recording Occidental’s investment in WES at fair value as of December 31, 2019 upon the loss of control.
(d)The 2019 amount represented a $30 million mark-to-market gain on an interest rate swap for WES.
Midstream and marketing segment results, excluding items affecting comparability, decreasedincreased in 20202022 compared to 2019,2021, primarily due to lowerhigher equity income from WES, improved gas marketing marginsmargin from transportation capacity optimization and improved sulfur prices at Al Hosn Gas, partially offset by the tighteningtiming impact of the average Midland-to-Gulf-Coastcrude oil spreads by $5.15 per barrel, and to a lesser extent lower pipeline income following the sale of the Plains equity investmentsales in the third quarter of 2019 and lower sulfur prices impacting Al Hosn Gas.marketing business.
CORPORATE
Significant corporate items include the following:
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
| Items Affecting Comparability | | | | | | |
| Anadarko Acquisition-related costs | | $ | (339) | | | $ | (1,647) | | | $ | — | |
| Bridge loan financing fees | | $ | — | | | $ | (122) | | | $ | — | |
| Acquisition-related pension and termination benefits | | $ | 114 | | | $ | 37 | | | $ | — | |
| Interest rate swaps mark-to-market, net | | $ | (428) | | | $ | 122 | | | $ | — | |
| Other charges and asset impairments | | $ | — | | | $ | (22) | | | $ | — | |
| Warrant gains mark-to-market | | $ | 5 | | | $ | 81 | | | $ | — | |
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Items Affecting Comparability | | | | | | |
| Anadarko acquisition-related costs | | $ | (89) | | | $ | (153) | | | $ | (339) | |
Interest rate swap gains (losses), net (a) | | $ | 317 | | | $ | 122 | | | $ | (428) | |
| Maxus environmental reserve adjustment | | $ | (22) | | | $ | — | | | $ | — | |
| Early debt extinguishment | | $ | 149 | | | $ | (118) | | | $ | — | |
| Acquisition-related pension & termination benefits | | $ | — | | | $ | — | | | $ | 114 | |
Warrants gains, net (a) | | $ | — | | | $ | — | | | $ | 5 | |
(a)See Note 8 - Derivatives in the Notes to the Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information.
| | | | | | | | |
| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
Totaldeferred tax assets, after valuation allowance, were $4.3 $2.2 billion and $3.7and $3.5 billion atas of December 31, 2020,2022 and 2019,2021, respectively. Occidental expects to realize the recorded deferred tax assets, net of any allowances, through future operating income and reversal of temporary differences. The total deferred tax liabilities were $11.4were $7.7 billion and $13.4and $10.5 billion as of December 31, 2020,2022 and 2019,2021, respectively. TheThe decrease in netnet deferred tax liability in 2020 over 2019 is2022 compared to 2021 was primarily driven by domestic asset impairments for whichthe legal entity reorganization that Occidental does not receive an immediate tax benefit as well as an increaseundertook in net operating loss carryforwards.the first quarter of 2022. See more discussion below.
| | | | | | | | |
| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
WORLDWIDE EFFECTIVE TAX RATE
The following table sets forth the calculation of the worldwide effective tax rate for income from continuing operations:
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| SEGMENT RESULTS | SEGMENT RESULTS | | | | | | | SEGMENT RESULTS | | | | | | |
| Oil and gas | Oil and gas | | $ | (9,632) | | | $ | 2,520 | | | $ | 2,442 | | Oil and gas | | $ | 12,803 | | | $ | 4,145 | | $ | (9,632) | |
| Chemical | Chemical | | 664 | | | 799 | | | 1,159 | | Chemical | | 2,508 | | | 1,544 | | 664 | |
| Midstream and marketing | Midstream and marketing | | (4,175) | | | 241 | | | 2,802 | | Midstream and marketing | | 273 | | | 257 | | (4,175) | |
| Unallocated corporate items | Unallocated corporate items | | (2,562) | | | (3,206) | | | (795) | | Unallocated corporate items | | (1,467) | | | (2,241) | | (2,562) | |
| Income (loss) from continuing operations before taxes | Income (loss) from continuing operations before taxes | | (15,705) | | | 354 | | | 5,608 | | Income (loss) from continuing operations before taxes | | $ | 14,117 | | | $ | 3,705 | | $ | (15,705) | |
| Income tax benefit (expense) | Income tax benefit (expense) | | | | | Income tax benefit (expense) | | | | | |
| Federal and state | Federal and state | | 2,607 | | | 34 | | | (463) | | Federal and state | | 248 | | | (247) | | 2,607 | |
| Foreign | Foreign | | (435) | | | (895) | | | (1,014) | | Foreign | | (1,061) | | | (668) | | (435) | |
| Total income tax benefit (expense) | Total income tax benefit (expense) | | 2,172 | | | (861) | | | (1,477) | | Total income tax benefit (expense) | | (813) | | | (915) | | 2,172 | |
| Income (loss) from continuing operations | Income (loss) from continuing operations | | (13,533) | | | (507) | | | 4,131 | | Income (loss) from continuing operations | | $ | 13,304 | | | $ | 2,790 | | $ | (13,533) | |
| Worldwide effective tax rate | Worldwide effective tax rate | | 14% | | 243% | | 26% | Worldwide effective tax rate | | 6% | | 25 | % | | 14% |
In 2022, Occidental’s worldwide effective tax rate was 6%, which was impacted by a tax benefit associated with Occidental's legal entity reorganization, as further described below.
In 2021, Occidental’s worldwide effective tax rate was 25%, which was higher than the U.S. statutory rate of 21% due to higher tax rates in the foreign jurisdictions in which Occidental operates, partially offset by the tax impact of business credits, state tax revaluations and other domestic tax benefits.
In 2020, Occidental’s worldwide effective tax rate was 14%, which was largely a result of the impairment of the WES goodwill and certain international assets for which Occidental receivesreceived no tax benefit and higher-taxed foreigninternational operations which generally caused Occidental’s tax rate to vary significantly from the U.S. corporate tax rate. Occidental’s effective tax rate is impacted each year by the relative pre-tax income (loss) earned by its domestic and international operations.
LEGAL ENTITY REORGANIZATION
To align Occidental’s legal entity structure with the nature of its business activities after completing the Anadarko Acquisition and subsequent large scale post-acquisition divestiture program, management undertook a legal entity reorganization that was completed in the first quarter of 2022.
As a result of this legal entity reorganization, management made an adjustment to the tax basis in a portion of its operating assets, thus reducing Occidental’s deferred tax liabilities. Accordingly, in 2022, Occidental recorded a tax benefit of $2.7 billion in connection with this reorganization. The timing of any reduction in Occidental’s future cash taxes as a result of this legal entity reorganization will be dependent on a number of factors, including prevailing commodity prices, capital activity level and production mix. The legal entity reorganization transaction is currently under IRS review as part of the Company’s 2022 federal tax audit.
INFLATION REDUCTION ACT
In August 2022, Congress passed the Inflation Reduction Act that contains, among other provisions, a corporate book minimum tax on financial statement income, an excise tax on stock buybacks, a methane emissions fee and certain tax incentives related to climate change and clean energy. Occidental is currently evaluating the provisions of this act. The ultimate impact of the act is yet to be determined and will depend on additional regulatory guidance and interpretations.
| | | | | | | | |
| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
| | |
| CONSOLIDATED RESULTS OF OPERATIONS |
REVENUE AND OTHER INCOME ITEMS
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Net sales | Net sales | | $ | 17,809 | | | $ | 20,911 | | | $ | 17,824 | | Net sales | | $ | 36,634 | | | $ | 25,956 | | | $ | 17,809 | |
| Interest, dividends and other income | Interest, dividends and other income | | $ | 118 | | | $ | 217 | | | $ | 136 | | Interest, dividends and other income | | $ | 153 | | | $ | 166 | | | $ | 118 | |
| Gains (losses) on sale of assets, net | Gains (losses) on sale of assets, net | | $ | (1,666) | | | $ | 622 | | | $ | 974 | | Gains (losses) on sale of assets, net | | $ | 308 | | | $ | 192 | | | $ | (1,666) | |
NET SALES
Price and volume changes generally represent the majority of the change in the oil and gas and chemical segments sales. Midstream and marketing sales are mainly impactedgenerally represent the margins earned by the lower marketing margins frombusiness at it strives to optimize the decrease in the Midland-to-Gulf-Coast oil spreadsuse of its transportation, storage and terminal commitments to provide access to domestic and international markets and, to a lesser extent, the change in NGL and sulfur prices forrevenues from the gas processing business.
The decreaseincrease in net sales in 20202022 compared to 20192021 was primarily due to lowerhigher realized oilcommodity prices in the oil and gas segment despitesegment. Chemical sales increased primarily due to higher prices and volumes as a result of a full year of production from properties addedacross all product lines. The increase in the Acquisition and net gains on the three-way oil collars. Midstreammidstream and marketing sales declinedwas due to tightening ofhigher crude oil prices impacting the Midland-to-Gulf-Coast oil spreads. Chemical sales declined primarily due to lower sales volumes across all products and lower realized caustic soda prices.
The 2020 losses on sales of assets, net, is primarily comprised of $820 million related to the sale of certain non-core, largely non-operated acreage in the Permian Basin, $440 million related to the sale of 4.5 million mineral acres and 1 million fee surface acres located in Wyoming, Colorado and Utah, $353 million related to the sale of the Colombia onshore assets and a loss of $46 million related to the WES note exchange.marketing businesses.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
EXPENSE ITEMS
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Oil and gas operating expense | Oil and gas operating expense | | $ | 3,065 | | | $ | 3,282 | | | $ | 2,761 | | Oil and gas operating expense | | $ | 4,028 | | | $ | 3,160 | | | $ | 3,065 | |
| Transportation and gathering expense | Transportation and gathering expense | | $ | 1,600 | | | $ | 635 | | | $ | 152 | | Transportation and gathering expense | | $ | 1,475 | | | $ | 1,419 | | | $ | 1,600 | |
| Chemical and midstream cost of sales | Chemical and midstream cost of sales | | $ | 2,408 | | | $ | 2,791 | | | $ | 2,833 | | Chemical and midstream cost of sales | | $ | 3,273 | | | $ | 2,772 | | | $ | 2,408 | |
| Purchased commodities | Purchased commodities | | $ | 1,395 | | | $ | 1,679 | | | $ | 822 | | Purchased commodities | | $ | 3,287 | | | $ | 2,308 | | | $ | 1,395 | |
| Selling, general and administrative | Selling, general and administrative | | $ | 864 | | | $ | 893 | | | $ | 585 | | Selling, general and administrative | | $ | 945 | | | $ | 863 | | | $ | 864 | |
| Other operating and non-operating expense | Other operating and non-operating expense | | $ | 884 | | | $ | 1,421 | | | $ | 1,028 | | Other operating and non-operating expense | | $ | 1,271 | | | $ | 1,065 | | | $ | 884 | |
| Taxes other than on income | | Taxes other than on income | | $ | 1,548 | | | $ | 1,005 | | | $ | 622 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | | $ | 8,097 | | | $ | 6,140 | | | $ | 3,977 | | Depreciation, depletion and amortization | | $ | 6,926 | | | $ | 8,447 | | | $ | 8,097 | |
| Asset impairments and other charges | Asset impairments and other charges | | $ | 11,083 | | | $ | 1,361 | | | $ | 561 | | Asset impairments and other charges | | $ | — | | | $ | 304 | | | $ | 11,083 | |
| Taxes other than on income | | $ | 622 | | | $ | 840 | | | $ | 439 | | |
| Anadarko Acquisition-related costs | Anadarko Acquisition-related costs | | $ | 339 | | | $ | 1,647 | | | $ | — | | Anadarko Acquisition-related costs | | $ | 89 | | | $ | 153 | | | $ | 339 | |
| Exploration expense | Exploration expense | | $ | 132 | | | $ | 247 | | | $ | 110 | | Exploration expense | | $ | 216 | | | $ | 252 | | | $ | 132 | |
| Interest and debt expense, net | Interest and debt expense, net | | $ | 1,424 | | | $ | 1,066 | | | $ | 389 | | Interest and debt expense, net | | $ | 1,030 | | | $ | 1,614 | | | $ | 1,424 | |
OIL AND GAS OPERATING EXPENSE
Oil and gas operating expense decreasedincreased in 20202022 from the prior year, primarily due to operational efficiencies that decreased downholeas a result of higher workovers, supports and maintenance costs in the Permian Basin, Rockies and workoverOther and support costs and lower energy and purchased injectant costs.
TRANSPORTATION AND GATHERING EXPENSE
Transportation and gathering expense increased in 2020 from the prior year, primarily due to a full yearGulf of increased sales volumes related to the AcquisitionMexico, as well as transportationhigher purchase injectant costs to WES which was previously a consolidated entity in 2019.the Permian Basin.
CHEMICAL AND MIDSTREAM COST OF SALES
Chemical and midstream cost of sales decreasedincreased in 20202022 from the prior year, primarily due to favorablehigher raw material costs in the chemical segment, primarily energy costs, and lowerincreased power generation costs in the midstream operation costs due to the loss of control of WES in 2019.and marketing segment.
PURCHASED COMMODITIES
Purchased commodities decreasedincreased in 20202022 from the prior year, largely as a result of lower crude oilhigher prices on third-party crude purchases related to the midstream and marketing segment.
OTHER OPERATING AND NON-OPERATING EXPENSE
Other operating and non-operating expense decreasedincreased in 20202022 from the prior year, primarily due to the realization of overhead savingsincreases in employee related costs and a net gain related to the settlement, curtailment and special termination benefits on pension plans acquired in the Acquisition.environmental remediation expenses.
DEPRECIATION, DEPLETION AND AMORTIZATION (DD&A)
DD&A expense increaseddecreased in 20202022 from the prior year, primarily as a result of lower per Boe DD&A rates due to havinghigher proved reserves as a full yearresult of production in 2020 associated with assets acquired through the Acquisition.positive program adds during 2021.
ASSET IMPAIRMENTS AND OTHER CHARGES
In 2020, asset impairments and other charges included pre-tax impairments of $4.5 billion primarily related to domestic onshore unproved acreage as well as $1.3 billion primarily related to other domestic onshore assets and the Gulf of Mexico. In addition there were $931 million of impairment and related charges associated with Occidental’s proved properties in Algeria to remeasure the Algeria oil and gas properties to their fair value. In addition, for the midstream and marketing segment, there were pre-tax impairment charges of $2.7 billion other-than-temporary impairment of the equity investment in WES and $1.2 billion of impairments related to the write-off of goodwill.
TAXES OTHER THAN ON INCOME
Taxes other than on income in 2020 decreased from the prior year, due to lower production taxes which are directly tied to prices on oil, NGL and natural gas volumes.
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4046 | OXY 20202022 FORM 10-K |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
ACQUISITION RELATED EXPENSESASSET IMPAIRMENTS AND OTHER CHARGES
Acquisition related expensesThere were no asset impairments in 2020 are associated with employee severance2022. In 2021, asset impairments and related employee costs primarily related to one-time severance costs and the accelerated vestingother charges of certain Anadarko share-based awards for former Anadarko employees based on the terms$304 million were mainly comprised of the Acquisitionimpairment of undeveloped leases that either expired or were set to expire in the near term where Occidental had no plans to pursue exploration activities.
TAXES OTHER THAN ON INCOME
Taxes other than on income in 2022 increased from the prior year, primarily due to higher production taxes, which are directly tied to revenues, and existing change of control provisions within the former Anadarko employment agreements.higher ad valorem taxes.
INTEREST AND DEBT EXPENSE, NET
Interest and debt expense net, increaseddecreased in 20202022 from the prior year, due to an increase inlower outstanding debt issued to partially fund the Acquisition, as well as thea result of debt assumed through the Acquisition.repayments.
OTHER ITEMS
| Income/(expense) millions | | 2020 | | 2019 | | 2018 | |
Income (expense) millions | | Income (expense) millions | | 2022 | | 2021 | | 2020 |
| Gains (losses) on interest rate swaps and warrants | Gains (losses) on interest rate swaps and warrants | | $ | (423) | | | $ | 233 | | | $ | — | | Gains (losses) on interest rate swaps and warrants | | $ | 317 | | | $ | 122 | | | $ | (423) | |
| Income from equity investments | Income from equity investments | | $ | 370 | | | $ | 373 | | | $ | 331 | | Income from equity investments | | $ | 793 | | | $ | 631 | | | $ | 370 | |
| Income tax benefit (expense) | Income tax benefit (expense) | | $ | 2,172 | | | $ | (861) | | | $ | (1,477) | | Income tax benefit (expense) | | $ | (813) | | | $ | (915) | | | $ | 2,172 | |
| Loss from discontinued operations, net | | Loss from discontinued operations, net | | $ | — | | | $ | (468) | | | $ | (1,298) | |
LOSS FROM DISCONTINUED OPERATIONS, NET
GAINS (LOSSES) ON INTEREST RATE SWAPS AND WARRANTSThere were no discontinued operations in 2022. In 2021, discontinued operations, net primarily included a $437 million after-tax loss contingency associated with Occidental’s former operations in Ecuador, see
Gains (losses) on interest rate swapsNote - 13 Lawsuits, Claims, Commitments and warrants are primarily due to a declineContingencies in the reference rate on the interest rate swaps throughout 2020, as fixed interest rates exceed the floating interest rates during the reference period.Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information. In addition, discontinued operations, net was associated with operations in Ghana which were sold in October 2021.
INCOME TAX BENEFIT (EXPENSE)
Occidental realized an income tax benefit for the year ended December 31, 2020 as compared to an income tax expense for the year ended December 31, 2019, primarily due to lower pre-tax income, partially offset by the impairment of certain international assets as well as the equity method goodwill associated with the WES investment, for which Occidental received no tax benefit.
DISCONTINUED OPERATIONS, NET
Discontinued operations, net in 2020 is associated with the operations of Ghana for which Occidental continues to present as held for sale. The decrease in income in 2020 is primarily associated with an after-tax impairment of $1.4 billion in the second quarter of 2020 to reflect the held for sale assets at their fair value less costs to sell based on the income approach.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
| | |
| LIQUIDITY AND CAPITAL RESOURCES |
CASH ON HAND
AtAs of December 31, 2020,2022, Occidental had approximately $2.0$1.0 billion in cash and cash equivalents. A substantial majority of this cash is held and available for use in the United States.
Occidental’s $5 billion RCF, available cash, continued access to capital markets and positive operating cash flows will allow Occidental to meet its short- and long-term purchase obligations, near-term debt maturities and other liabilities.
At December 31, 2020, Occidental had $0.4 billion in current maturities of long-term debt through December 31, 2021 and an additional $2.1 billion in long-term obligations due in 2022. Other near-term obligations include interest rate swaps with mandatory termination dates in September 2021 with a notional value of $750 million and accounts payable incurred in the course of Occidental’s business activities.SOURCES AND USES OF CASH
Occidental continues to pursue divestitures of certain assets and intends to use the net proceeds from asset sales and free cash flow to repay its nearer-term debt maturities, but the expected timing and final proceeds from such asset sales are uncertain. Occidental currently expects its operational cash flows and cash on hand to be sufficient to meet its current debt maturities operating expenditures and other obligations for the next 12 months from the date of this filing. However, given the inherent uncertainty associated with the durationShould commodity prices return to their 2020 lows, Occidental’s $4.0 billion RCF, receivables securitization facility and severity of the COVID-19 pandemic and its resulting impact on oil demand, Occidental may needaccess to raise capital to fund its operations and refinance debt maturities.
At December 31, 2020, Occidental had $170 million in restricted cash and restricted cash equivalents, which was primarily associated with an international joint venture, a benefits trust for former Anadarko employees that was funded as part of the Acquisition and a judicially controlled account related to a Brazilian tax dispute. Restricted cash within the benefits trust will be mademarkets are available to Occidental as benefitsmeet its ongoing capital needs, purchase obligations, near-term debt maturities and other liabilities and financial obligations, if required.
Occidental’s planned 2023 capital expenditures are paid to former Anadarko employees.
DEBT ACTIVITY
On March 23, 2020, Occidental amended the sole financial covenant in its RCF by revising the definition of "Total Capitalization" to exclude any non-cash write-downs, impairmentsbetween $5.4 billion and related charges occurring after September 30, 2019. The amendments provide Occidental with additional flexibility in the event of any such write-downs, impairments or other changes under the ratio of Total Debt to Total Capitalization covenant.
In July, August, and December, 2020, Occidental issued several series of notes with maturities from five to ten years. The proceeds from these issuances were used to tender and repay nearer-term notes and the Term Loan. Occidental used proceeds from the sale of mineral and surface acres located in Wyoming, Colorado and Utah, the Colombian asset sale and proceeds from other divestitures to repay debt. Occidental used the net proceeds from asset sales, cash on hand and Senior Notes Offerings to retire or tender $6.0$6.2 billion, of 2021, $2.7 billion of 2022 and $264 million of 2023 maturities.
In August 2020, Occidental exchanged approximately 27.9 million WES common unitswhich only a small percentage is allocated to retire a $260 million note payable to WES.
See Note 7 - Long-Term Debt in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information related to Occidental’s debt issuance and repayments.non-cancellable commitments.As of December 31, 2020, under the most restrictive covenants of its financing agreements,2022, Occidental had substantial$22 million in current maturities of long-term debt which were paid in January 2023, and an additional $1.1 billion in long-term obligations due in 2024.
As of December 31, 2022, Occidental had $433 million in non-cancelable lease payments due in 2023, and an additional $335 million in non-cancelable lease payments due in 2024.
Dividends paid to common and preferred shareholders were $1.2 billion for the year ended December 31, 2022.
Occidental is party to various purchase agreements that are not accounted for as leases or otherwise accrued as liabilities as of December 31, 2022. These agreements consist primarily of obligations to secure terminal, pipeline and processing capacity, purchase services used in the normal course of business including transporting and disposing of produced water, purchase goods used in the production of finished goods including certain chemical raw materials and power and agreements relating to equipment maintenance and service. The amounts that will be paid for additional unsecured borrowings, the paymentsuch outstanding off-balance sheet purchase obligations as of cash dividendsDecember 31, 2022 are $3.0 billion in 2023, $4.2 billion in 2024 and other distributions on, or acquisitions of, Occidental stock.2025, $2.5 billion in 2026 and 2027 and $2.2 billion in 2028 and thereafter.
CASH FLOW ANALYSISSHARE REPURCHASE PROGRAM
CASH PROVIDED BY OPERATING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
| Operating cash flow from continuing operations | | $ | 3,842 | | | $ | 7,336 | | | $ | 7,669 | |
| Operating cash flow from discontinued operations, net of taxes | | 113 | | | 39 | | | — | |
| Net cash provided by operating activities | | $ | 3,955 | | | $ | 7,375 | | | $ | 7,669 | |
Cash provided by operating activities decreased $3.4Under the $3.0 billion share repurchase program announced and completed in 2020 compared2022, Occidental purchased approximately 47.7 million shares. In February 2023, the Board authorized a new share repurchase program of up to 2019, primarily due to lower oil prices as average WTI and Brent prices decreased by 31% and 33%, respectively. Operating cash flows also decreased due to the decrease in the average Midland-to-Gulf-Coast oil spreads, which decreased by $5.15 per barrel in 2020 compared to 2019. To a lesser extent, the reduction in realized NGL and natural gas prices also impacted the lower operating cash flows in 2020. These decreases were partially offset by higher oil and gas sale volumes as 2020 had a full year$3.0 billion of production from assets associated with the Acquisition along with settlementOccidental’s shares of the three-way oil collars of $0.9 billion.
common stock. | | | | | |
42 | OXY 20202022 FORM 10-K | 47 |
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS | |
CASH USED BY INVESTING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
| Capital expenditures | | | | | | |
| Oil and gas | | $ | (2,208) | | | $ | (5,512) | | | $ | (4,413) | |
| Chemical | | (255) | | | (267) | | | (271) | |
| Midstream and marketing | | (50) | | | (461) | | | (216) | |
| Corporate | | (22) | | | (127) | | | (75) | |
| Total | | $ | (2,535) | | | $ | (6,367) | | | $ | (4,975) | |
| Changes in capital accrual | | (519) | | | (249) | | | 55 | |
| Purchase of businesses and assets, net | | (114) | | | (28,088) | | | (928) | |
| Proceeds from sale of assets and equity investments, net | | 2,281 | | | 6,143 | | | 2,824 | |
| Other investing activities, net | | 109 | | | (291) | | | (182) | |
| Investing cash flows from continuing operations | | $ | (778) | | | $ | (28,852) | | | $ | (3,206) | |
| Investing cash flows from discontinued operations | | (41) | | | (175) | | | — | |
| Net cash used by investing activities | | $ | (819) | | | $ | (29,027) | | | $ | (3,206) | |
Cash flows used by investing activities decreased by $28.2 billion in 2020 compared to 2019 primarily due to the 2019 Acquisition. Additionally, Occidental reduced capital spending in 2020 in response to the COVID-19 pandemic. See Note 4 - Divestitures and Other Transactions in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for a listing of assets and equity investments sold in 2020, 2019 and 2018.
CASH PROVIDED (USED) BY FINANCING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
| Financing cash flows from continuing operations | | $ | (4,508) | | | $ | 22,196 | | | $ | (3,102) | |
| Financing cash flows from discontinued operations | | $ | (8) | | | $ | (3) | | | $ | — | |
| Net cash provided (used) by financing activities | | $ | (4,516) | | | $ | 22,193 | | | $ | (3,102) | |
Cash provided by financing activities decreased by $26.7 billion compared to 2019 primarily due to the 2019 increase in debt used to fund the Acquisition. Additionally, common dividends paid in 2020 were lower than 2019 due to the Board of Directors’ decision to reduce the quarterly dividend rate effective as of July 2020 from $0.79 to $0.01 per share. See Note 7 - Long-Term Debt in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information related to Occidental’s debt issuance and repayments.
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OFF-BALANCE SHEET ARRANGEMENTS |
GUARANTEES
Occidental has guaranteed its portion of the debt of Dolphin Energy Limited, an equity method investment, and has entered into various other guarantees, including performance bonds, letters of credit, indemnities and commitments provided by Occidental to third parties, mainly to provide assurance that Occidental or its subsidiaries and affiliates will meet their various obligations. See “Midstream and Marketing Segment — Business Review — Pipeline” and “Segment Results of Operations” for further information regarding the Dolphin Energy Project. As of December 31, 2020, and 2019, Occidental had provided limited recourse guarantees of approximately $242 million, primarily related to Dolphin Energy Limited’s debt, which are limited to certain political and other events.
| | |
COMMITMENTS AND OBLIGATIONS |
DELIVERY COMMITMENTS
Occidental has made long-term commitments to certain refineries and other buyers to deliver oil, NGL and natural gas. The total amount contracted to be delivered is approximately 111 MMbbl of oil through 2025, 862 MMbbl of NGL through 2029 and 1,025 Bcf of gas through 2029. The price for these deliveries is set at the time of delivery of the product. Occidental has significantly more production capacity than the amounts committed and has the ability to secure additional volumes in case of a shortfall.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
CONTRACTUAL OBLIGATIONS
The following table summarizes and cross-references Occidental’s contractual obligations and indicates on- and off-balance sheet obligations as of December 31, 2020.2022. Commitments related to held for sale assets are excluded.
|
millions |
millions | | | Payments Due by Year |
millions | | | Payments Due by Year |
| Total | | 2021 | | 2022 and 2023 | | 2024 and 2025 | | 2026 and
thereafter | Total | | 2023 | | 2024 and 2025 | | 2026 and 2027 | | 2028 and
thereafter |
| On-Balance Sheet | On-Balance Sheet | | | | | | | | | | On-Balance Sheet | | | | | | | | | |
Current portion of long-term debt (Note 7) (a) | $ | 398 | | | $ | 398 | | | $ | — | | | $ | — | | | $ | — | | |
Long-term debt (Note 7) (a) | 34,837 | | | — | | | 3,007 | | | 6,798 | | | 25,032 | | |
Leases (Note 8) (b) | 1,724 | | | 500 | | | 374 | | | 234 | | | 616 | | |
Current portion of long-term debt (Note 6) (a) | | Current portion of long-term debt (Note 6) (a) | $ | 22 | | | $ | 22 | | | $ | — | | | $ | — | | | $ | — | |
Long-term debt (Note 6) (a) | | Long-term debt (Note 6) (a) | 17,936 | | | — | | | 2,264 | | | 2,351 | | | 13,321 | |
| Expected interest payments on long-term debt | | Expected interest payments on long-term debt | 11,400 | | | 1,060 | | | 2,042 | | | 1,754 | | | 6,544 | |
Leases (Note 7) (b) | | Leases (Note 7) (b) | 1,818 | | | 433 | | | 538 | | | 320 | | | 527 | |
| Asset retirement obligations (Note 1) | Asset retirement obligations (Note 1) | 4,130 | | | 153 | | | 845 | | | 631 | | | 2,501 | | Asset retirement obligations (Note 1) | 3,805 | | | 169 | | | 1,124 | | | 961 | | | 1,551 | |
Other long-term liabilities (c) | Other long-term liabilities (c) | 2,386 | | | 321 | | | 336 | | | 187 | | | 1,542 | | Other long-term liabilities (c) | 2,594 | | | 11 | | | 851 | | | 253 | | | 1,479 | |
| Off-Balance Sheet | Off-Balance Sheet | | Off-Balance Sheet | |
Purchase obligations (d) | Purchase obligations (d) | 13,184 | | | 2,826 | | | 4,344 | | | 2,986 | | | 3,028 | | Purchase obligations (d) | 11,963 | | | 2,983 | | | 4,246 | | | 2,510 | | | 2,224 | |
| Total | Total | $ | 56,659 | | | $ | 4,198 | | | $ | 8,906 | | | $ | 10,836 | | | $ | 32,719 | | Total | $ | 49,538 | | | $ | 4,678 | | | $ | 11,065 | | | $ | 8,149 | | | $ | 25,646 | |
(a)Excluded unamortized debt discount and interest on the debt. As of December 31, 2020, interest on long-term debt totaling $19.9 billion is payable in the following years: 2021 - $1.6 billion, 2022 and 2023 - $3.2 billion, 2024 and 2025 - $2.9 billion, 2026 and thereafter - $12.2 billion.interest.
(b)Occidental is the lessee under various agreements for real estate, equipment, plants and facilities. See Note 2 - Accounting and Disclosure Changes in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K regarding the impact of rules effective January 1, 2019 which required Occidental to recognize most leases, including operating leases, on the balance sheet. (c)Includes long termIncluded long-term obligations and current portions of long termlong-term obligations under postretirement benefit,benefits, accrued transportation commitments, ad valorem taxes and other accrued liabilities.
(d)Amounts includeincluded payments which will become due under long-term agreements to purchase goods and services used in the normal course of business to secure terminal, pipeline and processing capacity, CO2, electrical power, steam and certain chemical raw materials.materials including but not limited to capital commitments. Amounts excludeexcluded certain product purchase obligations related to marketing activities for which there are no minimum purchase requirements or the amounts are not fixed or determinable. Long-term purchase contracts are discountedwere discounted at a 4.41% 5.03% discount rate.
DEBT ACTIVITY
For the twelve months ended December 31, 2022, Occidental repaid debt with a face value of more than $10.5 billion, reducing the face value of Occidental’s debt to less than $18.0 billion. The net book value of the full year repayments was $9.8 billion, which resulted in a gain of $149 million.
See Note 6 - Long-Term Debt in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information related to Occidental’s debt issuance and repayments.
GUARANTEES
Occidental has entered into various guarantees, indemnities and commitments provided by Occidental to third parties, mainly to provide assurance that Occidental or its consolidated subsidiaries or affiliates will meet their various obligations.
As of the date of this filing, Occidental has provided required financial assurance through a combination of cash, letters of credit and surety bonds. Occidental has not issued any letters of credit under the RCF or other committed facilities. For additional information, see Risk Factors in Part I, Item 1A of this Form 10-K.
CASH FLOW ANALYSIS
CASH PROVIDED BY OPERATING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Operating cash flow from continuing operations | | $ | 16,810 | | | $ | 10,253 | | | $ | 3,842 | |
| Operating cash flow from discontinued operations, net of taxes | | — | | | 181 | | | 113 | |
| Net cash provided by operating activities | | $ | 16,810 | | | $ | 10,434 | | | $ | 3,955 | |
Cash provided by operating activities increased in 2022 compared to 2021, primarily due to higher commodity prices, as average WTI and Brent prices increased by 39% and 40%, respectively and NYMEX natural gas prices increased by 76%. The chemical segment also generated substantial operating cash flows largely due to higher prices for most chemical products, especially caustic soda, compared to 2021.
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
CASH USED BY INVESTING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Capital expenditures | | | | | | |
| Oil and gas | | $ | (3,844) | | | $ | (2,409) | | | $ | (2,208) | |
| Chemical | | (322) | | | (308) | | | (255) | |
| Midstream and marketing | | (268) | | | (106) | | | (50) | |
| Corporate | | (63) | | | (47) | | | (22) | |
| Total | | $ | (4,497) | | | $ | (2,870) | | | $ | (2,535) | |
| Changes in capital accrual | | 147 | | | 97 | | | (519) | |
| Purchase of businesses, assets and equity investments, net | | (990) | | | (431) | | | (114) | |
| Proceeds from sale of assets and equity investments, net | | 584 | | | 1,624 | | | 2,281 | |
| Other investing activities, net | | (116) | | | 406 | | | 109 | |
| Investing cash flows from continuing operations | | $ | (4,872) | | | $ | (1,174) | | | $ | (778) | |
| Investing cash flows from discontinued operations | | — | | | (79) | | | (41) | |
| Net cash used by investing activities | | $ | (4,872) | | | $ | (1,253) | | | $ | (819) | |
Cash flows used by investing activities increased by $3.6 billion in 2022 compared to 2021. In 2022, Occidental increased capital spending as a result of increased activity in the Permian. Occidental acquired additional primarily producing assets in the Permian Basin for approximately $400 million and additional interests in emerging low-carbon businesses and net-zero pathway for approximately $350 million. Occidental sold certain strategic assets in the Permian Basin for approximately $190 million. See Note 5 - Acquisitions, Divestitures and Other Transactions in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for a listing of assets and equity investments acquired and sold in 2022, 2021 and 2020. In addition in 2022, Occidental sold 10 million limited partner units of WES for proceeds of approximately $250 million.
CASH USED BY FINANCING ACTIVITIES
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Financing cash flows from continuing operations | | $ | (13,715) | | | $ | (8,564) | | | $ | (4,508) | |
| Financing cash flows from discontinued operations | | — | | | (8) | | | (8) | |
| Net cash used by financing activities | | $ | (13,715) | | | $ | (8,572) | | | $ | (4,516) | |
Cash used by financing activities increased by $5.1 billion compared to 2021 primarily due to the 2022 debt tenders and repayments and treasury share repurchase activity. See Note 6 - Long-Term Debt in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for more information related to Occidental’s debt repayments and see Item 5 Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities in Part II of this Form 10-K and Note 14 - Stockholders' Equity in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for additional information related to Occidental’s share repurchases. In addition, cash used by financing activities reflected cash dividend payments of $1.2 billion on preferred and common stock and $111 million, related to net interest rate swap settlements and collateral activity.
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| LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES |
LEGAL MATTERS
Occidental or certain of its subsidiaries are involved,For information on Occidental’s Lawsuits, Claims, Commitments and Contingencies, see the information in Note 13 - Lawsuits, Claims, Commitments and Contingencies in the normal courseNotes to Consolidated Financial Statements in Part II Item 8 of business, in lawsuits, claims and other legal proceedings that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. Occidental or certain of its subsidiaries also are involved in proceedings under Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) and similar federal, state, local and foreign environmental laws. These environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties and injunctive relief. Usually Occidental or such subsidiaries are among many companies in these environmental proceedings and have to date been successful in sharing response costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or disposed assets with respect to which a third party or Occidental retains liability or indemnifies the other party for conditions that existed prior to the transaction.In accordance with applicable accounting guidance, Occidental accrues reserves for outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserves for matters, other than for environmental remediation, that satisfy this criteria as of December 31, 2020 and 2019, were not material to Occidental’s Consolidated Balance Sheets.
In 2016, Occidental received payments from the Republic of Ecuador of approximately $1.0 billion pursuant to a November 2015 arbitration award for Ecuador’s 2006 expropriation of Occidental's Participation Contract for Block 15. The awarded amount represented a recovery of 60% of the value of Block 15. In 2017, Andes Petroleum Ecuador Ltd. (Andes) filed a demand for arbitration, claiming it is entitled to a 40% share of the judgment amount obtained by Occidental. Occidental contends that Andes is not entitled to any of the amounts paid under the 2015 arbitration award because Occidental’s recovery was limited to Occidental’s own 60% economic interest in the block. The merits hearing occurred in September 2020 and an arbitration decision is expected within the next six months.
In August 2019, Sanchez Energy Corporation and certain of its affiliates (Sanchez) filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code. Sanchez is a party to agreements with Anadarko as
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
a result of its 2017 purchase of Anadarko's Eagle Ford Shale assets. Sanchez is attempting to reject some of the agreements related to the purchase of Anadarko’s Eagle Ford Shale assets. If Sanchez is permitted to reject certain of those agreements, then Anadarko may owe deficiency payments to various third parties. Occidental intends to defend vigorously any attempt by Sanchez to reject the agreements. Occidental expects a ruling on Sanchez's purported contract rejection in the first half of 2021.
On May 26, 2020, a putative securities class action captioned City of Sterling Heights General Employees’ Retirement System, et al. v. Occidental Petroleum Corporation, et al., No. 651994/2020 (City of Sterling), was filed in the Supreme Court of the State of New York. The complaint asserts claims under Sections 11, 12 and 15 of the Securities Act of 1933, as amended (the Securities Act), based on alleged misstatements in the Securities Act filings, including the registration statement filed in connection with the Anadarko Acquisition and Occidental’s related issuance of common stock and debt securities offerings that took place in August 2019. The lawsuit was filed against Occidental, certain current and former officers and directors and certain underwriters of the debt securities offerings, and seeks damages in an unspecified amount, plus attorneys’ fees and expenses. Two additional putative class actions were filed in the same court (together with City of Sterling, the State Cases) and the State Cases were consolidated into In re Occidental Petroleum Corporation Securities Litigation, No. 651830/2020. Occidental intends to vigorously defend itself in all respects in regard to the State Cases.
The ultimate outcome and impact of outstanding lawsuits, claims and proceedings on Occidental cannot be predicted. Management believes that the resolution of these matters will not, individually or in the aggregate, have a material adverse effect on Occidental's Consolidated Balance Sheets. If unfavorable outcomes of these matters were to occur, future results of operations or cash flows for any particular quarterly or annual period could be materially adversely affected. Occidental’s estimates are based on information known about the legal matters and its experience in contesting, litigating and settling similar matters. Occidental reassesses the probability and estimability of contingent losses as new information becomes available.Form 10-K.
TAX MATTERS
During the course of its operations, Occidental is subject to audit by tax authorities for varying periods in various federal, state, local and foreign tax jurisdictions. Taxable years through 2017 for U.S. federal income tax purposes have been audited by the U.S. Internal Revenue Service (IRS) pursuant to its Compliance Assurance Program and subsequent taxable years are currently under review. Taxable years through 2009 have been audited for state income tax purposes. All other significant audit matters in foreign jurisdictions have been resolved through 2010. During the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law. Occidental believes that the resolution of outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations.
For Anadarko, its taxable years through 2014 and tax year 2016 for U.S. federal and state income tax purposes have been audited by the IRS and respective state taxing authorities. There are outstanding significant audit matters in one foreign jurisdiction. As stated above, during the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law. Other than the matter discussed below, Occidental believes that the resolution of these outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations.
Anadarko received an $881 million tentative refund in 2016 related to its $5.2 billion Tronox Adversary Proceeding settlement payment in 2015. In September 2018, Anadarko received a statutory notice of deficiency from the IRS disallowing the net operating loss carryback and rejecting Anadarko’s refund claim. As a result, Anadarko filed a petition with the U.S. Tax Court to dispute the disallowances in November 2018. The case was in the IRS appeals process until the second quarter of 2020, however it has since been returned to the U.S. Tax Court where Occidental expects to continue pursuing resolution.
In accordance with ASC 740’s guidance on the accounting for uncertain tax positions, Occidental has recorded no tax benefit on the tentative cash tax refund of $881 million. As a result, should Occidental not ultimately prevail on the issue, there would be no additional tax expense recorded relative to this position for financial statement purposes other than future interest. However, in that event Occidental would be required to repay approximately $925 million ($898 million federal and $27 million in state taxes) plus accrued interest of approximately $255 million. A liability for this amount plus interest is included in deferred credits and other liabilities-other.
INDEMNITIES TO THIRD PARTIES
Occidental, its subsidiaries, or both, have indemnified various parties against specified liabilities those parties might incur in the future in connection with purchases and other transactions that they have entered into with Occidental. These indemnities usually are contingent upon the other party incurring liabilities that reach specified thresholds. As of December 31, 2020, Occidental is not aware of circumstances that it believes would reasonably be expected to lead to indemnity claims that would result in payments materially in excess of reserves.
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OXY 20202022 FORM 10-K | 4549 |
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| ENVIRONMENTAL LIABILITIES AND EXPENDITURES |
Occidental’s operations are subjectENVIRONMENTAL COSTS
Environmental costs relate to stringent federal, state, local and international laws and regulations related to improving or maintaining environmental quality. The laws that require or address environmental remediation, including CERCLA and similar federal, state, local and international laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership orprevention, monitoring, control, of sites. Occidental or certain of its subsidiaries participate in or actively monitor a range of remedial activities and government or private proceedings under these laws with respect to alleged past practices at operating, closed and third-party sites. Remedial activities may include one or more of the following: investigation involving sampling, modeling, risk assessment or monitoring; cleanup measures including removal, treatment or disposal;abatement of waste, emissions or operation and maintenancereleases to air, water or land from operations of remedial systems.Occidental’s subsidiaries. These activities are generally integrated with ongoing operations or development projects, so the costs in this table include estimates. The environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties, injunctive relief and government oversight costs.
ENVIRONMENTAL REMEDIATION
As of December 31, 2020, Occidental participated in or monitored remedial activities or proceedings at 170 sites. The following table presents Occidental’s current and non-current environmental remediation liabilities as of December 31, 2020 and 2019, the current portion of which is included in accrued liabilities ($123 million in 2020 and $162 million in 2019) and the remainder in deferred credits and other liabilities - environmental remediation liabilities ($1.03 billion in 2020 and $1.04 billion in 2019).
Occidental’s environmental remediation sites are grouped into four categories: National Priorities List (NPL) sites listed or proposed for listing by the EPA on the CERCLA NPL and three categories of non-NPL sites — third-party sites, Occidental-operated sites and closed or non-operated Occidental sites.
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| | 2020 | | 2019 |
| millions, except number of sites | | Number of Sites | | Remediation Balance | | Number of Sites | | Remediation Balance |
| NPL sites | | 35 | | | $ | 447 | | | 36 | | | $ | 463 | |
| Third-party sites | | 69 | | | 293 | | | 74 | | | 311 | |
| Occidental-operated sites | | 17 | | | 144 | | | 17 | | | 154 | |
| Closed or non-operated Occidental sites | | 49 | | | 267 | | | 50 | | | 269 | |
| Total | | 170 | | | $ | 1,151 | | | 177 | | | $ | 1,197 | |
As of December 31, 2020, Occidental’s environmental liabilities exceeded $10 million each at 19 of the 170 sites described above, and 96 of the sites had liabilities from $0 to $1 million each. As of December 31, 2020, two sites — the Diamond Alkali Superfund Site and a former chemical plant in Ohio (both of which are indemnified by Maxus Energy Corporation, as discussed further below) — accounted for 92% of its liabilities associated with NPL sites. 17 of the 35 NPL sites are indemnified by Maxus.
Five of the 69 third-party sites — a Maxus-indemnified chrome site in New Jersey, a former copper mining and smelting operation in Tennessee, a former oil field and a landfill in California, and an active refinery in Louisiana where Occidental reimburses the current owner for certain remediation activities — accounted for 76% of Occidental’s liabilities associated with these sites. 9 of the 69 third-party sites are indemnified by Maxus.
Five sites — oil and gas operations in Colorado and chemical plants in Kansas, Louisiana, New York and Texas — accounted for 70% of the liabilities associated with the Occidental-operated sites. Seven other sites — a landfill in Western New York, a former refinery in Oklahoma, former chemical plants in California, Michigan, Tennessee and Washington, and a closed coal mine in Pennsylvania — accounted for 70% of the liabilities associated with closed or non-operated Occidental sites.
Environmental remediation liabilities vary over time depending on factors such as acquisitions or divestitures, identification of additional sites and remedy selection and implementation. Occidental recorded environmental remediation expenses of $36 million, $112 million and $47 million for the years ended December 31, 2020, 2019, and 2018, respectively. Environmental remediation expenses primarily relate to changes to existing conditions from past operations. Based on current estimates, Occidental expects to expend funds corresponding to approximately 45% of the year-end remediation balance over the next three to four years with the remainder over the subsequent 10 or more years. Occidental believes its range of reasonably possible additional losses beyond those amounts currently recorded for environmental remediation for all of its environmental sites could be up to $1.1 billion.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
MAXUS ENVIRONMENTAL SITES
When Occidental acquired Diamond Shamrock Chemicals Company (DSCC) in 1986, Maxus agreed to indemnify Occidental for a number of environmental sites, including the Diamond Alkali Superfund Site (Site) along a portion of the Passaic River. On June 17, 2016, Maxus and several affiliated companies filed for Chapter 11 bankruptcy in Federal District Courtcosts in the State of Delaware. Prior to filing for bankruptcy, Maxus defended and indemnified Occidentaltable do not include litigation-related costs, including fines, penalties or settlements, or Occidental’s investments in connection with clean-up and other costs associated with the sites subject to the indemnity, including the Site.
In March 2016, the EPA issued a Record of Decision (ROD) specifying remedial actions required for the lower 8.3 miles of the Lower Passaic River. The ROD does not address any potential remedial action for the upper nine miles of the Lower Passaic River or Newark Bay. During the third quarter of 2016, and following Maxus’s bankruptcy filing, Occidental and the EPA entered into an Administrative Order on Consent (AOC) to complete the design of the proposed clean-up plan outlined in the ROD at an estimated cost of $165 million. The EPA announced that it will pursue similar agreements with other potentially responsible parties.
Occidental has accrued a reserve relating to its estimated allocable share of the costs to perform the design and remediation called for in the AOC and the ROD, as well as for certain other Maxus-indemnified sites. Occidental's accrued estimated environmental reserve does not consider any recoveries for indemnified costs. Occidental’s ultimate share of this liability may be higher or lower than the reserved amount, and is subject to final design plans and the resolution of Occidental's allocable share with other potentially responsible parties. Occidental continues to evaluate the costs to be incurred to comply with the AOC, the ROD and to perform remediation at other Maxus-indemnified sites in light of the Maxus bankruptcy and the share of ultimate liability of other potentially responsible parties. In June 2018, Occidental filed a complaint under CERCLA in Federal District Court in the State of New Jersey against numerous potentially responsible parties for reimbursement of amounts incurred or to be incurred to comply with the AOC, the ROD, or to perform other remediation activities at the Site.
In June 2017, the court overseeing the Maxus bankruptcy approved a Plan of Liquidation (Plan) to liquidate Maxus and create a trust to pursue claims against current and former parents YPF and each of its respective subsidiaries and affiliates (YPF) and Repsol, S.A. and each of its respective subsidiaries and affiliates (Repsol), as well as others to satisfy claims by Occidental and other creditors for past and future cleanup and other costs. In July 2017, the court-approved Plan became final and the trust became effective. The trust is pursuing claims against YPF, Repsol and others and is expected to distribute assets to Maxus' creditors in accordance with the trust agreement and Plan. In June 2018, the trust filed its complaint against YPF and Repsol in Delaware bankruptcy court asserting claims based upon, among other things, fraudulent transfer and alter ego. During 2019, the bankruptcy court denied Repsol's and YPF's motions to dismiss the complaint as well as their motions to move the case away from the bankruptcy court. Discovery remains ongoing at the time of this report.
ENVIRONMENTAL COSTS
low-carbon ventures. Occidental’s environmental costs some of which include estimates, are presented below for each segment for each of the years ended December 31:
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Operating Expenses | Operating Expenses | | | | | | | Operating Expenses | | | | | | |
| Oil and gas | Oil and gas | | $ | 176 | | | $ | 174 | | | $ | 91 | | Oil and gas | | $ | 304 | | | $ | 267 | | | $ | 176 | |
| Chemical | Chemical | | 73 | | | 80 | | | 80 | | Chemical | | 115 | | | 88 | | | 73 | |
| Midstream and marketing | Midstream and marketing | | 4 | | | 12 | | | 10 | | Midstream and marketing | | 6 | | | 6 | | | 4 | |
| Total | Total | | $ | 253 | | | $ | 266 | | | $ | 181 | | Total | | $ | 425 | | | $ | 361 | | | $ | 253 | |
| Capital Expenditures | Capital Expenditures | | Capital Expenditures | |
| Oil and gas | Oil and gas | | $ | 74 | | | $ | 109 | | | $ | 71 | | Oil and gas | | $ | 110 | | | $ | 87 | | | $ | 74 | |
| Chemical | Chemical | | 40 | | | 34 | | | 23 | | Chemical | | 53 | | | 66 | | | 40 | |
| Midstream and marketing | Midstream and marketing | | 1 | | | 4 | | | 2 | | Midstream and marketing | | 5 | | | 1 | | | 1 | |
| Total | Total | | $ | 115 | | | $ | 147 | | | $ | 96 | | Total | | $ | 168 | | | $ | 154 | | | $ | 115 | |
| Remediation Expenses | Remediation Expenses | | Remediation Expenses | |
| Corporate | Corporate | | $ | 36 | | | $ | 112 | | | $ | 47 | | Corporate | | $ | 65 | | | $ | 28 | | | $ | 36 | |
Operating expenses are incurred on a continual basis. Capital expenditures relate to longer-lived improvements in properties currently operated by Occidental. Remediation expenses relate to existing conditions from past operations.operations of Occidental or its subsidiaries.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
A portion of Occidental’s assets are located outside North America. The following table shows the geographic distribution of Occidental’s assets atas of December 31, 20202022, at both the segment and consolidated level related to Occidental’s ongoing operations:
| | millions | millions | Oil and gas | | Chemical | | Midstream and marketing | | Corporate and other | | Total Consolidated | millions | Oil and gas | | Chemical | | Midstream and marketing | | Corporate and other | | Total Consolidated |
| North America | North America | | North America | |
| United States | United States | $ | 57,026 | | | $ | 4,140 | | | $ | 6,260 | | | $ | 2,951 | | | $ | 70,377 | | United States | $ | 49,786 | | | $ | 4,323 | | | $ | 8,701 | | | $ | 1,917 | | | $ | 64,727 | |
| Canada | Canada | — | | | 123 | | | 22 | | | — | | | 145 | | Canada | — | | | 111 | | | 104 | | | — | | | 215 | |
| Middle East | Middle East | 3,500 | | | — | | | 3,547 | | | — | | | 7,047 | | Middle East | 3,602 | | | — | | | 3,133 | | | — | | | 6,735 | |
| Latin America | 33 | | | 57 | | | — | | | — | | | 90 | | |
| Africa and Other | 2,372 | | | 6 | | | 27 | | | — | | | 2,405 | | |
| North Africa and Other | | North Africa and Other | 670 | | | 124 | | | 138 | | | — | | | 932 | |
| Consolidated | Consolidated | $ | 62,931 | | | $ | 4,326 | | | $ | 9,856 | | | $ | 2,951 | | | $ | 80,064 | | Consolidated | $ | 54,058 | | | $ | 4,558 | | | $ | 12,076 | | | $ | 1,917 | | | $ | 72,609 | |
For the year ended December 31, 2020,2022, net sales outside North America totaled $3.4$5.5 billion, or approximately 19%15% of total net sales.
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
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| CRITICAL ACCOUNTING POLICIES AND ESTIMATES |
The process of preparing financial statements in accordance with generally accepted accounting principlesUnited States GAAP requires Occidental’s management to make informed estimates and judgments regarding certain items and transactions. Changes in facts and circumstances or discovery of new information may result in revised estimates and judgments and actual results may differ from these estimates upon settlement but generally not by material amounts. The selection and development of these policies and estimates have been discussed with the Audit Committee of the Board of Directors. Occidental considers the following to be its most critical accounting policies and estimates that involve management’s judgment.
OIL AND GAS PROPERTIES
The carrying value of Occidental’s property, plant and equipment (PP&E)PP&E represents the cost incurred to acquire or develop the asset, including any asset retirement obligations (AROs)AROs and capitalized interest, net of DD&A and any impairment charges. For assets acquired in a business combination, PP&E cost is based on fair values at the acquisition date. Asset retirement obligationsAROs and interest costs incurred in connection with qualifying capital expenditures are capitalized and amortized over the useful lives of the related assets.
Occidental uses the successful efforts method to account for its oil and gas properties. Under this method, Occidental capitalizes costs of acquiring properties, costs of drilling successful exploration wells and development costs. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. If proved reserves have been found, the costs of exploratory wells remain capitalized. For exploratory wells that find reserves that cannot be classified as proved when drilling is completed, costs continue to be capitalized as suspended exploratory drilling costs if there have been sufficient reserves found to justify completion as a producing well and sufficient progress is being made in assessing the economic and operating viability of the project. At the end of each quarter, management reviews the status of all suspended exploratory drilling costs in light of ongoing exploration activities and in particular, whether Occidental is making sufficient progress in its ongoing exploration and appraisal efforts or, in the case of discoveries requiring government sanctioning, analyzing whether development negotiations are underway and proceeding as planned. If management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed.
Occidental expenses annual lease rentals, the costs of injectants used in production and geological and geophysical costs as incurred for exploration activities.
Occidental determines depreciation and depletion of oil and gas producing properties by the unit-of-production method. It amortizes leasehold acquisition costs over total proved reserves and capitalized development and successful exploration costs over proved developed reserves.
Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain,
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
regardless of whether deterministic or probabilistic methods are used for the estimation. Occidental has no proved oil and gas reserves for which the determination of economic producibility is subject to the completion of major additional capital expenditures.
Several factors could change Occidental’s proved oil and gas reserves. For example, Occidental receives a share of production from PSCs to recover its costs and generally an additional share for profit. Occidental’s share of production and reserves from these contracts decreases when product prices rise and increases when prices decline. Generally, Occidental’s net economic benefit from these contracts is greater at higher product prices. In other cases, particularly with long-lived properties, lower product prices may lead to a situation where production of a portion of proved reserves becomes uneconomical. For such properties, higher product prices typically result in additional reserves becoming economical. Estimation of future production and development costs is also subject to change partially due to factors beyond Occidental’s control, such as energy costs and inflation or deflation of oil field service costs. These factors, in turn, could lead to changes in the quantity of proved reserves. Additional factors that could result in a change of proved reserves include production decline rates and operating performance differing from those estimated when the proved reserves were initially recorded. Changes in the political and regulatory climate could lead to decreases in proved reserves as development horizons may be extended into the future.
Occidental performs impairment tests with respect to its proved properties whenever events or circumstances indicate that the carrying value of property may not be recoverable. If there is an indication the carrying amount of the asset may not be recovered due to significant and prolonged declines in current and forward prices, significant changes in reserve estimates, changes in management’s plans or other significant events, management will evaluate the property for impairment. Under the successful efforts method, if the sum of the undiscounted cash flows is less than the carrying value of the proved property, the carrying value is reduced to estimated fair value and reported as an impairment charge in the period. Individual proved properties are grouped for impairment purposes at the lowest level for which there are identifiable cash flows.flows unless observable and comparable transactions are available. The fair value of impaired assets is typically determined based on the present value of expected future cash flows using discount rates believed to be consistent with those used by market participants. The impairment test incorporates a number of assumptions involving expectations of future cash flows which can change significantly over time. These assumptions include estimates of future production, product prices, contractual prices, estimates of risk-adjusted oil and gas proved and unproved reserves and estimates of
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
future operating and development costs. It is reasonably possible that prolonged declines in commodity prices, reduced capital spending in response to lower prices or increases in operating costs could result in additional impairments.
For impairment testing, unless prices are contractually fixed, Occidental uses observable forward strip prices for oil and natural gas prices when projecting future cash flows. Future operating and development costs are estimated using the current cost environment applied to expectations of future operating and development activities to develop and produce oil and gas reserves. Market prices for oil, NGL and natural gas have been volatile and may continue to be volatile in the future. Changes in global supply and demand, transportation capacity, currency exchange rates, applicable laws and regulations and the effect of changes in these variables on market perceptions could impact current forecasts. Future fluctuations in commodity prices could result in estimates of future cash flows to vary significantly.
Net capitalized costs attributable to unproved properties were $18.6$12.6 billion atas of December 31, 2020,2022, and $29.5$14.8 billion atas of December 31, 2019.2021. The unproved amounts are not subject to DD&A until they are classified as proved properties. Individually insignificant unproved properties are combined and amortized on a group basis based on factors such as lease terms, success rates and other factors to provide for full amortization upon lease expiration or abandonment.
Significant unproved properties, primarily as a result of the Anadarko Acquisition, are assessed individually for impairment and when events or circumstances indicate that the carrying value of property may not be recovered a valuation allowance is provided if an impairment is indicated. Occidental periodically reviews significant unproved properties for impairments; numerous factors are considered, including but not limited to, availability of funds for future exploration and development activities, current exploration and development plans, favorable or unfavorable exploration activity on the property or the adjacent property, geologists’ evaluation of the property, the current and projected political and regulatory climate, contractual conditions and the remaining lease term for the properties. If an impairment is indicated, Occidental will first determine whether a comparable transaction for similar properties or implied acreage valuation derived from domestic onshore market participants is available and will adjust the carrying amount of the unproved property to its fair value using the market approach. In situations where the market approach is not observable and unproved reserves are available, undiscounted future net cash flows used in the impairment analysis are determined based on managements’ risk adjusted estimates of unproved reserves, future commodity prices and future costs to produce the reserves. If undiscounted future net cash flows are less than the carrying value of the property, the future net cash flows are discounted and compared to the carrying value for determining the amount of the impairment loss to record. Occidental utilizes the same assumptions and methodology discussed above for cash flows associated with proved properties.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
PROVED RESERVES
Occidental estimates its proved oil and gas reserves according to the definition of proved reserves provided by the SECSEC’s Rule 4-10 (a) of Regulation S-X and Financial Accounting Standards Board. This definition includesProved oil NGL and natural gas that geologicalreserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, demonstratecan be estimated with reasonable certainty to be economically producible in future periodsproducible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations, etc. (at prices and costs asregulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the date the estimates are made).estimation. Prices include consideration of price changes provided only by contractual arrangements and do not include adjustments based on expected future conditions. For reserves information, see the Supplemental Information on Oil and Gas Exploration and Production Activities under Item 8 of this Form 10-K. Engineering estimates of the quantities of proved reserves are inherently imprecise and represent only approximate amounts because of the judgments involved in developing such information. Occidental’s estimates of proved reserves are made using available geological and reservoir data as well as production performance data. The reliability of these estimates at any point in time depends on both the quality and quantity of the technical and economic data and the efficiency of extracting and processing the hydrocarbons. These estimates are reviewed annually by internal reservoir engineers and revised, either upward or downward, as warranted by additional data. Revisions are necessary due to changes in, among other things, development plans, reservoir performance, prices, economic conditions and governmental restrictions as well as changes in the expected recovery associated with infill drilling. Decreases in prices, for example, may cause a reduction in some proved reserves due to reaching economic limits at an earlier projected date. A material adverse change in the estimated volume of proved reserves could have a negative impact on DD&A and could result in property impairments.
The most significant ongoing financial statement effect from a change in Occidental’s oil and gas reserves or impairment of its proved properties would be to the DD&A rate. For example, a 5% increase or decrease in the amount of oil and gas reserves would change the DD&A rate by approximately $0.80/$0.60/Bbl, which would increase or decrease pre-tax income by approximately $330$270 million annually at current production rates.
FAIR VALUES
Occidental estimates fair-value of long-lived assets for impairment testing, assets and liabilities acquired in a business combination or exchanged in non-monetary transactions, pension plan assets and initial measurements of AROs.
Accounting for the acquisition of a business requires the allocation of the purchase price to the various assets and liabilities of the acquired business and recording deferred taxes for any differences between the allocated values and tax basis of assets and liabilities. Any excess of the purchase price over the amounts assigned to assets and liabilities is
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
recorded as goodwill. The purchase price allocation is accomplished by recording each asset and liability at its estimated fair value.
value, which may be determined using different methods of fair value measurements, largely based on the availability and quality of market information. Occidental primarily applies the market approach for recurring fair value measurements, maximizes its use of observable inputs and minimizes its use of unobservable inputs. When estimating the fair values of assets acquired and liabilities assumed, Occidental must apply various assumptions.
FINANCIAL ASSETS AND LIABILITIES
Occidental utilizes the mid-point between bid and askpublished prices or counterparty statements for valuing the majority of its financial assets and liabilities measured and reported at fair value. In addition to using market data, Occidental makes assumptions in valuing its assets and liabilities, including assumptions about the risks inherent in the inputs to the valuation technique. For financial assets and liabilities carried at fair value, Occidental measures fair value using the following methods:
■Occidental values exchange-cleared commodity derivatives using closing prices provided by the exchange as of the balance sheet date. These derivatives are classified as using quoted prices in active markets for the assets or liabilities (Level 1).
■Over-the-Counter (OTC)OTC bilateral financial commodity contracts, international exchange contracts, options and physical commodity forward purchase and sale contracts are generally classified as using observable inputs other than quoted prices for the assets or liabilities (Level 2) and are generally valued using quotations provided by brokers or industry-standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility factors, credit risk and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace.
■Occidental values commodity derivatives based on a market approach that considers various assumptions, including quoted forward commodity prices and market yield curves. The assumptions used include inputs that are generally unobservable in the marketplace or are observable but have been adjusted based upon various assumptions and the fair value is designated as using unobservable inputs (Level 3) within the valuation hierarchy.
■Occidental values debt using market-observable information for debt instruments that are traded on secondary markets. For debt instruments that are not traded, the fair value is determined by interpolating the value based on debt with similar terms and credit risk.
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
NON-FINANCIAL ASSETS
Occidental uses market-observable prices for assets when comparable transactions can be identified that are similar to the asset being valued. When Occidental is required to measure fair value and there is not a market-observable price for the asset or for a similar asset then the cost or income approach is used depending on the quality of information available to support management’s assumptions. The cost approach is based on management’s best estimate of the current asset replacement cost. The income approach is based on management’s best assumptions regarding expectations of future net cash flows and the expected cash flows are discounted using a commensurate risk-adjusted discount rate. Such evaluations involve significant judgment. The results are based on expected future events or conditions such as sales prices, estimates of future oil and gas production or throughput, development and operating costs and the timing thereof, economic and regulatory climates and other factors, most of which are often outside of management’s control. However, assumptions used reflect a market participant’s view of long-term prices, costs and other factors and are consistent with assumptions used in Occidental’s business plans and investment decisions.
ENVIRONMENTAL LIABILITIES AND EXPENDITURES
EnvironmentalCertain subsidiaries of Occidental incur environmental liabilities and expenditures that relate to current operations and are expensed or capitalized by such subsidiaries as appropriate. Occidental recordsCertain subsidiaries also incur environmental liabilities and expenditures with respect to remediation of existing conditions from alleged past practices at Third-Party, Currently Operated, and Closed or Non-operated Sites. Those environmental liabilities and related charges and expenses for estimated remediation costs that relate to existing conditions from past operations are recorded when environmental remediation efforts are probable and the costs can be reasonably estimated. Occidental discloses such remediation liabilities on a consolidated basis. In determining the environmental remediation liability and the range of reasonably possible additional losses, Occidental refers to currently available information, including relevant past experience, remedial objectives, available technologies, applicable laws and regulations and cost-sharing arrangements. Occidental bases itsThese environmental remediation liabilities are based on management’s estimate of the most likely cost to be incurred, using the most cost-effective technology reasonably expected to achieve the remedial objective. Occidental periodically reviews itsthese environmental remediation liabilities and adjusts them as new information becomes available. Occidental records environmental remediation liabilities on a discounted basis when it deems the aggregate amount and timing of cash payments to be reliably determinable at the time the reserves are established. The reserve methodology with respect to discounting for a specific site is not modified once it is established. Presently none of its environmental remediation liabilities are recorded on a discounted basis. OccidentalOccidental’s subsidiaries generally recordsrecord reimbursements or recoveries of environmental remediation costs in income when received, or when receipt of recovery is highly probable.
Many factors could affect Occidental’s future remediation costs incurred by Occidental’s subsidiaries and result in adjustments to its environmental remediation liabilities and the range of reasonably possible additional losses. The most significant are: (1) cost estimates for remedial activities may vary from the initial estimate; (2) the length of time, type or amount of remediation necessary to achieve the remedial objective may change due to factors such as site conditions, the ability to identify and
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| | MANAGEMENT’S DISCUSSION AND ANALYSIS |
control contaminant sources or the discovery of additional contamination; (3) a regulatory agency may ultimately reject or modify Occidental’s proposed remedial plan;plans; (4) improved or alternative remediation technologies may change remediation costs; (5) laws and regulations may change remediation requirements or affect cost sharing or allocation of liability; and (6) changes in allocation or cost-sharing arrangements may occur.
Certain sites involve multiple parties with various cost-sharing arrangements, which generally fall into the following three categories: (1) environmental proceedings that result in a negotiated or prescribed allocation of remediation costs among Occidentalthe affected Occidental’s subsidiary and other alleged potentially responsible parties; (2) oil and gas ventures in which each participant pays its proportionate share of remediation costs reflecting its working interest; or (3) contractual arrangements, typically relating to purchases and sales of properties, in which the parties to the transaction agree to methods of allocating remediation costs. In these circumstances, Occidentalthe affected subsidiary evaluates the financial viability of other parties with whom it is alleged to be jointly liable, the degree of their commitment to participate and the consequences to Occidentalsuch subsidiary of their failure to participate when estimating Occidental’sits ultimate share of liability. Occidental records itssubsidiaries record environmental remediation liabilities at itstheir expected net cost of remedial activities and, basedactivities. Based on these factors, believesexcept as otherwise disclosed in Note 12 - Environmental Liabilities and Expenditures in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K, Occidental’s subsidiaries believe that itthey will not be required to assume a share of liability of such other potentially responsible parties in an amount materially above amounts reserved. In addition to the costs of investigations and cleanupclean-up measures, which often take in excess of 10 years at CERCLA NPL sites, Occidental’sOccidental subsidiaries’ environmental remediation liabilities include management’s estimates of the costs to operate and maintain remedial systems. If remedial systems are modified over time in response to significant changes in site-specific data, laws, regulations, technologies or engineering estimates, Occidental reviewsOccidental’s subsidiaries review and adjusts itsadjust their environmental remediation liabilities accordingly.
If Occidental or its subsidiaries were to adjust the balance of itstheir environmental remediation liabilities based on the factors described above, the amount of the increase or decrease would be recognized in earnings. For example, if the balance were reduced by 10%, Occidental would record a pre-tax gainincrease to income of $115$105 million. If the balance were increased by 10%, Occidental would record an additional remediation expense of $115$105 million.
INCOME TAXES
Occidental filesand its subsidiaries file various U.S. federal, state and foreign income tax returns. The impact of changes in tax regulations are reflected when enacted. In general, deferred federal, state and foreign income taxes are provided on temporary differences between the financial statement carrying amounts of assets and liabilities and their respective tax basis. Occidental routinely assesses the realizability of its deferred tax assets. If Occidental concludes that it is more likely than not that some of the
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
deferred tax assets will not be realized, the tax asset is reduced by a valuation allowance. Occidental recognizes a tax benefit from an uncertain tax position when it is more likely than not that the position will be sustained upon examination, based on the technical merits of the position. The tax benefit recorded is equal to the largest amount that is greater than 50% likely to be realized through final settlement with a taxing authority. Interest and penalties related to unrecognized tax benefits are recognized in income tax expense (benefit). Occidental uses the flow-through method to account for its investment tax credits. See Note 1210 - Income Taxes in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K.
LOSS CONTINGENCIES
Occidental isor certain of its subsidiaries are involved, in the normal course of business, in lawsuits, claims and other legal proceedings and audits. Occidental or its affected subsidiaries, as appropriate, accrues reserves for these matters when it is probable that a liability has been incurred and the liability can be reasonably estimated. In addition, Occidental discloses, in aggregate itson a consolidated basis, exposure to loss in excess of the amount recorded on the balance sheet for these matters if it is reasonably possible that an additional material loss may be incurred. Occidental reviews itssuch loss contingencies on an ongoing basis.
Loss contingencies are based on judgments made by management with respect to the likely outcome of these matters and are adjusted as appropriate. Management’s judgments could change based on new information, changes in, or interpretations of, laws or regulations, changes in management’s plans or intentions, opinions regarding the outcome of legal proceedings or other factors. See Note 1113 - Lawsuits, Claims, Commitments and Contingencies in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for additional information.
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| 54 | SIGNIFICANT ACCOUNTING OXY 2022 FORM 10-K
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| | MANAGEMENT’S DISCUSSION AND DISCLOSURE CHANGESANALYSIS |
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| SAFE HARBOR DISCUSSION REGARDING OUTLOOK AND OTHER FORWARD-LOOKING DATA |
Portions of this report contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact are “forward-looking statements” for purposes of federal and state securities laws, and they include, but are not limited to: any projections of earnings, revenue or other financial items or future financial position or sources of financing; any statements of the plans, strategies and objectives of management for future operations, business strategy or business strategy;financial position; any statements regarding future economic conditions or performance; any statements of belief; and any statements of assumptions underlying any of the foregoing. Words such as “estimate,” “project,” “predict,” “will,” “would,” “should,” “could,” “may,” “might,” “anticipate,” “plan,” “intend,” “believe,” “expect,” “aim,” “goal,” “target,” “objective,” "commit," "advance," “likely” or similar expressions that convey the prospective nature of events or outcomes are generally indicative of forward-looking statements. You should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Occidental does not undertake any obligation to update, modify or withdraw any forward-looking statements as a result of new information, future events or otherwise.
Although Occidental believes that the expectations reflected in any of its forward-looking statements are reasonable, actual results may differ from anticipated results, sometimes materially. In addition, historical, current and forward-looking sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve and assumptions that are subject to change in the future. Factors that could cause results to differ from those projected or assumed in any forward-looking statement include, but are not limited to: the scopegeneral economic conditions, including slowdowns and duration of the COVID-19 pandemic and actions taken by governmental authorities and other third parties in response to the pandemic;recessions, domestically or internationally; Occidental’s indebtedness and other payment obligations, including the need to generate sufficient cash flows to fund operations; Occidental’s ability to successfully monetize select assets and repay or refinance debt and the impact of changes in Occidental’s credit ratings; the scope and duration of the global or regional health pandemics or epidemics, including the COVID-19 pandemic and ongoing actions taken by governmental authorities and other third parties in response to the pandemic; assumptions about energy markets; global and local commodity and commodity-futures pricing fluctuations such as the sharp decline in crude oil prices that occurred in the first half of 2020;and volatility; supply and demand considerations for, and the prices of, Occidental’s products and services; actions by OPEC and non-OPEC oil producing countries; results from operations and competitive conditions; future impairments of ourOccidental's proved and unproved oil and gas properties or equity investments, or write-downs of productive assets, causing charges to earnings; unexpected changes in costs; inflation, its impact on markets and economic activity and related monetary policy actions by governments in response to inflation; availability of capital resources, levels of capital expenditures and contractual obligations; the regulatory approval environment, including Occidental's ability to timely obtain or maintain permits or other governmental approvals, including those necessary for drilling and/or development projects; Occidental's ability to successfully complete, or any material delay of, field developments, expansion projects, capital expenditures, efficiency projects, acquisitions or dispositions; risks associated with acquisitions, mergers and joint ventures, such as difficulties integrating businesses, uncertainty associated with financial projections, projected synergies, restructuring, increased costs and adverse tax consequences; uncertainties and liabilities associated with acquired and divested properties and businesses; uncertainties about the estimated quantities of oil, NGL and natural gas reserves; lower-than-expected production from development projects or acquisitions;
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| MANAGEMENT’S DISCUSSION AND ANALYSIS | |
Occidental’s ability to realize the anticipated benefits from prior or future streamlining actions to reduce fixed costs, simplify or improve processes and improve Occidental’s competitiveness; exploration, drilling and other operational risks; disruptions to, capacity constraints in, or other limitations on the pipeline systems that deliver Occidental’s oil and natural gas and other processing and transportation considerations; general economic conditions, including slowdowns, domestically or internationally, and volatility in the securities, capital or credit markets; uncertainty fromgovernmental actions, war (including the expected discontinuance of LIBOR and transition to any other interest rate benchmark; governmental actionsRussia-Ukraine war) and political conditions and events; environmental risks and liability under federal, regional, state, provincial, tribal, local and international environmental laws, and regulations, and litigation (including the potential liability for remedial actions or assessments under existing or future laws, regulations and litigation); legislative or regulatory changes, including changes relating to hydraulic fracturing or other oil and natural gas operations, retroactive royalty or production tax regimes, deepwaterdeep-water and onshore drilling and permitting regulations and environmental regulationregulations (including regulations related to climate change); environmental risksOccidental's ability to recognize intended benefits from its business strategies and liability under international, provincial, federal, regional, state, tribal, local and foreign environmental laws and regulations (including remedial actions);initiatives, such as Occidental's low carbon ventures businesses or announced greenhouse gas emissions reduction targets or net-zero goals; potential liability resulting from pending or future litigation; disruption or interruption of production or manufacturing or facility damage due to accidents, chemical releases, labor unrest, weather, power outages, natural disasters, cyber attackscyber-attacks, terrorist acts or insurgent activity; the creditworthiness and performance of Occidental's counterparties, including financial institutions, operating partners and other parties; failure of risk management; Occidental’s ability to retain and hire key personnel; supply, transportation, and labor constraints; reorganization or restructuring of Occidental’s operations; changes in state, federal or foreigninternational tax rates; and actions by third parties that are beyond Occidental's control. The unprecedented nature of the COVID-19 pandemic and recent market decline may make it more difficult to identify potential risks, give rise to risks that are currently unknown or amplify the impact of known risks.
Additional information concerning these and other factors that may cause Occidental’s results of operations and financial position to differ from expectations can be found in Item 1A, “Risk Factors” and elsewhere in this Form 10-K, as well as in Occidental’s other filings with the U.S. Securities and Exchange Commission,SEC, including Occidental’s Quarterly Reports on Form 10-Q and Current Reports on Form 8-K.
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| | QUANTITATIVE AND QUALITATIVE DISCLOSURES |
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
GENERAL
Occidental’s results are sensitive to fluctuations in oil, NGL and natural gas prices. Price changes at current global prices and levels of production affect Occidental’s budgeted 2023 pre-tax annual income by approximately $200 million for a $1 per barrel change in oil prices and $85approximately $30 million for a $1 per barrel change in NGL prices. If domestic natural gas prices varied by $0.10 per Mcf, it would have an estimated annual effect on Occidental’s budgeted 2023 pre-tax income of approximately $35$30 million. These price-change sensitivities include the impact of PSC and similar contract volume changes on income. If production levels change in the future, the sensitivity of Occidental’s results to prices also will change. Marketing results are sensitive to price changes of oil, natural gas and, to a lesser degree, other commodities. A $0.25 change in the Midland-to-Gulf-Coast oil spreads impacts total yearbudgeted 2023 operating cash flows by approximately $65 million.
Occidental’s results are also sensitive to fluctuations in chemical prices. A variation in chlorine and caustic soda prices of $10 per ton would have a pre-tax annual effect on income of approximately $10 million and $30 million, respectively. A variation in PVC prices of $0.01 per lb. would have a pre-tax annual effect on income of approximately $30 million. Historically, over time, product price changes have tracked raw material and feedstock product price changes, somewhat mitigating the effect of price changes on margins.
Occidental uses derivative instruments, including a combination of short-term futures, forwards, options and swaps, to obtain the average prices for the relevant production month and to improve realized prices for oil and gas.
RISK MANAGEMENT
Occidental conducts its risk management activities for marketing and trading under the controls and governance of its risk control policies. The controls under these policies are implemented and enforced by a risk management group which monitors risk by providing an independent and separate evaluation and check. Members of the risk management group report to the Corporate Vice President and Treasurer. Controls for these activities include limits on value at risk, limits on credit, limits on total notional trade value, segregation of duties, delegation of authority, daily price verifications, reporting to senior management on various risk measures and a number of other policy and procedural controls.
FAIR VALUE OF MARKETING DERIVATIVE CONTRACTS
Occidental carries derivative contracts it enters into in connection with its marketing activities at fair value. Fair values for these contracts are derived from Level 1 and Level 2 sources. The fair values in future maturity periods are insignificant.
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| QUANTITATIVE AND QUALITATIVE DISCLOSURES | |
The following table shows the fair value of Occidental’s derivatives (excluding collateral), segregated by maturity periods and by methodology of fair value estimation:
| | | Maturity Periods | | | | Maturity Periods | | |
Source of Fair Value Assets/(Liabilities) millions | | 2021 | | 2022 and 2023 | | 2024 and 2025 | | 2026 and thereafter | | Total | |
Source of Fair Value Assets (Liabilities) millions | | Source of Fair Value Assets (Liabilities) millions | | 2023 | | 2024 and 2025 | | 2026 and 2027 | | 2028 and thereafter | | Total |
| Prices actively quoted | Prices actively quoted | | $ | (97) | | | $ | — | | | $ | — | | | $ | — | | | $ | (97) | | Prices actively quoted | | $ | (18) | | | $ | — | | | $ | — | | | $ | — | | | $ | (18) | |
| Prices provided by other external sources | Prices provided by other external sources | | (1) | | | 2 | | | — | | | — | | | 1 | | Prices provided by other external sources | | 31 | | | 1 | | | — | | | — | | | 32 | |
| Total | Total | | $ | (98) | | | $ | 2 | | | $ | — | | | $ | — | | | $ | (96) | | Total | | $ | 13 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 14 | |
QUANTITATIVE INFORMATION
Occidental uses value at risk to estimate the potential effects of changes in fair values of commodity contracts used in trading activities. This measure determines the maximum potential negative one day change in fair value with a 95% level of confidence. Additionally, Occidental uses complementary trading limits including position and tenor limits and maintains liquid positions as a result of which market risk typically can be neutralized or mitigated on short notice. As a result of these controls, Occidental believes that the market risk of its trading activities is not reasonably likely to have a material adverse effect on its performance.
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| | QUANTITATIVE AND QUALITATIVE DISCLOSURES |
GENERAL
Occidental acquired interest rate swap contracts in the Acquisition. Occidental pays a fixed interest rate and receives a floating interest rate indexed to three-month LIBOR. The swaps have an initial term of 30 years with mandatory termination dates in September 2021 through 2023 and a total notional amount of approximately $1.5 billion as of December 31, 2020. As of December 31, 2020, Occidental had a net liability of approximately $1.4 billion based on the fair value of the swaps of negative $1.8 billion netted against $374 million in posted cash collateral. A 25-basis point decrease in implied LIBOR rates over the term of the swaps would result in an additional liability of approximately $173 million on these swaps.
As of December 31, 2020, Occidental had variable rate debt with a notional value of $1.1 billion outstanding. A 25-basis point increase in LIBOR interest rates would increase gross interest expense approximately $3 million per year.
As of December 31, 2020,2022, Occidental had fixed rate debt with a fair value of $32.7$17.5 billion outstanding. A 25-basis point change in Treasury rates would change the fair value of the fixed rate debt approximately $600$295 million.
TABULAR PRESENTATION OF INTEREST RATE RISK
The table below provides information about Occidental’s long-term debt obligations. Debt amounts represent principal payments by maturity date.
| | millions except percentages | millions except percentages | | U.S. Dollar
Fixed-Rate Debt | | U.S. Dollar
Variable-Rate Debt | | Total (a) | millions except percentages | | U.S. Dollar
Fixed-Rate Debt | | U.S. Dollar
Variable-Rate Debt | | Total (a) |
| 2021 | | $ | 371 | | | $ | 27 | | | $ | 398 | | |
| 2022 | | 1,006 | | | 1,052 | | | 2,058 | | |
| 2023 | 2023 | | 949 | | | — | | | 949 | | 2023 | | $ | 22 | | | $ | — | | | $ | 22 | |
| 2024 | 2024 | | 3,898 | | | — | | | 3,898 | | 2024 | | 1,056 | | | — | | | 1,056 | |
| 2025 | 2025 | | 2,900 | | | — | | | 2,900 | | 2025 | | 1,208 | | | — | | | 1,208 | |
| 2026 | | 2026 | | 1,448 | | | — | | | 1,448 | |
| 2027 | | 2027 | | 903 | | | — | | | 903 | |
| Thereafter | Thereafter | | 24,964 | | | 68 | | | 25,032 | | Thereafter | | 13,253 | | | 68 | | | 13,321 | |
| Total | Total | | $ | 34,088 | | | $ | 1,147 | | | $ | 35,235 | | Total | | $ | 17,890 | | | $ | 68 | | | $ | 17,958 | |
| Weighted-average interest rate | Weighted-average interest rate | | 4.78% | | 1.73% | | 4.68% | Weighted-average interest rate | | 5.92% | | 5.32% | | 5.91% |
| Fair Value | Fair Value | | $ | 32,678 | | | $ | 1,128 | | | $ | 33,806 | | Fair Value | | $ | 17,508 | | | $ | 68 | | | $ | 17,576 | |
(a)Excluded net unamortized debt premiums of $748 million$1.3 billion and debt issuance costcosts of $156$73 million.
Occidental’s international operations have limited currency risk. Occidental manages its exposure primarily by balancing monetary assets and liabilities and limiting cash positions in foreign currencies to levels necessary for operating purposes. A vast majority of international oil sales are denominated in United States dollars. Additionally, all of Occidental’s consolidated
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| QUANTITATIVE AND QUALITATIVE DISCLOSURES | |
international oil and gas subsidiaries have the United States dollar as the functional currency. As of December 31, 2020, the fair value of foreign currency derivatives used in the marketing operations was immaterial. The effect of exchange rates on transactions in foreign currencies is included in periodic income.
The majority of Occidental’s counterparty credit risk is related to the physical delivery of energy commodities to its customers and any inability of these customers to meet their settlement commitments. Occidental manages credit risk by selecting counterparties that it believes to be financially strong, by entering into netting arrangements with counterparties and by requiring collateral or other credit risk mitigants, as appropriate. Occidental actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. Occidental also enters into futures contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk, as a significant portion of these transactions settle on a daily margin basis.
Certain OTC derivative instruments contain credit-risk-contingent features, primarily tied to credit ratings for Occidental or its counterparties, which may affect the amount of collateral that each party would need to post. The fair value of derivative instruments with credit-risk-contingent features, that were net liabilities at December 31, 2020 was $104 million (net of $374 million collateral) and $787 million (net of $169 million collateral) at December 31, 2019. Credit-risk-contingent features are primarily related to interest rate swaps.if any.
As of December 31, 2020,2022, the substantial majority of the credit exposures were with investment grade counterparties. Occidental believes its exposure to credit-related losses atas of December 31, 2020,2022, was not material and losses associated with credit risk have been insignificant for all years presented.
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DERIVATIVE INSTRUMENTS HELD FOR NON-TRADING PURPOSES |
As of December 31, 2020, Occidental had derivative instruments in place to reduce the price risk associated with future oil production of 350Mbbl/d. As of December 31, 2020, these derivative instruments were at a $42 million net derivative liability position.
The following table shows a sensitivity analysis based on both a 5% and 10% change in commodity prices and their effect on the net derivative liability position of $42 million at December 31, 2020:
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| millions except percentages | | | |
| Percent change in commodity prices | | Resulting net fair value position-asset (liability) | | Change to fair value from December 31, 2020 position |
| + 5% | | | $ | (67) | | | | $ | (25) | |
| - 5% | | | $ | (26) | | | | $ | 16 | |
| + 10% | | | $ | (102) | | | | $ | (60) | |
| -10% | | | $ | (15) | | | | $ | 27 | |
As of December 31, 2020, Occidental had derivative instruments in place to reduce the price risk associated with future gas production of 530 thousand MMbtu/d. As of December 31, 2020, these derivative instruments were at a $25 million net derivative asset position.
The following table shows a sensitivity analysis based on both a 5% and 10% change in commodity prices and their effect on the net derivative asset position of $25 million at December 31, 2020:
| | | | | | | | | | | | | | | | | | | | |
| millions except percentages | | | |
| Percent change in commodity prices | | Resulting net fair value position-asset (liability) | | Change to fair value from December 31, 2020 position |
| + 5% | | | $ | 13 | | | | $ | (12) | |
| - 5% | | | $ | 37 | | | | $ | 12 | |
| + 10% | | | $ | 1 | | | | $ | (24) | |
| -10% | | | $ | 51 | | | | $ | 26 | |
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OXY 20202022 FORM 10-K | 5557 |
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| | FINANCIAL STATEMENTS INDEX | |
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
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5658 | OXY 20202022 FORM 10-K |
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| | FINANCIAL STATEMENTS REPORT | |
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
Occidental Petroleum Corporation:
Opinion on the ConsolidatedFinancial Statements
We have audited the accompanying consolidated balance sheets of Occidental Petroleum Corporation and subsidiaries (the Company) as of December 31, 20202022 and 2019,2021, the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows for each of the years in the three‑yearthree-year period ended December 31, 2020,2022, and the related notes and financial statement schedule II –- valuation and qualifying accounts (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 20202022 and 2019,2021, and the results of its operations and its cash flows for each of the years in the three‑yearthree-year period ended December 31, 2020,2022, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2020,2022, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 26, 202127, 2023 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.
Change in Accounting Principle
As discussed in Notes 2 and 8 to the consolidated financial statements, the Company changed its method of accounting for leases as of January 1, 2019 due to the adoption of Accounting Standards Codification Topic 842, Leases.reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
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| FINANCIAL STATEMENTS
REPORT
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Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Evaluation of the environmental liability associated with the lower 8.3 miles of the Lower Passaic River site
As discussed in Notes 1 and 10 to the consolidated financial statements, the Company accrues a liability for estimated environmental remedial activities when it is probable a liability has been incurred and the amount of remediation costs can be estimated. The Company accrued a liability related to its estimated allocable share of the costs to perform the remedial activities required for the lower 8.3 miles of the Lower Passaic River site. As of December 31, 2020, the Company’s estimated environmental liabilities were $1.2 billion.
We identified the evaluation of the environmental liability associated with the lower 8.3 miles of the Lower Passaic River site as a critical audit matter. There was a high degree of subjective auditor judgment in applying and evaluating the results of our procedures. This is due to (1) possible changes to expected remedial activities to implement the proposed clean-up plan outlined in the Record of Decision (ROD) issued by the Environmental Protection Agency (EPA) and their estimated costs, and (2) possible changes to the Company’s estimated share of the remediation costs.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s environmental liability process to estimate the cost of remedial activities and estimate the Company’s allocable share of the remediation costs. We evaluated the remedial activities and related cost assumptions used by the Company by comparing them against remedial activities and cost estimates provided by the EPA in the ROD. We compared certain design documentation provided by the Company to the EPA in order to identify potential differences between the design plan and the ROD and assessed the impact of any such differences on the remediation cost assumptions used by the Company to estimate the liability. We assessed the Company’s assumption for its allocable share of the remediation costs and analyzed publicly available data sources for information that might be contrary to the information used by the Company. We involved an environmental analysis professional with specialized skills and knowledge who assisted in reading correspondence between the Company and the EPA related to the design phase for this site to assess the Company’s remediation cost assumptions.
Assessment of the estimated proved oil and gas reserves on the determination of depreciation and depletion expense related tofor proved oil and gas propertiesproperties.
As discussed in Note 1 to the consolidated financial statements, the Company determines depreciation and depletion of oil and gas producing properties by the unit-of-production method. Under this method, capitalized costs are amortized over estimated proved reserves. For the year ended December 31, 2020,2022, the Company recorded depreciation and depletion expense related to proved oil and gas properties of $7.4$6.2 billion.
We identified the assessment of the estimated proved oil and gas reserves on the determination of depreciation and depletion expense related to proved oil and gas properties as a critical audit matter. Complex auditor judgment was required to assess the Company’s estimate of proved oil and gas reserves, which is a key input for the determination of depreciation and depletion expense. Estimating proved oil and gas reserves requires the expertise of professional petroleum reservoir engineers. The key assumptions included (1) commodity prices, inclusive of market differentials, (2) estimated future production quantities, and (3)(2) estimated operating and capital costs.
| | | | | | | | |
| FINANCIAL STATEMENTS
REPORT
| |
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s depreciation and depletion process, including the estimation of proved oil and gas reserves. We analyzed and assessed the determination of depreciation and depletion expense for compliance with industry and regulatory standards. We
| | | | | | | | |
| | FINANCIAL STATEMENTS REPORT |
assessed compliance of the methodology used by the Company’s engineering and technical staff to estimate proved oil and gas reserves with industry and regulatory standards. We read the findings of the independent reservoir engineering specialist’s review of the methods and procedures used by the Company in estimating the proved reserves for compliance with industry and regulatory standards. We assessed the commodity prices, including relevant market differentials, used by the Company’s engineering and technical staff by comparing them to publicly available prices, adjusted for historical market differentials. To assess the Company’s ability to accurately estimate future production quantities, we compared the future production quantity assumptions used by the Company in prior periods to the actual production amounts. We compared the estimated future production quantities used by the Company in the current period to historical production rates. We evaluated the operating and capital cost assumptions used by the Company’s engineering and technical staff by comparing them to historical costs. We evaluated the professional qualifications and the knowledge, skills, and ability of the Company’s internal reserve engineers and the independent reservoir engineering specialists engaged by the Company.
Evaluation of the recoverability and fair value estimateenvironmental liability associated with the lower 8.3 miles of certain proved oil and gas propertiesthe Lower Passaic River site.
As discussed in Notes 1 and 1712 to the consolidated financial statements, the Company performs impairment tests with respectaccrues a liability for estimated environmental remedial activities when it is probable a liability has been incurred and the amount of remediation costs can be estimated. The Company accrued a liability related to its proved oil and gas properties whenever events or circumstances indicate that the carrying value of property may not be recoverable. If there is an indication the carrying amountestimated allocable share of the asset may not be recovered,costs to perform the Company estimatesremedial activities required for the undiscounted cash flowslower 8.3 miles of the proved oil and gas property and comparesLower Passaic River site. As of December 31, 2022, the undiscounted cash flows to carrying valueCompany’s total estimated environmental liabilities were $1 billion, which includes the estimated environmental liability for the lower 8.3 miles of the proved property. If the sum of the undiscounted cash flows is less than the carrying value of the proved property, the carrying value is reduced to estimated fair value and reported as an impairment charge in the period. The Company recorded impairment charges of $4.6 billion for its proved oil and gas properties, including properties held for sale, for the year ended December 31, 2020.Lower Passaic River Site.
We identified the evaluation of the recoverability and fair value estimateenvironmental liability associated with the lower 8.3 miles of certain proved oil and gas propertiesthe Lower Passaic River site as a critical audit matter. SubjectiveThere was a high degree of subjective auditor judgment was requiredin applying and evaluating the results of our procedures due to evaluatepossible changes to the key assumptions usedCompany’s estimated allocable share of the remediation costs.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s environmental liability process to estimate the undiscounted future net cash flowsCompany’s allocable share of the remediation costs associated with the lower 8.3 miles of the Lower Passaic River site. We assessed the Company’s assumption for its allocable share of the remediation costs and analyzed publicly available data sources for information that might be contrary to the information used by the Company. We involved an environmental analysis professional with specialized skills and knowledge who assisted in the recoverability analysisevaluation of information used by management, including publicly available data sources.
Determination of tax impact of the legal entity reorganization
As discussed in Note 10 to the consolidated financial statements, the Company completed a legal entity reorganization in the first quarter of 2022 that resulted in an adjustment to the tax basis in a portion of its operating assets that reduced its deferred tax liabilities. As a result of the legal entity reorganization, the Company recorded a tax benefit of $2.7 billion.
We identified the evaluation of the tax impact due to the legal entity reorganization as a critical audit matter. Evaluating the application of the United States tax laws and regulations, which can be complex, and the discounted future net cash flows used in the determinationtax impact required a high degree of fair value for those properties where the carrying value exceeded the undiscounted cash flows. The key assumptions included (1) estimated future commodities prices, (2) estimated future production quantities, (3) estimated future operatingauditor effort and capital costs, (4) discount rate,specialized skills and (5) reserve category risk adjustment factors.knowledge.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s proved oil and gas impairment process, including controls related to the key assumptions. We compared benchmark commodity prices used byCompany’s process of determining the Company in estimating future commodity prices to publicly disclosed projected commodity prices. To assess the Company’s ability to accurately estimate future production quantities, we compared the future production quantity assumptions used by the Company in prior periodstax impact due to the actual production amounts. We comparedlegal entity reorganization including the estimated future production quantities used by the Company in the current period to historical production rates.application of United States tax laws and regulations. We evaluated the estimated future operatinginformation, including third party opinions, United States tax laws and capital cost assumptionsregulations, and other relevant evidence used by comparing themmanagement to historical costs. Wesupport its position regarding the tax impact of the transaction; and evaluated the professional qualifications and the knowledge, skills, and ability of the Company’s internal reserve engineers, including their ability to estimate applicable reserve category risk adjustment factors. In addition, welegal entity reorganization related tax impact. We involved valuationincome tax professionals with specialized skills and knowledge who assisted in evaluating the (1) discount rate by comparing it to a discount rate range that was independently developed using publicly available market data for comparable entities and (2) reserve category risk adjustment factors by comparing them to third party publications of risk adjustment factors utilized by market participants.evaluation of:
Evaluation■ the tax impact of the fair value measurementlegal entity reorganization
■ certain facts, representations and assumptions from management
■ the application of certain unproved oilrelevant United States tax laws and gas properties
As discussed in Notes 1 and 17 to the consolidated financial statements, the Company performs impairment tests with respect to its unproved oil and gas properties whenever events or circumstances indicate that the carrying value of property may not be recoverable. Occidental periodically reviews unproved properties for impairments; numerous factors are considered, including but not limited to, current exploration and development plans, favorable or unfavorable exploration activity, geologists’ evaluation of the property, the current and projected political and regulatory climate, and the remaining
| | | | | | | | |
| FINANCIAL STATEMENTS
REPORT
| |
lease term for the property. The Company measured the fair value of certain domestic onshore unproved property based on a market approach using an implied acreage valuation derived from domestic onshore market participants excluding the fair value assigned to proved properties, which was based on an income approach. Impairment charges of $4.6 billion were recorded for the year ended December 31, 2020.
We identified the evaluation of the fair value of certain domestic onshore unproved oil and gas properties as a critical audit matter. A high degree of subjectivity was involved in evaluating the results of the market-based enterprise values, the control premium, and the discounted cash flow models used in the income approach. The evaluation of the market-based enterprise values and control premium included determining which market participants had acreage positions most comparable to the Company’s acreage position of certain domestic onshore oil and gas properties. In addition, the income approach utilized risk adjusted discounted cash flow models, which included several significant assumptions. The key assumptions used in the risk adjusted discounted cash flow models include (1) estimated future commodities prices, (2) estimated future production quantities, (3) estimated future operating and capital costs, (4) discount rate, and (5) reserve category risk adjustment factors.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s unproved oil and gas impairment process, including controls related to the key assumptions, identification of comparable acreage positions and selection of the control premium. We evaluated the selection of market participants having acreage positions most comparable to the Company by comparing the domestic onshore acreage held by the market participants to the oil and gas properties under evaluation. We compared benchmark commodity prices used by the Company in estimating future commodity prices to publicly disclosed projected commodity prices. To assess the Company’s ability to accurately estimate future production quantities, we compared the future production quantity assumptions used by the Company in prior periods to the actual production amounts. We compared estimated future production quantities used by the Company in the current period to historical production rates. We evaluated the estimated future operating and capital cost assumptions by comparing them to historical costs. We evaluated the professional qualifications and the knowledge, skills, and ability of the Company’s internal reserve engineers, including their ability to estimate applicable reserve category risk adjustment factors. In addition, we involved valuation professionals with specialized skills and knowledge, who assisted in evaluating the Company’s:
• market-based enterprise value by comparing the Company’s estimated value for certain domestic onshore unproved oil and gas properties to a range of indicated values based on comparable companies using publicly available market data
• control premium by comparing it to a control premium range that was independently developed using publicly available market data for comparable companies
• discount rate by comparing it to a discount rate range that was independently developed using publicly available market data for comparable entities
• reserve category risk adjustment factors by comparing them to third party publications of risk adjustment factors utilized by market participants
/s/ KPMG LLPregulations.
We have served as the Company’s auditor since 2002.
Houston, Texas
February 26, 2021
27, 2023
| | | | | | | | |
| | FINANCIAL STATEMENTS REPORT | |
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
Occidental Petroleum Corporation:
Opinion on Internal Control Over Financial Reporting
We have audited Occidental Petroleum Corporation and subsidiaries’subsidiaries' (the Company) internal control over financial reporting as of December 31, 2020,2022, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020,2022, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 20202022 and 2019,2021, the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2020,2022, and the related notes and financial statement schedule II –- valuation and qualifying accounts (collectively, the consolidated financial statements), and our report dated February 26, 202127, 2023 expressed an unqualified opinion on those consolidated financial statements.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Assessment of and Report on Internal Control overOver Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ KPMG LLP
Houston, Texas
February 26, 202127, 2023
| | | | | |
| Consolidated Balance Sheets | Occidental Petroleum Corporation
and Subsidiaries |
| | | | | | | | | | | | | | |
| | December 31, |
| millions | | 2022 | | 2021 |
| ASSETS | | | | |
| CURRENT ASSETS | | | | |
| Cash and cash equivalents | | $ | 984 | | | $ | 2,764 | |
| Trade receivables, net of reserves of $37 in 2022 and $35 in 2021 | | 4,281 | | | 4,208 | |
| Inventories | | 2,059 | | | 1,846 | |
| | | | |
| Other current assets | | 1,562 | | | 1,393 | |
| Total current assets | | 8,886 | | | 10,211 | |
| | | | |
| INVESTMENTS IN UNCONSOLIDATED ENTITIES | | 3,176 | | | 2,938 | |
| | | | |
| PROPERTY, PLANT AND EQUIPMENT | | | | |
| Oil and gas | | 104,487 | | | 101,251 | |
| Chemical | | 7,808 | | | 7,571 | |
| Midstream and marketing | | 7,550 | | | 8,371 | |
| Corporate | | 889 | | | 964 | |
| | 120,734 | | | 118,157 | |
| Accumulated depreciation, depletion and amortization | | (62,350) | | | (58,227) | |
| Total property, plant and equipment, net | | 58,384 | | | 59,930 | |
| | | | |
| OPERATING LEASE ASSETS | | 903 | | | 726 | |
| | | | |
| LONG-TERM RECEIVABLES AND OTHER ASSETS, NET | | 1,260 | | | 1,231 | |
| | | | |
| TOTAL ASSETS | | $ | 72,609 | | | $ | 75,036 | |
The accompanying notes are an integral part of these Consolidated Financial Statements.
| | | | | |
| Consolidated Balance Sheets | Occidental Petroleum Corporation
and Subsidiaries |
| | | | | | | | | | | | | | |
| | December 31, |
| millions | | 2020 | | 2019 |
| ASSETS | | | | |
| CURRENT ASSETS | | | | |
| Cash and cash equivalents | | $ | 2,008 | | | $ | 3,032 | |
| Restricted cash and restricted cash equivalents | | 170 | | | 485 | |
| Trade receivables, net of reserves of $24 in 2020 and $19 in 2019 | | 2,115 | | | 4,233 | |
| Inventories | | 1,898 | | | 1,581 | |
| Assets held for sale | | 1,433 | | | 3,870 | |
| Other current assets | | 1,195 | | | 1,432 | |
| Total current assets | | 8,819 | | | 14,633 | |
| | | | |
| INVESTMENTS IN UNCONSOLIDATED ENTITIES | | 3,250 | | | 6,389 | |
| | | | |
| PROPERTY, PLANT AND EQUIPMENT | | | | |
| Oil and gas | | 102,454 | | | 107,801 | |
| Chemical | | 7,356 | | | 7,172 | |
| Midstream and marketing | | 8,232 | | | 8,176 | |
| Corporate | | 922 | | | 1,118 | |
| | 118,964 | | | 124,267 | |
| Accumulated depreciation, depletion and amortization | | (53,075) | | | (42,037) | |
| Total property, plant and equipment, net | | 65,889 | | | 82,230 | |
| | | | |
| OPERATING LEASE ASSETS | | 1,062 | | | 1,411 | |
| | | | |
| LONG-TERM RECEIVABLES AND OTHER ASSETS, NET | | 1,044 | | | 2,527 | |
| | | | |
| TOTAL ASSETS | | $ | 80,064 | | | $ | 107,190 | |
| | | | | | | | | | | | | | |
| | December 31, |
| millions except share and per-share amounts | | 2022 | | 2021 |
| LIABILITIES AND EQUITY | | | | |
| CURRENT LIABILITIES | | | | |
Current maturities of long-term debt (a) | | $ | 165 | | | $ | 186 | |
| Current operating lease liabilities | | 273 | | | 186 | |
| Accounts payable | | 4,029 | | | 3,899 | |
| Accrued liabilities | | 3,290 | | | 4,053 | |
| | | | |
| Total current liabilities | | 7,757 | | | 8,324 | |
| | | | |
| LONG-TERM DEBT, NET | | | | |
Long-term debt, net (b) | | 19,670 | | | 29,431 | |
| | | | |
| DEFERRED CREDITS AND OTHER LIABILITIES | | | | |
| Deferred income taxes, net | | 5,512 | | | 7,039 | |
| Asset retirement obligations | | 3,636 | | | 3,687 | |
| Pension and postretirement obligations | | 1,055 | | | 1,540 | |
| Environmental remediation liabilities | | 905 | | | 944 | |
| Operating lease liabilities | | 657 | | | 585 | |
| Other | | 3,332 | | | 3,159 | |
| Total deferred credits and other liabilities | | 15,097 | | | 16,954 | |
| | | | |
| EQUITY | | | | |
| Preferred stock, at $1.00 per share par value (100,000 shares as of December 31, 2022 and 2021) | | 9,762 | | | 9,762 | |
| Common stock, $0.20 per share par value, authorized shares: 1.5 billion, issued shares: 2022 — 1,098,512,626 and 2021 — 1,083,423,094 | | 220 | | | 217 | |
| Treasury stock: 2022 — 198,653,682 shares and 2021 — 149,348,394 shares | | (13,772) | | | (10,673) | |
| Additional paid-in capital | | 17,181 | | | 16,749 | |
| Retained earnings | | 16,499 | | | 4,480 | |
| Accumulated other comprehensive income (loss) | | 195 | | | (208) | |
| Total stockholders’ equity | | 30,085 | | | 20,327 | |
| | | | |
| TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY | | $ | 72,609 | | | $ | 75,036 | |
(a)Included $143 million and $85 million of current finance lease liabilities as of December 31, 2022 and 2021, respectively.
(b)Included $546 million and $504 million of finance lease liabilities as of December 31, 2022 and 2021, respectively.
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Financial Statements.
| | | | | |
Consolidated Balance Sheets | Occidental Petroleum Corporation
and Subsidiaries |
| | | | | | | | | | | | | | |
| | December 31, |
| millions except share and per-share amounts | | 2020 | | 2019 |
| LIABILITIES AND EQUITY | | | | |
| CURRENT LIABILITIES | | | | |
| Current maturities of long-term debt | | $ | 440 | | | $ | 51 | |
| Current operating lease liabilities | | 473 | | | 579 | |
| Accounts payable | | 2,987 | | | 4,910 | |
| Accrued liabilities | | 3,570 | | | 5,447 | |
| Liabilities of assets held for sale | | 753 | | | 1,718 | |
| Total current liabilities | | 8,223 | | | 12,705 | |
| | | | |
| LONG-TERM DEBT, NET | | | | |
| Long-term debt, net | | 35,745 | | | 38,537 | |
| | | | |
| DEFERRED CREDITS AND OTHER LIABILITIES | | | | |
| Deferred income taxes, net | | 7,113 | | | 9,717 | |
| Asset retirement obligations | | 3,977 | | | 4,411 | |
| Pension and postretirement obligations | | 1,763 | | | 1,823 | |
| Environmental remediation liabilities | | 1,028 | | | 1,035 | |
| Operating lease liabilities | | 641 | | | 872 | |
| Other | | 3,001 | | | 3,858 | |
| Total deferred credits and other liabilities | | 17,523 | | | 21,716 | |
| | | | |
| EQUITY | | | | |
| Preferred stock, at $1.00 per share par value (100,000 shares at December 31, 2020) | | 9,762 | | | 9,762 | |
Common stock, $0.20 per share par value, authorized shares: 1.5 billion, issued shares: 2020 — 1,080,564,947 and 2019 — 1,044,434,893 | | 216 | | | 209 | |
| Treasury stock: 2020 — 149,051,634 shares and 2019 — 150,323,151 shares | | (10,665) | | | (10,653) | |
| Additional paid-in capital | | 16,552 | | | 14,955 | |
| Retained earnings | | 2,996 | | | 20,180 | |
| Accumulated other comprehensive loss | | (288) | | | (221) | |
| Total stockholders’ equity | | 18,573 | | | 34,232 | |
| | | | |
| TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY | | $ | 80,064 | | | $ | 107,190 | |
The accompanying notes are an integral part of these consolidated financial statements.
| | | | | |
| Consolidated Statements of Operations | Occidental Petroleum Corporation
and Subsidiaries |
| | | Years Ended December 31, | | Years Ended December 31, |
| millions except per-share amounts | millions except per-share amounts | | 2020 | | 2019 | | 2018 | millions except per-share amounts | | 2022 | | 2021 | | 2020 |
| REVENUES AND OTHER INCOME | REVENUES AND OTHER INCOME | | | | | | | REVENUES AND OTHER INCOME | | | | | | |
| Net sales | Net sales | | $ | 17,809 | | | $ | 20,911 | | | $ | 17,824 | | Net sales | | $ | 36,634 | | | $ | 25,956 | | | $ | 17,809 | |
| Interest, dividends and other income | Interest, dividends and other income | | 118 | | | 217 | | | 136 | | Interest, dividends and other income | | 153 | | | 166 | | | 118 | |
| Gains (losses) on sale of assets, net | Gains (losses) on sale of assets, net | | (1,666) | | | 622 | | | 974 | | Gains (losses) on sale of assets, net | | 308 | | | 192 | | | (1,666) | |
| Total | Total | | 16,261 | | | 21,750 | | | 18,934 | | Total | | 37,095 | | | 26,314 | | | 16,261 | |
| | COSTS AND OTHER DEDUCTIONS | COSTS AND OTHER DEDUCTIONS | | | COSTS AND OTHER DEDUCTIONS | | |
| Oil and gas operating expense | Oil and gas operating expense | | 3,065 | | | 3,282 | | | 2,761 | | Oil and gas operating expense | | 4,028 | | | 3,160 | | | 3,065 | |
| Transportation and gathering expense | Transportation and gathering expense | | 1,600 | | | 635 | | | 152 | | Transportation and gathering expense | | 1,475 | | | 1,419 | | | 1,600 | |
| Chemical and midstream cost of sales | Chemical and midstream cost of sales | | 2,408 | | | 2,791 | | | 2,833 | | Chemical and midstream cost of sales | | 3,273 | | | 2,772 | | | 2,408 | |
| Purchased commodities | Purchased commodities | | 1,395 | | | 1,679 | | | 822 | | Purchased commodities | | 3,287 | | | 2,308 | | | 1,395 | |
| Selling, general and administrative | Selling, general and administrative | | 864 | | | 893 | | | 585 | | Selling, general and administrative | | 945 | | | 863 | | | 864 | |
| Other operating and non-operating expense | Other operating and non-operating expense | | 884 | | | 1,421 | | | 1,028 | | Other operating and non-operating expense | | 1,271 | | | 1,065 | | | 884 | |
| Taxes other than on income | | Taxes other than on income | | 1,548 | | | 1,005 | | | 622 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | | 8,097 | | | 6,140 | | | 3,977 | | Depreciation, depletion and amortization | | 6,926 | | | 8,447 | | | 8,097 | |
| Asset impairments and other charges | Asset impairments and other charges | | 11,083 | | | 1,361 | | | 561 | | Asset impairments and other charges | | — | | | 304 | | | 11,083 | |
| Taxes other than on income | | 622 | | | 840 | | | 439 | | |
| Anadarko Acquisition-related costs | Anadarko Acquisition-related costs | | 339 | | | 1,647 | | | 0 | | Anadarko Acquisition-related costs | | 89 | | | 153 | | | 339 | |
| Exploration expense | Exploration expense | | 132 | | | 247 | | | 110 | | Exploration expense | | 216 | | | 252 | | | 132 | |
| Interest and debt expense, net | Interest and debt expense, net | | 1,424 | | | 1,066 | | | 389 | | Interest and debt expense, net | | 1,030 | | | 1,614 | | | 1,424 | |
| Total | Total | | 31,913 | | | 22,002 | | | 13,657 | | Total | | 24,088 | | | 23,362 | | | 31,913 | |
| Income (loss) before income taxes and other items | Income (loss) before income taxes and other items | | (15,652) | | | (252) | | | 5,277 | | Income (loss) before income taxes and other items | | 13,007 | | | 2,952 | | | (15,652) | |
| OTHER ITEMS | OTHER ITEMS | | OTHER ITEMS | |
| Gains (losses) on interest rate swaps and warrants, net | Gains (losses) on interest rate swaps and warrants, net | | (423) | | | 233 | | | 0 | | Gains (losses) on interest rate swaps and warrants, net | | 317 | | | 122 | | | (423) | |
| Income from equity investments | Income from equity investments | | 370 | | | 373 | | | 331 | | Income from equity investments | | 793 | | | 631 | | | 370 | |
| Total | Total | | (53) | | | 606 | | | 331 | | Total | | 1,110 | | | 753 | | | (53) | |
| Income (loss) from continuing operations before income taxes | Income (loss) from continuing operations before income taxes | | (15,705) | | | 354 | | | 5,608 | | Income (loss) from continuing operations before income taxes | | 14,117 | | | 3,705 | | | (15,705) | |
| Income tax benefit (expense) | Income tax benefit (expense) | | 2,172 | | | (861) | | | (1,477) | | Income tax benefit (expense) | | (813) | | | (915) | | | 2,172 | |
| Income (loss) from continuing operations | Income (loss) from continuing operations | | (13,533) | | | (507) | | | 4,131 | | Income (loss) from continuing operations | | 13,304 | | | 2,790 | | | (13,533) | |
| Loss from discontinued operations, net of tax | Loss from discontinued operations, net of tax | | (1,298) | | | (15) | | | 0 | | Loss from discontinued operations, net of tax | | — | | | (468) | | | (1,298) | |
| | NET (LOSS) INCOME | | (14,831) | | | (522) | | | 4,131 | | |
| Less: Net loss attributable to noncontrolling interest | | 0 | | | (145) | | | 0 | | |
| NET INCOME (LOSS) | | NET INCOME (LOSS) | | 13,304 | | | 2,322 | | | (14,831) | |
| | Less: Preferred stock dividends | Less: Preferred stock dividends | | (844) | | | (318) | | | 0 | | Less: Preferred stock dividends | | (800) | | | (800) | | | (844) | |
| NET (LOSS) INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS | | $ | (15,675) | | | $ | (985) | | | $ | 4,131 | | |
| NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS | | NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS | | $ | 12,504 | | | $ | 1,522 | | | $ | (15,675) | |
| | PER COMMON SHARE | PER COMMON SHARE | | | | | | | PER COMMON SHARE | | | | | | |
| Income (loss) from continuing operations—basic | Income (loss) from continuing operations—basic | | $ | (15.65) | | | $ | (1.20) | | | $ | 5.40 | | Income (loss) from continuing operations—basic | | $ | 13.41 | | | $ | 2.12 | | | $ | (15.65) | |
| Loss from discontinued operations—basic | Loss from discontinued operations—basic | | (1.41) | | | (0.02) | | | 0 | | Loss from discontinued operations—basic | | — | | | (0.50) | | | (1.41) | |
| Net income (loss) attributable to common stockholders—basic | Net income (loss) attributable to common stockholders—basic | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.40 | | Net income (loss) attributable to common stockholders—basic | | $ | 13.41 | | | $ | 1.62 | | | $ | (17.06) | |
| | Income (loss) from continuing operations—diluted | Income (loss) from continuing operations—diluted | | $ | (15.65) | | | $ | (1.20) | | | $ | 5.39 | | Income (loss) from continuing operations—diluted | | $ | 12.40 | | | $ | 2.06 | | | $ | (15.65) | |
| Loss from discontinued operations—diluted | Loss from discontinued operations—diluted | | (1.41) | | | (0.02) | | | 0 | | Loss from discontinued operations—diluted | | — | | | (0.48) | | | (1.41) | |
| Net income (loss) attributable to common stockholders—diluted | Net income (loss) attributable to common stockholders—diluted | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.39 | | Net income (loss) attributable to common stockholders—diluted | | $ | 12.40 | | | $ | 1.58 | | | $ | (17.06) | |
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Financial Statements.
| | | | | |
Consolidated Statements of Comprehensive
Income (Loss) | Occidental Petroleum Corporation
and Subsidiaries |
| | | Years Ended December 31, | | Years Ended December 31, |
| millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Net income (loss) | Net income (loss) | | $ | (14,831) | | | $ | (522) | | | $ | 4,131 | | Net income (loss) | | $ | 13,304 | | | $ | 2,322 | | | $ | (14,831) | |
| Other comprehensive income (loss) items: | Other comprehensive income (loss) items: | | | | | | | Other comprehensive income (loss) items: | | | | | | |
| Losses on derivatives (a) | | (2) | | | (129) | | | (6) | | |
Gains on derivatives (a) | | Gains on derivatives (a) | | 80 | | | 14 | | | 4 | |
Pension and postretirement gains (losses) (b) | Pension and postretirement gains (losses) (b) | | (71) | | | 78 | | | 137 | | Pension and postretirement gains (losses) (b) | | 321 | | | 67 | | | (71) | |
Reclassification of realized losses on derivatives (c) | | 6 | | | 2 | | | 13 | | |
| Other | | Other | | 2 | | | (1) | | | — | |
| Other comprehensive income (loss), net of tax | Other comprehensive income (loss), net of tax | | (67) | | | (49) | | | 144 | | Other comprehensive income (loss), net of tax | | 403 | | | 80 | | | (67) | |
| Comprehensive income (loss) | Comprehensive income (loss) | | (14,898) | | | (571) | | | 4,275 | | Comprehensive income (loss) | | 13,707 | | | 2,402 | | | (14,898) | |
| Less: Comprehensive income attributable to noncontrolling interests | | 0 | | | (145) | | | 0 | | |
| | Comprehensive income (loss) attributable to preferred and common stockholders | Comprehensive income (loss) attributable to preferred and common stockholders | | $ | (14,898) | | | $ | (716) | | | $ | 4,275 | | Comprehensive income (loss) attributable to preferred and common stockholders | | $ | 13,707 | | | $ | 2,402 | | | $ | (14,898) | |
(a)Net of tax expense of $1, $36$(22), $(4) and $2$(1) in 2020, 20192022, 2021 and 2018,2020, respectively.
(b)Net of tax benefit (expense) of $(99), $(18) and $24 $(25)in 2022, 2021 and $(38) in 2020, 2019 and 2018, respectively. See Note 1511 - Retirement and Postretirement Benefit Plans in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K for additional information. (c)Net of tax of $(2), $0 and $(4) in 2020, 2019 and 2018, respectively.
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Financial Statements.
| | | | | |
| Consolidated Statements of Stockholders’ Equity | Occidental Petroleum Corporation
and Subsidiaries |
| | | Equity Attributable to Common Stock | | | Equity Attributable to Common Stock | | | |
| | Preferred Stock | | Common Stock | | Treasury Stock | | Additional Paid-in Capital | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss) | | Non-controlling Interests | | Total Equity | | Preferred Stock | | Common Stock | | Treasury Stock | | Additional Paid-in Capital | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss) | | | Total Equity |
| Balance, December 31, 2017 | | $ | 0 | | | $ | 179 | | | $ | (9,168) | | | $ | 7,884 | | | $ | 21,935 | | | $ | (258) | | | $ | 0 | | | $ | 20,572 | | |
| Net income | | — | | | — | | | — | | | — | | | 4,131 | | | — | | | — | | | 4,131 | | |
| Other comprehensive income, net of tax | | — | | | — | | | — | | | — | | | — | | | 144 | | | — | | | 144 | | |
| Dividends on common stock, $3.10 per share | | — | | | — | | | — | | | — | | | (2,374) | | | — | | | — | | | (2,374) | | |
| Issuance of common stock and other, net | | — | | | — | | | — | | | 162 | | | — | | | — | | | — | | | 162 | | |
| Purchases of treasury stock | | — | | | — | | | (1,305) | | | — | | | — | | | — | | | — | | | (1,305) | | |
| Reclassification of stranded tax effects | | — | | | — | | | — | | | — | | | 58 | | | (58) | | | — | | | 0 | | |
| Balance, December 31, 2018 | | $ | 0 | | | $ | 179 | | | $ | (10,473) | | | $ | 8,046 | | | $ | 23,750 | | | $ | (172) | | | $ | 0 | | | $ | 21,330 | | |
| Net income (loss) | | — | | | — | | | — | | | — | | | (667) | | | — | | | 145 | | | (522) | | |
| Other comprehensive loss, net of tax | | — | | | — | | | — | | | — | | | — | | | (49) | | | — | | | (49) | | |
| Dividends on common stock, $3.14 per share | | — | | | — | | | — | | | — | | | (2,585) | | | — | | | — | | | (2,585) | | |
| Dividends on preferred stock, $3,489 per share | | — | | | — | | | — | | | — | | | (318) | | | — | | | — | | | (318) | | |
| Issuance of common stock, net | | — | | | 30 | | | — | | | 6,909 | | | — | | | — | | | — | | | 6,939 | | |
| Issuance of preferred stock | | 9,762 | | | — | | | — | | | — | | | — | | | — | | | — | | | 9,762 | | |
| Purchases of treasury stock | | — | | | — | | | (180) | | | — | | | — | | | — | | | — | | | (180) | | |
| Fair value of noncontrolling interest acquired | | — | | | — | | | — | | | — | | | — | | | — | | | 4,895 | | | 4,895 | | |
| Noncontrolling interest distributions, net | | — | | | — | | | — | | | — | | | — | | | — | | | (131) | | | (131) | | |
| Change in control WES | | — | | | — | | | — | | | — | | | — | | | — | | | (4,909) | | | (4,909) | | |
| Balance, December 31, 2019 | Balance, December 31, 2019 | | $ | 9,762 | | | $ | 209 | | | $ | (10,653) | | | $ | 14,955 | | | $ | 20,180 | | | $ | (221) | | | $ | 0 | | | $ | 34,232 | | Balance, December 31, 2019 | | $ | 9,762 | | | $ | 209 | | | $ | (10,653) | | | $ | 14,955 | | | $ | 20,180 | | | $ | (221) | | | | $ | 34,232 | |
| Net loss | Net loss | | — | | | — | | | — | | | — | | | (14,831) | | | — | | | — | | | (14,831) | | Net loss | | — | | | — | | | — | | | — | | | (14,831) | | | — | | | | (14,831) | |
| Other comprehensive loss, net of tax | Other comprehensive loss, net of tax | | — | | | — | | | — | | | — | | | — | | | (67) | | | — | | | (67) | | Other comprehensive loss, net of tax | | — | | | — | | | — | | | — | | | — | | | (67) | | | | (67) | |
| Dividends on common stock, $0.82 per share | Dividends on common stock, $0.82 per share | | — | | | — | | | — | | | — | | | (746) | | | — | | | — | | | (746) | | Dividends on common stock, $0.82 per share | | — | | | — | | | — | | | — | | | (746) | | | — | | | | (746) | |
| Dividends on preferred stock, $8,444 per share | Dividends on preferred stock, $8,444 per share | | — | | | 6 | | | — | | | 438 | | | (844) | | | — | | | — | | | (400) | | Dividends on preferred stock, $8,444 per share | | — | | | 6 | | | — | | | 438 | | | (844) | | | — | | | | (400) | |
| Issuance of warrants on common stock | Issuance of warrants on common stock | | — | | | — | | | — | | | 767 | | | (763) | | | — | | | — | | | 4 | | Issuance of warrants on common stock | | — | | | — | | | — | | | 767 | | | (763) | | | — | | | | 4 | |
| | Berkshire Warrants | Berkshire Warrants | | — | | | — | | | — | | | 103 | | | — | | | — | | | — | | | 103 | | Berkshire Warrants | | — | | | — | | | — | | | 103 | | | — | | | — | | | | 103 | |
| Issuance of common stock and other, net | Issuance of common stock and other, net | | — | | | 1 | | | — | | | 289 | | | — | | | — | | | — | | | 290 | | Issuance of common stock and other, net | | — | | | 1 | | | — | | | 289 | | | — | | | — | | | | 290 | |
| Purchases of treasury stock | Purchases of treasury stock | | — | | | — | | | (12) | | | — | | | — | | | — | | | — | | | (12) | | Purchases of treasury stock | | — | | | — | | | (12) | | | — | | | — | | | — | | | | (12) | |
| | Balance, December 31, 2020 | Balance, December 31, 2020 | | $ | 9,762 | | | $ | 216 | | | $ | (10,665) | | | $ | 16,552 | | | $ | 2,996 | | | $ | (288) | | | $ | 0 | | | $ | 18,573 | | Balance, December 31, 2020 | | $ | 9,762 | | | $ | 216 | | | $ | (10,665) | | | $ | 16,552 | | | $ | 2,996 | | | $ | (288) | | | | $ | 18,573 | |
| Net income | | Net income | | — | | | — | | | — | | | — | | | 2,322 | | | — | | | | 2,322 | |
| Other comprehensive income, net of tax | | Other comprehensive income, net of tax | | — | | | — | | | — | | | — | | | — | | | 80 | | | | 80 | |
| Dividends on common stock, $0.04 per share | | Dividends on common stock, $0.04 per share | | — | | | — | | | — | | | — | | | (38) | | | — | | | | (38) | |
| Dividends on preferred stock, $8,000 per share | | Dividends on preferred stock, $8,000 per share | | — | | | — | | | — | | | — | | | (800) | | | — | | | | (800) | |
| Shareholder warrants exercised | | Shareholder warrants exercised | | — | | | — | | | — | | | 7 | | | — | | | — | | | | 7 | |
| | Issuance of common stock and other, net | | Issuance of common stock and other, net | | — | | | 1 | | | — | | | 190 | | | — | | | — | | | | 191 | |
| Purchases of treasury stock | | Purchases of treasury stock | | — | | | — | | | (8) | | | — | | | — | | | — | | | | (8) | |
| Balance, December 31, 2021 | | Balance, December 31, 2021 | | $ | 9,762 | | | $ | 217 | | | $ | (10,673) | | | $ | 16,749 | | | $ | 4,480 | | | $ | (208) | | | | $ | 20,327 | |
| Net income | | Net income | | — | | | — | | | — | | | — | | | 13,304 | | | — | | | | 13,304 | |
| Other comprehensive income, net of tax | | Other comprehensive income, net of tax | | — | | | — | | | — | | | — | | | — | | | 403 | | | | 403 | |
| Dividends on common stock, $0.52 per share | | Dividends on common stock, $0.52 per share | | — | | | — | | | — | | | — | | | (485) | | | — | | | | (485) | |
| Dividends on preferred stock, $8,000 per share | | Dividends on preferred stock, $8,000 per share | | — | | | — | | | — | | | — | | | (800) | | | — | | | | (800) | |
| Shareholder warrants exercised | | Shareholder warrants exercised | | — | | | 2 | | | — | | | 252 | | | — | | | — | | | | 254 | |
| Options Exercised | | Options Exercised | | — | | | — | | | — | | | 27 | | | — | | | — | | | | 27 | |
| Issuance of common stock and other, net | | Issuance of common stock and other, net | | — | | | 1 | | | — | | | 153 | | | — | | | — | | | | 154 | |
| Purchases of treasury stock | | Purchases of treasury stock | | — | | | — | | | (3,099) | | | — | | | — | | | — | | | | (3,099) | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | | $ | 9,762 | | | $ | 220 | | | $ | (13,772) | | | $ | 17,181 | | | $ | 16,499 | | | $ | 195 | | | | $ | 30,085 | |
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Financial Statements.
| | | | | |
| Consolidated Statements of Cash Flows | Occidental Petroleum Corporation
and Subsidiaries |
| | | | Years Ended December 31, | | | Years Ended December 31, |
| millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| CASH FLOW FROM OPERATING ACTIVITIES | CASH FLOW FROM OPERATING ACTIVITIES | | | CASH FLOW FROM OPERATING ACTIVITIES | | |
| Net income (loss) | Net income (loss) | | $ | (14,831) | | | $ | (522) | | | $ | 4,131 | | Net income (loss) | | $ | 13,304 | | | $ | 2,322 | | | $ | (14,831) | |
| Adjustments to reconcile net income (loss) to net cash from operating activities: | Adjustments to reconcile net income (loss) to net cash from operating activities: | | | Adjustments to reconcile net income (loss) to net cash from operating activities: | | |
| Discontinued operations, net | Discontinued operations, net | | 1,298 | | | 15 | | | 0 | | Discontinued operations, net | | — | | | 468 | | | 1,298 | |
| Depreciation, depletion and amortization of assets | Depreciation, depletion and amortization of assets | | 8,097 | | | 6,140 | | | 3,977 | | Depreciation, depletion and amortization of assets | | 6,926 | | | 8,447 | | | 8,097 | |
| Deferred income tax (benefit) provision | | (2,517) | | | (1,027) | | | 371 | | |
| Other noncash charges to income | | 419 | | | 958 | | | 34 | | |
| Deferred income tax provision (benefit) | | Deferred income tax provision (benefit) | | (1,644) | | | 46 | | | (2,517) | |
| Noncash charges (benefit) to income and other | | Noncash charges (benefit) to income and other | | (8) | | | 229 | | | 419 | |
| Asset impairments and other charges | Asset impairments and other charges | | 11,002 | | | 1,328 | | | 561 | | Asset impairments and other charges | | — | | | 304 | | | 11,002 | |
| (Gain) loss on sales of equity investments and other assets, net | (Gain) loss on sales of equity investments and other assets, net | | 1,666 | | | (622) | | | (974) | | (Gain) loss on sales of equity investments and other assets, net | | (308) | | | (192) | | | 1,666 | |
| Undistributed earnings from affiliates | Undistributed earnings from affiliates | | (61) | | | (50) | | | (43) | | Undistributed earnings from affiliates | | (219) | | | (70) | | | (61) | |
| Dry hole expense | Dry hole expense | | 47 | | | 89 | | | 56 | | Dry hole expense | | 84 | | | 125 | | | 47 | |
| Changes in operating assets and liabilities: | Changes in operating assets and liabilities: | | | Changes in operating assets and liabilities: | | | |
| Decrease in receivables | | 2,062 | | | 401 | | | 955 | | |
| (Increase) decrease in receivables | | (Increase) decrease in receivables | | (97) | | | (2,086) | | | 2,062 | |
| (Increase) decrease in inventories | (Increase) decrease in inventories | | (484) | | | 78 | | | (108) | | (Increase) decrease in inventories | | (230) | | | (86) | | | (484) | |
| Decrease in other current assets | | 350 | | | 170 | | | 94 | | |
| (Increase) decrease in other current assets | | (Increase) decrease in other current assets | | (335) | | | (119) | | | 350 | |
| Increase (decrease) in accounts payable and accrued liabilities | Increase (decrease) in accounts payable and accrued liabilities | | (3,228) | | | 358 | | | (1,500) | | Increase (decrease) in accounts payable and accrued liabilities | | (478) | | | 865 | | | (3,228) | |
| Increase in current domestic and foreign income taxes | | 22 | | | 20 | | | 38 | | |
| Other operating, net | | 0 | | | 0 | | | 77 | | |
| Increase (decrease) in current domestic and foreign income taxes | | Increase (decrease) in current domestic and foreign income taxes | | (185) | | | — | | | 22 | |
| Operating cash flow from continuing operations | Operating cash flow from continuing operations | | 3,842 | | | 7,336 | | | 7,669 | | Operating cash flow from continuing operations | | 16,810 | | | 10,253 | | | 3,842 | |
| Operating cash flow from discontinued operations, net of taxes | Operating cash flow from discontinued operations, net of taxes | | 113 | | | 39 | | | 0 | | Operating cash flow from discontinued operations, net of taxes | | — | | | 181 | | | 113 | |
| Net cash provided by operating activities | Net cash provided by operating activities | | 3,955 | | | 7,375 | | | 7,669 | | Net cash provided by operating activities | | 16,810 | | | 10,434 | | | 3,955 | |
| | CASH FLOW FROM INVESTING ACTIVITIES | CASH FLOW FROM INVESTING ACTIVITIES | | | CASH FLOW FROM INVESTING ACTIVITIES | | | |
| Capital expenditures | Capital expenditures | | (2,535) | | | (6,367) | | | (4,975) | | Capital expenditures | | (4,497) | | | (2,870) | | | (2,535) | |
| Change in capital accrual | Change in capital accrual | | (519) | | | (249) | | | 55 | | Change in capital accrual | | 147 | | | 97 | | | (519) | |
| Purchase of businesses and assets, net | | (114) | | | (28,088) | | | (928) | | |
| Purchase of businesses, assets and equity investments, net | | Purchase of businesses, assets and equity investments, net | | (990) | | | (431) | | | (114) | |
| Proceeds from sale of assets and equity investments, net | Proceeds from sale of assets and equity investments, net | | 2,281 | | | 6,143 | | | 2,824 | | Proceeds from sale of assets and equity investments, net | | 584 | | | 1,624 | | | 2,281 | |
| Equity investments and other, net | Equity investments and other, net | | 109 | | | (291) | | | (182) | | Equity investments and other, net | | (116) | | | 406 | | | 109 | |
| Investing cash flow from continuing operations | Investing cash flow from continuing operations | | (778) | | | (28,852) | | | (3,206) | | Investing cash flow from continuing operations | | (4,872) | | | (1,174) | | | (778) | |
| Investing cash flow from discontinued operations | Investing cash flow from discontinued operations | | (41) | | | (175) | | | 0 | | Investing cash flow from discontinued operations | | — | | | (79) | | | (41) | |
| Net cash used by investing activities | Net cash used by investing activities | | (819) | | | (29,027) | | | (3,206) | | Net cash used by investing activities | | (4,872) | | | (1,253) | | | (819) | |
| | CASH FLOW FROM FINANCING ACTIVITIES | CASH FLOW FROM FINANCING ACTIVITIES | | | CASH FLOW FROM FINANCING ACTIVITIES | | | |
| Proceeds from long-term debt, net - Occidental | | 6,936 | | | 21,557 | | | 978 | | |
| Payments of long-term debt, net - Occidental | | (8,916) | | | (6,959) | | | (500) | | |
| Proceeds from long-term debt, net - WES | | 0 | | | 459 | | | 0 | | |
| Proceeds from issuance of common and preferred stock | | 134 | | | 10,028 | | | 33 | | |
| Draws on receivables securitization facility | | Draws on receivables securitization facility | | 400 | | | — | | | — | |
| Payment of receivables securitization facility | | Payment of receivables securitization facility | | (400) | | | — | | | — | |
| Proceeds from long-term debt, net | | Proceeds from long-term debt, net | | — | | | — | | | 6,936 | |
| Payments of long-term debt, net | | Payments of long-term debt, net | | (9,484) | | | (6,834) | | | (8,916) | |
| | Proceeds from issuance of common stock | | Proceeds from issuance of common stock | | 293 | | | 31 | | | 134 | |
| Purchases of treasury stock | Purchases of treasury stock | | (12) | | | (237) | | | (1,248) | | Purchases of treasury stock | | (3,099) | | | (8) | | | (12) | |
| Cash dividends paid on common and preferred stock | Cash dividends paid on common and preferred stock | | (1,845) | | | (2,624) | | | (2,374) | | Cash dividends paid on common and preferred stock | | (1,184) | | | (839) | | | (1,845) | |
| Distributions to noncontrolling interest | | 0 | | | (257) | | | 0 | | |
| | Payment of liabilities associated with the sale of future royalties | Payment of liabilities associated with the sale of future royalties | | (386) | | | (28) | | | 0 | | Payment of liabilities associated with the sale of future royalties | | — | | | — | | | (386) | |
| Financing portion of net cash paid for derivative instruments | | Financing portion of net cash paid for derivative instruments | | (111) | | | (834) | | | (362) | |
| Other financing, net | Other financing, net | | (419) | | | 257 | | | 9 | | Other financing, net | | (130) | | | (80) | | | (57) | |
| Financing cash flow from continuing operations | Financing cash flow from continuing operations | | (4,508) | | | 22,196 | | | (3,102) | | Financing cash flow from continuing operations | | (13,715) | | | (8,564) | | | (4,508) | |
| Financing cash flow from discontinued operations | Financing cash flow from discontinued operations | | (8) | | | (3) | | | 0 | | Financing cash flow from discontinued operations | | — | | | (8) | | | (8) | |
| Net cash provided (used) by financing activities | | (4,516) | | | 22,193 | | | (3,102) | | |
| Net cash used by financing activities | | Net cash used by financing activities | | (13,715) | | | (8,572) | | | (4,516) | |
| | Increase (decrease) in cash, cash equivalents, restricted cash and restricted cash equivalents | Increase (decrease) in cash, cash equivalents, restricted cash and restricted cash equivalents | | (1,380) | | | 541 | | | 1,361 | | Increase (decrease) in cash, cash equivalents, restricted cash and restricted cash equivalents | | (1,777) | | | 609 | | | (1,380) | |
| Cash, cash equivalents, restricted cash and restricted cash equivalents — beginning of year | Cash, cash equivalents, restricted cash and restricted cash equivalents — beginning of year | | 3,574 | | | 3,033 | | | 1,672 | | Cash, cash equivalents, restricted cash and restricted cash equivalents — beginning of year | | 2,803 | | | 2,194 | | | 3,574 | |
| Cash, cash equivalents, restricted cash and restricted cash equivalents — end of year | Cash, cash equivalents, restricted cash and restricted cash equivalents — end of year | | $ | 2,194 | | | $ | 3,574 | | | $ | 3,033 | | Cash, cash equivalents, restricted cash and restricted cash equivalents — end of year | | $ | 1,026 | | | $ | 2,803 | | | $ | 2,194 | |
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Financial Statements.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
| | | | | |
| Notes to Consolidated Financial Statements | Occidental Petroleum Corporation
and Subsidiaries |
| | |
| NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES |
NATURE OF OPERATIONS
In this report, “Occidental” means Occidental Petroleum Corporation, a Delaware corporation (OPC), or OPC and one or more entities in which it owns a controlling interest (subsidiaries). Occidental conducts its operations through various subsidiaries and affiliates. On August 8, 2019, pursuant to the Agreement and Plan of Merger dated as of May 9, 2019 (the Merger Agreement), among Occidental, Baseball Merger Sub 1, Inc., a Delaware corporation and an indirect, wholly owned subsidiary of Occidental (Merger Subsidiary), and Anadarko Petroleum Corporation (Anadarko), Occidental acquired all of the outstanding shares of Anadarko through a transaction in which Merger Subsidiary merged with and into Anadarko (the Acquisition), with Anadarko continuing as the surviving entity and as an indirect, wholly owned subsidiary of Occidental. See Note 3 - The Acquisition for further information.Occidental’s principal businesses consist of 3three reporting segments: oil and gas, chemical and midstream and marketing. The oil and gas segment explores for, develops and produces oil and condensate, natural gas liquids (NGL)(which includes condensate), NGL and natural gas. The chemical segment (OxyChem) mainlyOxyChem primarily manufactures and markets basic chemicals and vinyls. The midstream and marketing segment purchases, markets, gathers, processes, transports and stores oil condensate,(which includes condensate), NGL, natural gas, CO2 and power. It also trades aroundoptimizes its assets, including transportation and storage capacity, and invests in entities that conduct similar activities, such as Western Midstream Partners, L.P. (WES). WES.
The midstream and marketing segment also includes Oxy Low Carbon Ventures (OLCV).OLCV. OLCV seeks to leverage Occidental’s legacy of carbon management expertise that is derived from its enhanced oil recovery (EOR) operations to develop carbon capture, utilizationCCUS projects, including the commercialization of DAC technology, and storage facilities that are expectedinvests in other low-carbon technologies intended to source anthropogenic CO2reduce GHG emissions from our operations and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducingstrategically partner with other industries to help reduce their emissions.
PRINCIPLES OF CONSOLIDATION
The consolidated financial statementsConsolidated Financial Statements have been prepared in conformity with United States Generally Accepted Accounting Principles (GAAP)GAAP and include the accounts of OPC,Occidental, its subsidiaries, its undivided interests in oil and gas exploration and production ventures and, previously, variable interest entities, (VIE) for which Occidental was the primary beneficiary. Occidental accounts for its share of oil and gas exploration and production ventures, in which it has a direct working interest, by reporting its proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on the balance sheets, statements of operations and statements of cash flows.
The Acquisition introduced different revenue and expense streams to Occidental’s legacy operations. As a result, changes were made to the structure of certain financial statements, notes and supplementary data to provide clarity. In addition, certain Certain prior period amounts have been reclassified to conform to the current presentation.
WES INVESTMENT
WES is a publicly traded limited partnership with its common units traded on the New York Stock Exchange (NYSE) under the ticker symbol “WES.” WES owns the entire non-economic general partner interest and a 98% limited partner interest in Western Midstream Operating, LP (WES Operating), a Delaware limited partnership formed by Anadarko in 2007 to acquire, own, develop and operate midstream assets.
From the Acquisition date through December 31, 2019, WES was determined to be a VIE, and Occidental, through its ownership of the general partner interest in WES, had the power to direct the activities that significantly affected the economic performance of WES and the obligation to absorb losses or the right to receive benefits that could be significant to WES. As such, Occidental was considered the primary beneficiary and consolidated WES and its consolidated subsidiaries from the date of the Acquisition to December 31, 2019. All intercompany transactions were eliminated during the consolidated period. Revenues of $1.1 billion, cost of sales of $500 million and operating cash flows of $498 million from the date of the Acquisition to December 31, 2019 are attributable to WES and are included in Occidental’s consolidated financial statements. Net income from noncontrolling interest for the same period relates to the 44.6% limited partner interest of WES owned by the public.
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On December 31, 2019, Occidental and WES executed several agreements to allow WES to operate as an independent midstream company to support its ongoing pursuit of third-party growth opportunities. The executed agreements include amendments to the partnership agreement that significantly expand the unaffiliated limited partner unitholders’ rights. The significant amendments to the partnership agreement included:
■Providing for a simple majority of the unaffiliated unitholders to remove and elect a new general partner;
■Allowing for 20% of the unaffiliated unitholders to call a special meeting to vote to remove the general partner;
■Eliminating ownership thresholds that could have prevented unaffiliated unitholders from voting;
■Limiting Occidental’s voting percentage to 45% for certain unitholder matters until Occidental owns less than 40% of the limited partner units for twelve consecutive months; and
■Transferring 2% of Occidental’s limited partner interest to the general partner to provide a 2% economic interest to the general partner.
In addition to the partnership agreement amendments, in December 2019, the WES management team’s employment was transferred from Occidental to WES, and WES-dedicated personnel were seconded to WES from Occidental. The seconded employees’ employment was contractually obligated to be transferred to WES during 2020 once employee benefit plans were established. As of December 31, 2020, there were no seconded employees remaining for WES. Additionally, as of December 31, 2019, Occidental employees no longer comprise a majority of the board of directors of WES’ general partner.
As a result of the 2019 partnership agreement amendments and other related agreements, WES no longer met the criteria to be considered a VIE. Accordingly, Occidental evaluated WES under the voting interest model and determined, because Occidental did not control the power to appoint or remove a successor general partner, it should no longer consolidate WES. Occidental recognized, at fair value, an equity method investment of $5.1 billion based on the closing market price of WES as of December 31, 2019 and recognized a loss of approximately $1 billion that was included in asset impairments and other charges on the Statement of Operations for the year ended December 31, 2019.
In the first quarter 2020, Occidental recorded a loss from an equity investment of $236 million primarily as a result of WES’ write-off of its goodwill. At the end of the third quarter 2020, Occidental recorded an other-than-temporary impairment of $2.7 billion, see Note 17 - Fair Value Measurements for a description of the inputs and assumptions utilized.In addition, Occidental recorded a loss of $46 million as a result of a non-cash transaction with WES in which Occidental exchanged approximately 27.9 million of its WES common units to retire a $260 million note payable to WES, see Note 7 - Long-Term Debt.As of December 31, 2020, Occidental’s equity method investment in WES was $1.9 billion, which exceeds Occidental’s pro-rata interest in the net assets of WES by $437 million. This basis difference is primarily associated with WES' property, plant and equipment and equity investments and is subject to amortization over their estimated average lives. Subsequent to the other-than-temporary impairment there was no equity method goodwill associated with the WES equity investment. As of December 31, 2020, Occidental has a 2% non-voting general partner interest and a 51.8% limited partner interest in WES and a 2% non-voting limited partner interest in WES Operating, a subsidiary of WES. On a combined basis, Occidental's total effective economic interest in WES and its subsidiaries is 53.5%. Occidental intends to reduce its limited partner ownership interest in WES to below 50%.
INVESTMENTS IN UNCONSOLIDATED ENTITIES
Occidental’s percentage interest in the underlying net assets of affiliates for which it exercises significant influence without having a controlling interest (excluding oil and gas ventures in which Occidental holds an undivided interest) are accounted for under the equity method. Occidental reviews equity-method investments for impairment whenever events or changes in circumstances indicate that an other-than-temporary decline in value may have occurred. The amount of impairment, if any, is based on quoted market prices, when available, or other valuation techniques, including discounted cash flows. Occidental evaluates the facts and circumstances of any distributions in excess of its carrying amount in the investment to determine the appropriate accounting, including the source of the proceeds and any implicit or explicit commitments to fund the affiliate. If there is no implicit or explicit commitment the distribution is treated as a gain. If an implicit or explicit commitment exists to possibly fund the affiliate at a future date the distribution is recorded against the equity-method investment. See Note16 4 - InvestmentsInvestments and Related-Party TransactionsRelated-Party Transactions for further discussion regarding investments in unconsolidated entities.
DISCONTINUED OPERATIONSWES INVESTMENT
WES is a publicly traded limited partnership with its common units traded on the NYSE under the ticker symbol “WES.” WES owns the entire non-economic general partner interest and a 98% limited partner interest in WES Operating.
In connection with the Acquisition,July 2022, Occidental entered intosold 10.0 million limited partner units of WES for proceeds of approximately $250 million, resulting in a purchase and sale agreement with TOTAL S.A. (Total) to sellgain of $62 million.
As of December 31, 2022, Occidental owned all of the assets, liabilities, businesses2.3% non-voting general partner interest and operations of Anadarko's operations in Algeria, Ghana, Mozambique and South Africa. Total and Occidental completed the sale49.5% of the Mozambiquelimited partner units in WES. On a combined basis, with its 2% non-voting limited partner interest in WES Operating, Occidental's total effective economic interest in WES and its subsidiaries was 51.7% and Occidental’s carrying value of WES was approximately $2.0 billion, which exceeds Occidental’s pro-rata interest in the net assets in September 2019 for approximately $4.2 billionof WES by $390 million. This basis difference is primarily associated with WES' PP&E and the South Africa assets in January 2020 for approximately $100 million.
In April 2020, subsequentequity investments and is subject to communications with Algerian government officials, Occidental determined that the sale of the Algeria operations to Total would not be consummated and the decision was made to continue to operate within Algeria. As a result, as of the second quarter of 2020, Occidental no longer classified the Algeria operations as a held for sale asset in discontinued operations and reclassified prior periods to reflect the Algeria operations as continuing operations, seeamortization over their estimated average lives. See Note 4 - DivestituresInvestment and OtherRelated-Party Transactions for the impact on prior periods. In addition, in the second quarter 2020, Occidental recorded a $931 million impairment to remeasure the Algeria oil and gas properties to their fair value, which was lower than the carrying amount as if DD&A were recorded from the date of the Acquisition. The fair value of the oil and gas properties
BERKSHIRE HATHAWAY OWNERSHIP
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In May 2020, Occidental and Total mutually agreed to execute a waiver of the obligation to purchase and sell the Ghana assets, so that Occidental could begin marketing the sale of the Ghana assets to other third parties. Occidental is currently marketing the Ghana assets. The assets and liabilities for Ghana remain presented as held for sale at December 31, 2020. Occidental recorded an after-tax impairment of $1.4 billion in the second quarter 2020 to reflect the held for sale assets at their fair value less costs to sell based on the income approach, refer to Note 17 - Fair Value Measurements. The results of operations of Ghana continue to be presented as discontinued operations, see Note 4 - Divestitures and Other Transactions.DISCONTINUED OPERATIONSUnless otherwise indicated, information presented in the Notes to the Consolidated Financial Statements relates only to Occidental's continuing operations. Information related to discontinued operations is included in Note 45 - Acquisitions, Divestitures and Other Transactions and in some instances, where appropriate, is included as a separate disclosure within the individual Notes to the Consolidated Financial Statements.
RISKS AND UNCERTAINTIES
The process of preparing consolidated financial statementsConsolidated Financial Statements in conformity with GAAP requires Occidental’s management to make informed estimates and judgments regarding certain types of financial statement balances and disclosures. Such estimates primarily relate to unsettled transactions and events as of the date of the consolidated financial statementsConsolidated Financial Statements and judgments on expected outcomes as well as the materiality of transactions and balances. Changes in facts and circumstances or discovery of new information relating to such transactions and events may result in revised estimates and judgments and actual results may differ from estimates upon settlement. Management believes that these estimates and judgments provide a reasonable basis for the fair presentation of Occidental’s financial statements. Occidental establishes a valuation allowance against net operating losses and other deferred tax assets to the extent it believes the future benefit from these assets will not be realized in the statutory carryforward periods. Realization of deferred tax assets is dependent upon Occidental generating sufficient future taxable income and reversal of temporary differences in jurisdictions where such assets originate.
The accompanying consolidated financial statementsConsolidated Financial Statements include assets of approximately $9.5$7.7 billion as of December 31, 20202022 and net sales of approximately $3.4$5.5 billion for the year ended December 31, 2020,2022, relating to Occidental’s operations in countries outside North America. Occidental operates somehas experienced and may continue to experience adverse consequences, such as risk of loss or production limitations, because certain of its oil and gas businessinternational operations are located in countries that have experiencedaffected by political instability, nationalizations, corruption, armed conflict, terrorism, insurgency, civil unrest, security problems, labor unrest, OPEC production restrictions, equipment import restrictions and sanctions, allsanctions. Exposure to such risks may increase if a greater percentage of which increase Occidental’s risk of loss, delayed or restrictedfuture oil and gas production or may result in other adverse consequences.revenue comes from international sources. Occidental attempts to conduct its affairs so as to mitigate its exposure to such risks and would seek compensation in the event of nationalization.
Because Occidental’s major products are commodities, significant changes in the prices of oil, NGL, natural gas and chemical products may have a significant impact on Occidental’s results of operations. Also, see Property, Plant and Equipment section below.
RECEIVABLES AND OTHER CURRENT ASSETS
Trade receivables, net of $2.1$4.3 billion and $4.2 billion atas of December 31, 2020,2022 and 2019,2021, respectively, represent rights to payment for which Occidental hashad satisfied its obligations under a contract with a customer and its right to payment iswas conditioned only on the passage of time.
Other current assets includes amounts receivable from working interest partners in Occidental’s oil and gas operations, derivative assets and taxes receivable.
INVENTORIES
Materials and supplies are valued at weighted-average cost and are reviewed periodically for obsolescence. Oil, NGL and natural gas inventories are valued at the lower of cost or market.
For the chemical segment, Occidental’s finished goods inventories are valued at the lower of cost or market. For most of its domestic inventories, other than materials and supplies, the chemical segment uses the last-in, first-out (LIFO)LIFO method as it better matches current costs and current revenue. For other countries, Occidental uses the first-in, first-out method (if the costs of goods are specifically identifiable) or the average-cost method (if the costs of goods are not specifically identifiable).
PROPERTY, PLANT AND EQUIPMENT
OIL AND GAS
The carrying value of Occidental’s property, plant and equipment (PP&E)PP&E represents the cost incurred to acquire or develop the asset, including any asset retirement obligationsAROs and capitalized interest, net of accumulated DD&A and any impairment charges. For assets acquired, PP&E cost is based on fair values at the acquisition date. Asset retirement obligationsAROs and interest costs incurred in connection with qualifying capital expenditures are capitalized and amortized over the lives of the related assets.
Occidental uses the successful efforts method to account for its oil and gas properties. Under this method, Occidental capitalizes costs of acquiring properties, costs of drilling successful exploration wells and development costs. The costs of
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exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. If proved reserves have been found, the costs of exploratory wells remain capitalized. For exploratory wells that find reserves that cannot be classified as proved when drilling is completed, costs continue to be capitalized as suspended exploratory drilling costs if there have been sufficient reserves found to justify completion as a producing well and sufficient progress is being made in assessing the reserves and the economic and operating viability of the project. At the end of each quarter, management reviews the status of all suspended exploratory drilling costs in light of ongoing exploration activities, in
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particular, whether Occidental is making sufficient progress in its ongoing exploration and appraisal efforts or, in the case of discoveries requiring government sanctioning, analyzing whether development negotiations are underway and proceeding as planned. If management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed.
The following table summarizes the activity of capitalized exploratory well costs for continuing operations for the years ended December 31:
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Balance — beginning of year | Balance — beginning of year | | $ | 424 | | | $ | 112 | | | $ | 108 | | Balance — beginning of year | | $ | 213 | | | $ | 211 | | | $ | 424 | |
| Exploratory well costs acquired through the Acquisition | | 0 | | | 231 | | | 0 | | |
| Additions to capitalized exploratory well costs pending the determination of proved reserves | Additions to capitalized exploratory well costs pending the determination of proved reserves | | 122 | | | 383 | | | 220 | | Additions to capitalized exploratory well costs pending the determination of proved reserves | | 323 | | | 163 | | | 122 | |
| Reclassifications to property, plant and equipment based on the determination of proved reserves | Reclassifications to property, plant and equipment based on the determination of proved reserves | | (309) | | | (230) | | | (198) | | Reclassifications to property, plant and equipment based on the determination of proved reserves | | (183) | | | (67) | | | (309) | |
| Capitalized exploratory well costs charged to expense | Capitalized exploratory well costs charged to expense | | (26) | | | (72) | | | (18) | | Capitalized exploratory well costs charged to expense | | (77) | | | (94) | | | (26) | |
| Balance — end of year | Balance — end of year | | $ | 211 | | | $ | 424 | | | $ | 112 | | Balance — end of year | | $ | 276 | | | $ | 213 | | | $ | 211 | |
Occidental expenses annual lease rentals, the costs of injectants used in production and geological and geophysical costs as incurred.
Occidental determines depreciation and depletion of oil and gas producing properties by the unit-of-production method. It amortizes leasehold costs over total proved reserves and capitalized development and successful exploration costs over proved developed reserves.
Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Proved reserves includes proved undevelopedinclude PUD reserves. Proved undevelopedPUD reserves are supported by a management approved,management-approved, detailed, field-level development plan where sufficient capital has been committed to develop those reserves. A majorityOnly PUD reserves which are reasonably certain to be drilled within five years of the proved undeveloped reservesbooking and are supported by a five-year,final investment decision to drill them are included in the development plan while certainplan. A portion of the PUD reserves associated with international proved undeveloped reservesoperations are associated withexpected to be developed beyond the five years and are tied to approved long-term development plans.projects.
Occidental performs impairment tests with respect to its proved properties whenever events or circumstances indicate that the carrying value of property may not be recoverable. If there is an indication the carrying amount of the asset may not be recovered due to significant and prolonged declines in current and forward prices, significant changes in reserve estimates, changes in management’s plans, or other significant events, management will evaluate the property for impairment. Under the successful efforts method, if the sum of the undiscounted cash flows is less than the carrying value of the proved property, the carrying value is reduced to estimated fair value and reported as an impairment charge in the period. Individual proved properties are grouped for impairment purposes at the lowest level for which there are identifiable cash flows.flows unless observable and comparable transactions are available. The fair value of impaired assets is typically determined based on the present value of expected future cash flows using discount rates believed to be consistent with those used by market participants. The impairment test incorporates a number of assumptions involving expectations of future cash flows which can change significantly over time. These assumptions include future production and timing of production, estimates of future production, product prices, contractual prices, estimates of risk-adjusted oil and gas proved and unproved reserves and estimates of future operating and development costs. It is reasonably possible that prolonged declines in commodity prices, reduced capital spending in response to lower prices or increases in operating costs could result in additional impairments. See Note 179 - Fair Value Measurements and below for further discussion of asset impairments. Net capitalized costs attributable to unproved properties were $18.6$12.6 billion atas of December 31, 20202022 and $29.5$14.8 billion atas of December 31, 2019.2021. The unproved amounts are not subject to DD&A until they are classified as proved properties. Individually insignificant unproved properties are combined and amortized on a group basis based on factors such as lease terms, success rates and other factors to provide for full amortization upon lease expiration or abandonment.
Significant unproved properties, primarily as a result of the Anadarko Acquisition, are assessed individually for impairment and when events or circumstances indicate that the carrying value of property may not be recovered a valuation allowance is provided if an impairment is indicated. Occidental periodically reviews significant unproved properties for impairments; numerous factors are considered, including but not limited to, availability of funds for future exploration and development activities, current exploration and development plans, favorable or unfavorable exploration activity on the property or the adjacent property, geologists’ evaluation of the property, the current and projected political and regulatory climate,
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contractual conditions and the remaining lease term for the properties. If an impairment is indicated, Occidental will first determine whether a comparable transaction for similar properties or implied acreage valuation derived from domestic onshore market participants is available and will adjust the carrying amount of the unproved property to its fair value using the market approach. In situations where the market approach is not observable and unproved reserves are available,
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undiscounted future net cash flows used in the impairment analysis are determined based on managements’ risk adjusted estimates of unproved reserves, future commodity prices and future costs to produce the reserves. If undiscounted future net cash flows are less than the carrying value of the property, the future net cash flows are discounted and compared to the carrying value for determining the amount of the impairment loss to record. Occidental utilizes the same assumptions and methodology discussed above for cash flows associated with proved properties.
CHEMICAL
Occidental’s chemical assets are depreciated using either the unit-of-production or the straight-line method, based upon the estimated useful lives of the facilities. The estimated useful lives of Occidental’s chemical assets, which range from three years to 50 years, are also used for impairment tests. The estimated useful lives for the chemical facilities are based on the assumption that Occidental will provide an appropriate level of annual expenditures to ensure productive capacity is sustained. Such expenditures consist of ongoing routine repairs and maintenance, as well as planned major maintenance activities (PMMA).activities. Ongoing routine repairs and maintenance expenditures are expensed as incurred. PMMAPlanned major maintenance activities costs are capitalized and amortized over the period until the next planned overhaul. Additionally, Occidental incurs capital expenditures that extend the remaining useful lives of existing assets, increase their capacity or operating efficiency beyond the original specification or add value through modification for a different use. These capital expenditures are not considered in the initial determination of the useful lives of these assets at the time they are placed into service. The resulting revision, if any, of the asset’s estimated useful life is measured and accounted for prospectively.
Without these continued expenditures, the useful lives of these assets could decrease significantly. Other factors that could change the estimated useful lives of Occidental’s chemical assets include sustained higher or lower product prices, which are affected by domestic and international competition, demand, feedstock costs, energy prices, environmental regulations and technological changes.
Occidental performs impairment tests on its chemical assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets. Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
MIDSTREAM AND MARKETING
Occidental’s midstream and marketing PP&E is depreciated over the estimated useful lives of the assets, using either the unit-of-production or straight-line method.
Occidental performs impairment tests on its midstream and marketing assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets. Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
GOODWILLIMPAIRMENTS AND OTHER CHARGES
AsDuring 2021, Occidental’s oil and gas segment recognized pre-tax impairment and related charges of December 31, 2019,$282 million primarily related to undeveloped leases that either expired or were set to expire in the near-term, where Occidental had $1.2no plans to pursue exploration activities and, to a lesser extent, impairments of oil and gas materials and supplies inventories.
During 2020, Occidental’s oil and gas segment recognized pre-tax impairment and related charges of $7.0 billion of goodwill related to its ownership in WES, whichproved and unproved properties. An additional pre-tax impairment of $2.2 billion related to Ghana was included in long-term receivablesdiscontinued operations.
During 2020, Occidental’s midstream and other assets, net.marketing segment recognized pre-tax impairment and related charges of $1.2 billion related to goodwill associated with Occidental’s ownership in WES. Significant declines in the market value of WES’ publicly traded units resulted in management’s determination that, more likely than not, the fair value of the reporting unit was significantly less than its carrying value and the entire $1.2 billion in goodwillbalance was fully impaired in the first quarter of 2020.impaired. The market value of WES’ publicly traded units is considered a Level 1 input.
IMPAIRMENTS AND OTHER CHARGES
During 2020, Occidental’s oil and gas segment recognized pre-tax impairment and related charges of $7.0 billion relating to proved and unproved properties. An additional pre-tax impairment of $2.2 billion related to Ghana is included in discontinued operations.
During 2019, Occidental’s oil and gas segment recognized pre-tax impairment and related charges of $285 million related to domestic undeveloped leases that were set to expire in the near-term, where Occidental had no plans to pursue exploration activities, and $39 million related to Occidental’s mutually agreed early termination of its Qatar Idd El Shargi South Dome (ISSD) contract.
In 2018, Occidental recognized pre-tax impairment and related charges of $416 million related to Qatar Idd El Shargi North Dome (ISND) and ISSD proved properties and inventory. Also in 2018, the midstream and marketing segment incurred approximately $100 million of charges primarily for lower of cost or market adjustments on its crude inventory and line fill.
It is reasonably possible that prolongedProlonged declines in commodity prices, reduced capital spending in response to lower prices or increases in operating costs could result in additional impairments.
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FAIR VALUE MEASUREMENTS
Occidental has categorized its assets and liabilities that are measured at fair value in a three-level fair value hierarchy, based on the inputs to the valuation techniques: Level 1 – using quoted prices in active markets for the assets or liabilities; Level 2 – using observable inputs other than quoted prices for the assets or liabilities; and Level 3 – using unobservable inputs. Transfers between levels, if any, are reported at the end of each reporting period.
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FAIR VALUES - RECURRING
Occidental primarily applies the market approach for recurring fair value measurements, maximizes its use of observable inputs and minimizes its use of unobservable inputs. Occidental utilizes the mid-point between bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value. In addition to using market data, Occidental makes assumptions in valuing its assets and liabilities, including assumptions about the risks inherent in the inputs to the valuation technique. For assets and liabilities carried at fair value, Occidental measures fair value using the following methods:
■Occidental values exchange-cleared commodity derivatives using closing prices provided by the exchange as of the balance sheet date. These derivatives are classified as Level 1.
■OTC bilateral financial commodity contracts, foreign exchange contracts, interest rate swaps, warrants, options and physical commodity forward purchase and sale contracts are generally classified as Level 2 and are generally valued using quotations provided by brokers or industry-standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility factors, credit risk and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument, and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace.
■Occidental values commodity derivatives based on a market approach that considers various assumptions, including quoted forward commodity prices and market yield curves. The assumptions used include inputs that are generally unobservable in the marketplace or are observable but have been adjusted based upon various assumptions and the fair value is designated as Level 3 within the valuation hierarchy.
■Occidental values debt using market-observable information for debt instruments that are traded on secondary markets. For debt instruments that are not traded, the fair value is determined by interpolating the value based on debt with similar terms and credit risk.
NON-FINANCIAL ASSETS
Occidental uses market-observable prices for assets when comparable transactions can be identified that are similar to the asset being valued. When Occidental is required to measure fair value and there is not a market-observable price for the asset or for a similar asset then the cost or income approach is used depending on the quality of information available to support management’s assumptions. The cost approach is based on management’s best estimate of the current asset replacement cost. The income approach is based on management’s best assumptions regarding expectations of future net cash flows. The expected cash flows are discounted using a commensurate risk-adjusted discount rate. Such evaluations involve significant judgment, and the results are based on expected future events or conditions such as sales prices, estimates of future oil and gas production or throughput, development and operating costs and the timing thereof, economic and regulatory climates and other factors, most of which are often outside of management’s control. However, assumptions used reflect a market participant’s view of long-term prices, costs and other factors and are consistent with assumptions used in Occidental’s business plans and investment decisions.
ACCRUED LIABILITIES - CURRENT
Accrued liabilities - current included accrued payroll, commissions and related expenses of $461$582 million and $1.2 billion at$677 million as of December 31, 2020,2022 and 2019,2021, respectively, and taxes other than on income of $544 million and $445 million as of December 31, 2022 and 2021, respectively. Dividends payable, also included in accrued liabilities - current, were $189$289 million and $884$188 million atas of December 31, 2020,2022, and 2019,2021, respectively. Derivative financial instruments, also included in accrued liabilities - current, were $1.1 billion and $641 million at December 31, 2020, and 2019, respectively.
ENVIRONMENTAL LIABILITIES AND EXPENDITURES
EnvironmentalCertain subsidiaries of Occidental incur environmental liabilities and expenditures that relate to current operations and are expensed or capitalized by such subsidiaries as appropriate. Occidental recordsCertain subsidiaries also incur environmental liabilities and expenditures with respect to remediation of existing conditions from alleged past practices at Currently Operated, Closed or Non-Operated, and Third-Party Sites, which categories may include NPL sites. Those environmental liabilities and related charges and expenses for estimated remediation costs that relate to existing conditions from past operations are recorded when environmental remediation efforts are probable and the costs can be reasonably estimated. Occidental discloses such remediation liabilities on a consolidated basis. In determining the environmental remediation liability and the range of reasonably possible additional losses, Occidental refers to currently available information, including relevant past experience, remedial objectives, available technologies, applicable laws and regulations and cost-sharing arrangements. Occidental bases itsThese environmental remediation liabilities are based on management’s estimate of the most likely cost to be incurred, using the most cost-effective technology reasonably expected to achieve the remedial objective. Occidental periodically reviews itsthese environmental remediation liabilities and adjusts them as new information becomes available. Occidental records environmental remediation liabilities on a discounted basis when it deems the aggregate amount and timing of cash payments to be reliably
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determinable at the time the reserves are established. The reserve methodology with respect to discounting for a specific site is not modified once it is established. Presently none of its environmental remediation liabilities are recorded on a discounted basis. OccidentalOccidental’s subsidiaries generally recordsrecord reimbursements or recoveries of environmental remediation costs in income when received, or when receipt of recovery is highly probable.
Many factors could affect Occidental’s future remediation costs incurred by Occidental’s subsidiaries and result in adjustments to its environmental remediation liabilities and the range of reasonably possible additional losses. The most significant are: (1)
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cost estimates for remedial activities may vary from the initial estimate; (2) the length of time, type or amount of remediation necessary to achieve the remedial objective may change due to factors such as site conditions, the ability to identify and control contaminant sources or the discovery of additional contamination; (3) a regulatory agency may ultimately reject or modify Occidental’s proposed remedial plan; (4) improved or alternative remediation technologies may change remediation costs; (5) laws and regulations may change remediation requirements or affect cost sharing or allocation of liability; and (6) changes in allocation or cost-sharing arrangements may occur.
Certain sites involve multiple parties with various cost-sharing arrangements, which fall into the following three categories: (1) environmental proceedings that result in a negotiated or prescribed allocation of remediation costs among the affected Occidental subsidiary and other alleged potentially responsible parties; (2) oil and gas ventures in which each participant pays its proportionate share of remediation costs reflecting its working interest; or (3) contractual arrangements, typically relating to purchases and sales of properties, in which the parties to the transaction agree to methods of allocating remediation costs. In these circumstances, Occidentalthe affected subsidiary evaluates the financial viability of other parties with whom it is alleged to be jointly liable, the degree of their commitment to participate and the consequences to Occidentalsuch subsidiary of their failure to participate when estimating Occidental’sits ultimate share of liability. Occidental records its environmental remediation liabilities at its expected net cost of remedial activities and, based on these factors, believes that it will not be required to assume a share of liability of such other potentially responsible parties in an amount materially above amounts reserved.
In addition to the costs of investigations and cleanupclean-up measures, which often take in excess of 10 years at CERCLA NPL sites, Occidental’s environmental remediation liabilities include management’s estimates of the costs to operate and maintain remedial systems. If remedial systems are modified over time in response to significant changes in site-specific data, laws, regulations, technologies or engineering estimates, Occidental reviews and adjusts its environmental remediation liabilities accordingly.
ASSET RETIREMENT OBLIGATIONS
Occidental recognizes the fair value of asset retirement obligationsAROs in the period in which a determination is made that a legal obligation exists to dismantle an asset and reclaim or remediate the property at the end of its useful life and the cost of the obligation can be reasonably estimated. The liability amounts are based on future retirement cost estimates and incorporate many assumptions such as time to abandonment, future inflation rates and the risk-adjusted discount rate. When the liability is initially recorded, Occidental capitalizes the cost by increasing the related PP&E balances. If the estimated future cost of the asset retirement obligationsAROs changes, Occidental records an adjustment to both the asset retirement obligationsAROs and PP&E. Over time, the liability is increased, and expense is recognized for accretion and the capitalized cost is depreciated over the useful life of the asset.
The majority of Occidental’s asset retirement obligationsAROs relate to the plugging of wells and the related abandonment of oil and gas properties. Revisions in estimated liabilities during the period primarily relate to liabilities acquired in the Acquisition and include, but are not limited to, changes in estimates of asset retirement costs, revisions of estimated inflation rates, changes in property lives and the expected timing of settlements.
At a certain number of its facilities, Occidental has identified conditional asset retirement obligationsAROs that are related mainly to plant decommissioning. Occidental does not know or cannot estimate when it may settle these obligations. Therefore, Occidental cannot reasonably estimate the fair value of these liabilities. Occidental will recognize these conditional asset retirement obligationsAROs in the periods in which sufficient information becomes available to reasonably estimate their fair values.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
The following table summarizes the activity of asset retirement obligationsAROs for the years ended December 31:
| | millions | millions | | 2020 | | 2019 | millions | | 2022 | | 2021 |
| Beginning balance | Beginning balance | | $ | 4,659 | | | $ | 1,499 | | Beginning balance | | $ | 4,026 | | | $ | 4,130 | |
| Liabilities assumed in the Acquisition | | 0 | | | 3,370 | | |
| | Liabilities incurred – capitalized to PP&E | Liabilities incurred – capitalized to PP&E | | 79 | | | 71 | | Liabilities incurred – capitalized to PP&E | | 55 | | | 27 | |
| Liabilities settled and paid | Liabilities settled and paid | | (186) | | | (200) | | Liabilities settled and paid | | (342) | | | (174) | |
| Accretion expense | Accretion expense | | 147 | | | 131 | | Accretion expense | | 145 | | | 205 | |
| Acquisitions, divestitures and other, net | Acquisitions, divestitures and other, net | | (294) | | | 0 | | Acquisitions, divestitures and other, net | | (54) | | | (53) | |
| WES loss of control | | 0 | | | (359) | | |
| | Revisions to previous estimates | Revisions to previous estimates | | (275) | | | 147 | | Revisions to previous estimates | | (25) | | | (109) | |
Ending balance (a) | Ending balance (a) | | $ | 4,130 | | | $ | 4,659 | | Ending balance (a) | | $ | 3,805 | | | $ | 4,026 | |
(a)The ending balance included $153$169 million and $248$339 million related to the current balance of AROs that are includedpresented in Accrued Liabilitiesaccrued liabilities on the Consolidated Balance Sheets atas of December 31, 2020,2022 and 2019,2021, respectively.
DERIVATIVE INSTRUMENTS
Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty. Occidental applies hedge accounting when transactions meet specified criteria for cash flow hedge treatment and management elects and documents such treatment. Otherwise, any fair value gains or losses are recognized in earnings in the current period. For cash flow hedges, the gain or loss on the effective portion of the derivative is reported as a component of other comprehensive income (OCI)OCI with an offsetting adjustment to the carrying value of the item being hedged. Realized gains or losses from cash flow hedges, and any ineffective portion, are recorded as a component of net sales in the consolidated statementsConsolidated Statements of operations.Operations. Ineffectiveness is primarily created by a lack of correlation between the hedged item and the hedging instrument due to location, quality, grade or changes in the expected quantity of the hedged item. Gains and losses
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
from derivative instruments are reported net in the consolidated statementsConsolidated Statements of operations.Operations. There were no fair value hedges as of and during the years ended December 31, 2020, 20192022, 2021 and 2018.2020.
STOCK-BASED INCENTIVE PLANS
Occidental has established several stockholder-approved stock-based incentive plans for certain employees and directors (Plans)the Plan that areis more fully described in Note 1415 - Stock-Based Incentive Plans. A summary of Occidental’s accounting policy for awards issued under the PlansPlan is as follows. For cash- and stock-settled restricted stock units (RSU)RSUs and cash return on capital employed incentiveCROCEI awards, (CROCEI), compensation value is initially measured on the grant date using the quoted market price of Occidental’s common stock and the estimated payout on the grant date. The fair value of stock options is estimated using a Black Scholes model. For total shareholder return incentiveTSRI awards, (TSRI), compensation value is initially measured on the grant date using the fair value derived from a Monte Carlo valuation model. Compensation expense for all awards is recognized on a straight-line basis over the requisite service periods, which is generally over the awards’ respective vesting or performance periods. The stock-settled portion of these awards isare expensed using the initially measured compensation value. The liability resulting from the cash settled portion of these awards and accrued dividends are remeasured at each reporting period. Dividends accrued on unvested awards are adjusted quarterly for any changes in the number of share equivalents expected to be paid based on the relevant performance and market criteria, if applicable.
EARNINGS PER SHARE (EPS)
Occidental’s instruments containing rights to nonforfeitable dividends granted in stock-based awards are considered participating securities prior to vesting and, therefore, have been deducted from earnings in computing basic and diluted EPS under the two-class method.
Basic EPS was computed by dividing net income attributable to common stock, net of income allocated to participating securities, by the weighted-average number of common shares outstanding during each period, including vested but unissued shares and share units. The computation of diluted EPS reflects the additional dilutive effect of stock options and unvested stock awards.
RETIREMENT AND POSTRETIREMENT BENEFIT PLANS
Occidental’s defined benefit pension and postretirement benefit plan obligations are actuarially determined based on various assumptions and discount rates. The discount rate assumptions used are meant to reflect the interest rate at which the obligations could effectively be settled on the measurement date. Occidental estimates the rate of return on assets with
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
regard to current market factors but within the context of historical returns. Occidental funds and expenses negotiated pension increases for domestic union employees over the terms of the applicable collective bargaining agreements.
Pension and any postretirement plan assets are measured at fair value. Common stock, preferred stock, publicly registered mutual funds, U.S. government securities and corporate bonds are valued using quoted market prices in active markets when available. When quoted market prices are not available, these investments are valued using pricing models with observable inputs from both active and non-active markets. Common and collective trusts are valued at the fund units’ net asset value (NAV)NAV provided by the issuer, which represents the quoted price in a non-active market. Short-term investment funds are valued at the fund units’ NAV provided by the issuer.
SUPPLEMENTAL CASH FLOW INFORMATION
Occidental paidThe following table represents U.S. federal, domestic state and foreigninternational income taxes forpaid, tax refunds received and interest paid related to continuing operations of approximately $0.5 billion, $1.9 billion and $1.1 billion during the yearsyear ended December 31, 2022, 2021 and 2020, 2019 and 2018, respectively. Occidental received refunds of $223 million, $80 million and $82 million during the years ended December 31, 2020, 2019, and 2018, respectively. Occidental also paid production, property and other taxes of approximately $755 million, $724 million and $508 million during the years ended December 31, 2020, 2019 and 2018, respectively, substantially all of which was in the United States. Interest paid totaled $1.6 billion, $912 million and $383 million, net
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Income tax payments | | $ | 2,184 | | | $ | 763 | | | $ | 498 | |
| Income tax refunds received | | $ | 89 | | | $ | 70 | | | $ | 223 | |
| Production, property and other tax payments | | $ | 1,093 | | | $ | 790 | | | $ | 629 | |
Interest paid (a) | | $ | 1,425 | | | $ | 1,685 | | | $ | 1,521 | |
(a) Net of capitalized interest of $83$69 million, $89$61 million and $46$84 million, for the years 2022, 2021 and 2020, 2019respectively.
Occidental swapped oil and 2018, respectively.gas acreage with a fair value of $340 million in non-monetary exchange transactions during the year ended December 31, 2022.
CASH EQUIVALENTS AND RESTRICTED CASH EQUIVALENTS
Occidental considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents or restricted cash equivalents. The cash equivalents and restricted cash equivalents balance atas of December 31, 2020,2022, included investments in government money market funds in which the carrying value approximates fair value.
The following table provides a reconciliation of cash, cash equivalents, restricted cash and restricted cash equivalents as reported at the end of the period in the Consolidated Statements of Cash Flows for the year ended December 31, 2020,2022 and 2019 to the line items within the Consolidated Balance Sheet at December 31, 2020 and 2019.2021:
| | | | | | | | | | | |
| millions | | December 31, 2020 | December 31, 2019 |
| Cash and cash equivalents | | $ | 2,008 | | $ | 3,032 | |
| Restricted cash and restricted cash equivalents | | 170 | | 485 | |
| Cash and restricted cash included in assets held for sale | | 0 | | 3 | |
| Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net | | 16 | | 54 | |
| Cash, cash equivalents, restricted cash and restricted cash equivalents | | $ | 2,194 | | $ | 3,574 | |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
Total restricted cash and restricted cash equivalents are primarily associated with an international joint venture, a benefits trust for former Anadarko employees and a judicially-controlled account related to a Brazilian tax dispute. Total restricted cash at December 31, 2019 also included payments of future hard-minerals royalties conveyed, the related liability of which was settled in August 2020, see Note 4 - Divestitures and Other Transactions. | | | | | | | | | | | |
| millions | | 2022 | 2021 |
| Cash and cash equivalents | | $ | 984 | | $ | 2,764 | |
| Restricted cash and restricted cash equivalents | | 26 | | 24 | |
| Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net | | 16 | | 15 | |
| Cash, cash equivalents, restricted cash and restricted cash equivalents | | $ | 1,026 | | $ | 2,803 | |
FOREIGN CURRENCY TRANSACTIONS
The functional currency applicable to all of Occidental’s international oil and gas operations is the U.S. dollar since cash flows are denominated principally in U.S. dollars. In Occidental’s other operations, Occidental’s use of non-United States dollar functional currencies was not material for all years presented. The effect of exchange rates on transactions in foreign currencies is included in periodic income. Occidental reports the exchange rate differences arising from translating foreign-currency-denominated balance sheet accounts to the United States dollar as of the reporting date in other comprehensive income.OCI. Exchange-rate gains and losses for continuing operations were not material for all years presented.
INCOME TAXES
Occidental files various U.S. federal, state and foreign income tax returns. The impact of changes in tax regulations are reflected when enacted. In general, deferred federal, state and foreign income taxes are provided on temporary differences between the financial statement carrying amounts of assets and liabilities and their respective tax basis. Occidental routinely assesses the realizability of its deferred tax assets. If Occidental concludes that it is more likely than not that some of the deferred tax assets will not be realized, the tax asset is reduced by a valuation allowance. Occidental recognizes a tax benefit from an uncertain tax position when it is more likely than not that the position will be sustained upon examination, based on the technical merits of the position. The tax benefit recorded is equal to the largest amount that is greater than 50% likely to be realized through final settlement with a taxing authority. Interest and penalties related to unrecognized tax benefits are recognized in income tax expense (benefit). Occidental uses the flow-through method to account for its investment tax credits. See Note 1210 - Income Taxes for more information.
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
OTHER LOSS CONTINGENCIES
Occidental or certain of its subsidiaries are involved, in the normal course of business, in lawsuits, claims and other legal proceedings that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. Occidental or certain of its subsidiaries also are involved in proceedings under CERCLA and similar federal, state, local and international environmental laws. These environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties and injunctive relief. Usually Occidental or such subsidiaries are among many companies in these environmental proceedings and have to date been successful in sharing response costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or disposed assets with respect to which a third-partythird party or Occidental or its subsidiaries retains liability or indemnifies the other party for conditions that existed prior to the transaction.
| | |
NOTE 2 - ACCOUNTING AND DISCLOSURE CHANGES |
RECENTLY ADOPTED ACCOUNTING AND DISCLOSURE CHANGES
In January 2020, Occidental adopted Accounting Standards Update (ASU) 2016-13 Financial Instruments - Credit Losses (Topic 326). The new standard makes significant changes to the accounting for credit losses on financial assets and disclosures regarding credit losses. For trade receivables, loans and held-to-maturity debt securities, entities will be required to estimate lifetime expected credit losses. This will result in the earlier recognition of credit losses than the current incurred-loss model. The acceleration of the recognition of losses is more material for entities whose receivables and other held-to-maturity debt investments are (1) long dated and (2) with less credit worthy counterparties.
The majority of Occidental's receivables are short dated with maturities of less than 60 days with creditworthy counterparties, including refiners, pipelines and resellers. Occidental strives to maintain a strong credit portfolio and there have been no negative indications regarding the collectability of these receivables as of the date of this filing. The adoption of this standard has no material impact. Occidental will continue to assess the risk to its receivables in the future.
In January 2019, Occidental adopted the new lease standard ASC Topic 842 - Leases (ASC 842) using the modified retrospective approach, which did not require restatement of prior year amounts and disclosures. ASC 842 requires Occidental to recognize most leases, including operating leases, on the balance sheet. The new rules require lessees to recognize a right-of-use (ROU) asset and lease liability for all leases with lease terms of more than 12 months. Occidental adopted the standard including adopting the following practical expedients:
■Leases that commenced before the effective date carried forward their historical lease classification;
■Existing or expired land easements as of December 31, 2018, were not reassessed to determine whether or not they contained a lease;
■Leases with a lease term of 12 months or less from lease commencement date are considered short-term leases and not recorded on the Consolidated Balance Sheet; however, the lease expenditures recognized are captured and reported as incurred; and
■For asset classes, except long-term drilling rigs, Occidental elected to account for the lease and non-lease components as a single lease component as the non-lease portions were not significant to separate in determining the lease liability. For long-term drilling rig contracts, Occidental bifurcated the lease and non-lease components using relative fair value as a stand-alone selling price between the asset rental and the services obtained.
For Occidental operations, adoption of ASC 842 resulted in recording of net lease assets and lease liabilities of $772 million as of January 1, 2019. There was no material impact to net income, cash flows, or stockholders’ equity. See Note 8 - Lease Commitments.
| | | | | |
OXY 20202022 FORM 10-K | 7775 |
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| | FINANCIAL STATEMENTS FOOTNOTES | |
On May 9, 2019, Occidental entered into the Acquisition Agreement with Anadarko. On August 8, 2019, Anadarko’s stockholders voted to approve the Acquisition and it was made effective the same day. The Acquisition added to Occidental’s oil and gas portfolio, primarily in the Permian Basin, DJ Basin and Gulf of Mexico and Algeria and a controlling interest in WES.
In exchange for each share of Anadarko common stock, Anadarko stockholders received $59.00 in cash and 0.2934 of a share of Occidental common stock, plus cash in lieu of any fractional share of Occidental common stock that otherwise would have been issued, based on the average price of $46.31 per share of Occidental common stock on the NYSE on August 8, 2019.
In connection with the Acquisition, Occidental issued $13.0 billion of new senior unsecured notes, $8.8 billion of term loans (the Term Loans) and 100,000 shares of series A preferred stock (the Preferred Stock) with a warrant to purchase 80 million shares of Occidental common stock at an exercise price of $62.50 (the Warrant) for $10 billion. In addition, Occidental increased its existing $3.0 billion RCF by an additional $2.0 billion in commitments. See Note 7 - Long-term Debt and Note 13 - Stockholders’ Equity for additional information.The Acquisition constitutes a business combination and was accounted for using the acquisition method of accounting. The following table presents the Acquisition consideration paid to Anadarko stockholders as a result of the Acquisition:
| | | | | | | | |
millions except per-share amounts | As of August 8, 2019 |
Total shares of Anadarko common stock eligible for Acquisition consideration | | 491.6 | |
Cash consideration (per share of common stock and shares underlying Anadarko stock-based awards eligible for Acquisition consideration) | | $ | 59.00 | |
Cash portion of Acquisition consideration | | $ | 29,002 | |
| | |
Total shares of Anadarko common stock eligible for Acquisition consideration | | 491.6 | |
Exchange ratio (per share of Anadarko common stock) | | 0.2934 | |
Total shares of Occidental common stock issued to Anadarko stockholders | | 144 | |
Average share price of Occidental common stock at August 8, 2019 | | $ | 46.31 | |
Stock portion of Acquisition consideration | | $ | 6,679 | |
| | |
Acquisition consideration attributable to Anadarko stock-based awards | | $ | 23 | |
| | |
Total Acquisition consideration | | $ | 35,704 | |
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
The following table sets forth the allocation of the Acquisition consideration. Occidental finalized the purchase price allocation during the 12 month period following the Acquisition date, those measurement period adjustments recorded were immaterial and did not result in a material impact to the statements of operations.
| | | | | | | | |
millions | As of August 8, 2019 |
Fair value of assets acquired: | | |
Current assets | | $ | 3,586 | |
Assets held for sale (a)
| | 10,616 | |
Investments in unconsolidated entities | | 194 | |
Property, plant and equipment | | 49,125 | |
Other assets | | 836 | |
Amount attributable to assets acquired | | $ | 64,357 | |
| | |
Fair value of liabilities assumed: | | |
Current liabilities | | $ | 3,467 | |
Liabilities of assets held for sale (a)
| | 2,200 | |
Long-term debt | | 13,240 | |
Deferred income taxes | | 8,591 | |
Asset retirement obligations | | 2,724 | |
Pension and post-retirement obligations | | 1,072 | |
Non-current derivative liabilities | | 1,280 | |
Other long-term liabilities | | 2,323 | |
Amount attributable to liabilities assumed | | $ | 34,897 | |
| | |
Net assets | | $ | 29,460 | |
Fair value of WES net assets acquired less noncontrolling interests (a)
| | $ | 6,244 | |
Total Acquisition consideration | | $ | 35,704 | |
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
The following table summarizes the fair value of the major categories of WES assets acquired and liabilities assumed at the Acquisition date as well as the noncontrolling interest, which primarily consisted of the 44.6% limited partner interest in WES owned by the public. The fair value of Occidental’s controlling interest in WES is calculated based on the market capitalization value at the Acquisition date.
| | | | | | | | |
millions | As of August 8, 2019 |
Fair value of WES assets acquired: | | |
Current assets | | $ | 499 | |
Investments in unconsolidated entities | | 2,425 | |
Property, plant and equipment | | 10,160 | |
Intangible assets - customer relationships | | 1,800 | |
Goodwill | | 5,772 | |
Other assets | | 342 | |
Amount attributable to assets acquired | | $ | 20,998 | |
| | |
Fair value of WES liabilities assumed: | | |
Current liabilities | | $ | 815 | |
Long-term debt | | 7,407 | |
Deferred income taxes | | 1,174 | |
Asset retirement obligations | | 321 | |
Other long-term liabilities | | 142 | |
Amount attributable to liabilities assumed | | $ | 9,859 | |
| | |
Net assets | | $ | 11,139 | |
Less: Fair value of noncontrolling interests in WES | | $ | 4,895 | |
Fair value of WES net assets acquired less noncontrolling interests | | $ | 6,244 | |
The aggregate purchase price noted above was allocated to the major categories of assets and liabilities acquired based upon their preliminary estimated fair values at the date of the Acquisition. The valuation of certain assets, including property and intangible assets, are based on preliminary appraisals. The majority of measurements of assets acquired and liabilities assumed, other than debt, are based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of acquired properties and equipment is based on both available market data and a cost approach.
Onshore undeveloped oil and gas properties were valued primarily using a market approach based on comparable transactions for similar properties while the income approach was utilized for developed oil and gas properties based on underlying reserve projections at the Acquisition date. For the acquired Gulf of Mexico offshore properties, an income approach was used as the primary valuation method based on underlying reserve projections. Income approaches are considered level 3 fair value estimates and include significant assumptions of future production, commodity prices and operating and capital cost estimates, discounted using weighted average cost of capital for industry peers and risk adjustment factors based on reserve category. Price assumptions were based on a combination of market information and published industry resources adjusted for historical differentials. Cost estimates were based on current observable costs inflated based on historical and expected future inflation. Taxes were based on current statutory rates.
The fair value of WES investments in unconsolidated entities were valued using an income approach for each investment, with significant inputs being forecasted distributions, an anticipated growth rate and an estimated discount rate. Acquired WES property, plant and equipment primarily consisted of gathering systems and processing and treating facilities and were primarily valued using a replacement cost approach. Intangible assets primarily consist of relationships with third-party customers, the fair value of which was determined using an income approach, including significant assumptions related to estimated cash flows from third-party customers less a contributory asset charge, a customer retention rate and an estimated discount rate. Customer relationships are amortized over 30 years. Goodwill is attributable to the difference in WES market capitalization value and the net assets acquired and primarily relates to the relationship between Occidental and WES that is not recognized as a separate asset, due to Occidental consolidating WES as of the Acquisition date.
Deferred income taxes represent the tax effects of differences in the tax basis and acquisition-date fair values of assets acquired and liabilities assumed. The measurement of debt instruments was based on unadjusted quoted prices in an active market and are primarily Level 1; approximately $2.5 billion of the assumed Anadarko debt is considered Level 2 while
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| FINANCIAL STATEMENTS
FOOTNOTES
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approximately $730 million of the WES debt is considered Level 2. The value of derivative instruments was based on observable inputs, primarily forward commodity price and interest rate curves and is considered Level 2.
With the completion of the Acquisition, Occidental acquired proved and unproved properties of approximately $19.1 billion and $27.4 billion, respectively, primarily associated with the Permian Basin, DJ Basin, Gulf of Mexico and Powder River Basin. The remaining $2.5 billion in PP&E consisted of non-oil and gas mineral interests and other real estate assets.
From the date of the Acquisition through December 31, 2019, revenues and the net loss attributable to common stockholders associated with the operations acquired through the Acquisition totaled $4.2 billion and $1.7 billion, respectively, which includes a charge as a result of recording Occidental’s investment in WES at fair value as of December 31, 2019 upon the loss of control.
The following table summarizes the unaudited pro forma condensed financial information of Occidental for the year ended December 31 as if the Acquisition had occurred on January 1, 2018:
| | | | | | | | |
| Year ended December 31, |
| millions except per-share amounts | 2019 | 2018 |
| Revenues | $ | 28,723 | | $ | 31,206 | |
Net income (loss) attributable to common stockholders (a) | $ | (769) | | $ | 2,965 | |
| Net income (loss) attributable to common stockholders per share—basic | $ | (0.95) | | $ | 3.26 | |
| Net income (loss) attributable to common stockholders per share—diluted | $ | (0.95) | | $ | 3.25 | |
| | |
(a)Excluding the pro-forma results of WES, net income (loss) attributable to common stockholders would be $(1.1) billion and $2.8 billion for the year ended December 31, 2019 and 2018, respectively.
The unaudited pro forma information is presented for illustration purposes only and is not necessarily indicative of the operating results that would have occurred had the Acquisition been completed at January 1, 2018, nor is it necessarily indicative of future operating results of the combined entity. The unaudited pro forma information for 2019 is a result of combining the statements of operations of Occidental with the pre-Acquisition results from January 1, 2019 of Anadarko and included adjustments for revenues and direct expenses. The pro forma results exclude results from the held for sale Africa assets, any cost savings anticipated as a result of the Acquisition and the impact of any Acquisition-related costs. The pro forma results include adjustments to DD&A based on the purchase price allocated to property, plant and equipment and the estimated useful lives as well as adjustments to interest expense. The pro forma adjustments include estimates and assumptions based on currently available information. Management believes the estimates and assumptions are reasonable and the relative effects of the Acquisition are properly reflected.
ANADARKO ACQUISITION-RELATED COSTS
The following table summarizes the Acquisition-related costs incurred for the year ended December 31:
| | | | | | | | | | | |
| millions | | 2020 | 2019 |
| Employee severance and related employee cost | | $ | 314 | | $ | 1,033 | |
| Licensing fees for critical seismic data | | 0 | | 401 | |
| Bank, legal, consulting and other | | 25 | | 213 | |
| Total | | $ | 339 | | $ | 1,647 | |
| | | |
Employee severance and related employee cost primarily relates to one-time severance costs and the accelerated vesting of certain Anadarko share-based awards for former Anadarko employees based on the terms of the Acquisition Agreement and existing change of control provisions within the former Anadarko employment agreements. In addition, employee severance and related employee cost included expenses for a voluntary separation program for eligible employees. Occidental initiated this program to align the size and composition of its workforce with its expected future operating and capital plans.
The seismic licensing fees relate to relicensing of critical seismic data related to the Gulf of Mexico, Permian Basin and DJ Basin that Anadarko had licensed from third-party vendors. The third-party vendors who own the seismic data required a transfer fee in order for Occidental to use the data.
DEBT ISSUED AND ASSUMED IN CONNECTION WITH THE ACQUISITION
On August 8, 2019, Occidental issued $13.0 billion of new senior unsecured notes, consisting of both floating and fixed rate debt. Occidental also borrowed under the Term Loans, which consist of: (1) a 364-day senior unsecured variable-rate term loan tranche of $4.4 billion and (2) a two-year senior unsecured variable-rate term loan tranche of $4.4 billion. In total,
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
the $21.8 billion in debt issued was used to finance part of the cash portion of the purchase price for the Acquisition.
In the Acquisition, Occidental assumed Anadarko debt with an outstanding principal balance of $11.9 billion. In September 2019, Occidental completed its offers to exchange the Anadarko senior notes and debentures assumed as part of the Acquisition for notes of a corresponding series issued by Occidental and cash and related solicitation of consents. Of the approximately $11.9 billion in aggregate principal amount of Anadarko senior notes and debentures offered in the exchange, 97%, or approximately $11.5 billion, were tendered and accepted in the exchange offers. The portion not exchanged, approximately $400 million, remained outstanding.
| | |
NOTE 4 - DIVESTITURES AND OTHER TRANSACTIONS |
DIVESTITURES AND OTHER TRANSACTIONS
2020
In November 2020 and December 2020, Occidental divested of certain non-core, largely non-operated proved and unproved acreage in the Permian for a loss of approximately $820 million. The losses have been presented within gains (losses) on sale of assets, net in the Consolidated Statement of Operations. The net proceeds were used to pay down near-term maturities.
In October 2020, Occidental entered into an agreement to sell its onshore oil and gas Colombia assets. The transaction closed in December 2020, and Occidental recorded a loss on sale of approximately $353 million. The loss has been presented within gains (losses) on sale of assets, net in the Consolidated Statement of Operations. The net proceeds were used to pay down near-term maturities.
In August 2020, Occidental entered into an agreement to sell approximately 4.5 million mineral acres and 1 million fee surface acres located in Wyoming, Colorado and Utah for approximately $1.33 billion. The transaction closed in October 2020 for net cash proceeds of approximately $1.0 billion, after satisfying $329 million of liabilities associated with the sale of future royalties. Occidental recorded a loss on sale of $440 million. The loss has been presented within gains (losses) on sale of assets, net in the Consolidated Statement of Operations. The net proceeds were utilized to pay down a portion of the 2-year variable rate Term Loan due 2021. See Note 7 - Long-Term Debt for further information.
2019
In December 2019, Occidental disposed of real estate assets for $565 million. Occidental utilized net proceeds to pay down a portion of the Term Loans. Concurrent with the sale, Occidental entered a 13-year lease for part of the real estate assets. Based on the terms of the lease, Occidental treated this as a failed sale-leaseback, retained the related book value in property, plant and equipment and recognized a finance lease of approximately $300 million based on the discounted future minimum lease payments.
In November 2019, Occidental and Ecopetrol closed on the joint venture to develop approximately 97,000 net acres of Occidental’s Midland Basin unproved properties in the Permian Basin. Ecopetrol paid $750 million in cash at closing and up to $750 million of carried capital in exchange for a 49% interest in the new venture. Occidental recognized a gain of $563 million on the sale. Following the close, Occidental owned a 51% interest and operates the joint venture. During the carry period, Ecopetrol will pay 75% of Occidental’s share of capital expenditures, up to $750 million. The joint venture allows Occidental to accelerate its development plans in the Midland Basin, where it currently has minimal activity. Occidental will retain production and cash flow from its existing operations in the Midland Basin. The proceeds were used to pay down a portion of the Term Loans.
In September 2019, Occidental sold its remaining equity investment in Plains for net proceeds of $646 million, which resulted in a pre-tax gain of $114 million. The proceeds were used to pay down a portion of the Term Loans.
2018
In September 2018, Occidental divested non-core domestic midstream assets for total consideration of $2.6 billion, of which approximately $2.4 billion was received at closing, resulting in a pre-tax net gain of $907 million. These assets include the Centurion common carrier oil pipeline and storage system, Southeast New Mexico oil gathering system and Ingleside Crude Terminal. Following the transactions, Occidental retained its long-term flow assurance, pipeline takeaway and export capacity through its retained marketing business.
In July 2018, Occidental acquired a previously leased power and steam cogeneration facility for $443 million.
In March 2018, Occidental divested non-core midstream assets for approximately $150 million, resulting in a pre-tax gain of $43 million.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
DISCONTINUED OPERATIONS
The following table presents the amounts reported in discontinued operations, net of income taxes, related to the Ghana assets for the year ended December 31, 2020 and for the Ghana, Mozambique and South Africa assets subsequent to the Acquisition closing date through December 31, 2019:
| | | | | | | | |
| millions | 2020 | 2019 |
| Revenues and other income | | |
| Net sales | $ | 419 | | $ | 221 | |
| | |
| Costs and other deductions | | |
| Oil and gas lease operating expense | 117 | | 45 | |
| Fair value adjustment on assets held for sale | 2,263 | | 85 | |
| Other | 48 | | 45 | |
| Total costs and other deductions | $ | 2,428 | | $ | 175 | |
| | |
| Income (loss) before income taxes | $ | (2,009) | | $ | 46 | |
| Income tax benefit (expense) | 711 | | (61) | |
| Discontinued operations, net of tax | $ | (1,298) | | $ | (15) | |
The following table presents amounts related to the Ghana assets reported as held for sale in the Consolidated Balance Sheet as of December 31, 2020 and the amounts related to the Mozambique, South Africa and Ghana assets reported as held for sale in the Consolidated Balance Sheet as of December 31, 2019, respectively:
| | | | | | | | |
| millions | 2020 | 2019 |
| | |
| Current assets | $ | 37 | | $ | 40 | |
| Property, plant and equipment, net | 1,364 | | 3,720 | |
| Long-term receivables and other assets, net | 32 | | 110 | |
| Assets held for sale | $ | 1,433 | | $ | 3,870 | |
| | |
| Current liabilities | $ | 84 | | $ | 264 | |
| Long-term debt, net - finance leases | 175 | | 185 | |
| Deferred income taxes | 328 | | 1,112 | |
| Asset retirement obligations | 166 | | 155 | |
| Other | 0 | | 2 | |
| Liabilities of assets held for sale | $ | 753 | | $ | 1,718 | |
| | |
| Net assets held for sale | $ | 680 | | $ | 2,152 | |
| | |
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
ALGERIA OPERATIONS RECLASSIFICATION
The following table presents the amounts previously reported in discontinued operations, net of income taxes, for the year ended December 31, 2019 which was reclassified to continuing operations as a result of Occidental's decision to operate in Algeria.
| | | | | | | | |
millions | | Year ended December 31, 2019 |
| | |
Revenues and other income | | |
Net sales | | $ | 518 | |
| | |
Costs and other deductions | | |
Oil and gas lease operating expense | | 36 | |
Transportation expense | | 14 | |
Taxes other than on income | | 133 | |
Depreciation, depletion and amortization | | 159 | |
Other | | 9 | |
Total costs and other deductions | | 351 | |
| | |
Income before income taxes | | 167 | |
Income tax expense | | (167) | |
Net income of Algeria operations, after taxes | | $ | 0 | |
The following table presents the amounts previously reported in the Consolidated Balance Sheets as held for sale related to Algeria that were subsequently reclassified as of December 31, 2019:
| | | | | | | | |
millions | | December 31, 2019 |
Current assets | | $ | 249 | |
Property, plant and equipment, net | | 1,761 | |
Long-term receivables and other assets, net | | 146 | |
Total Assets | | $ | 2,156 | |
| | |
Current liabilities | | $ | 188 | |
Non-current liabilities | | 104 | |
Total Liabilities | | $ | 292 | |
Revenue from customers is recognized when obligations under the terms of a contract are satisfied; this generally occurs with the delivery of oil, NGL, gas, chemicals or services such as transportation. Revenue from customers is measured as the amount of consideration Occidental expects to receive in exchange for the delivery of goods or services. Contracts may last from one month to one year or more and may have renewal terms that extend indefinitely at the option of either party. Price is typically based on market indexes. Volumes fluctuate due to production and, in certain cases, customer demand and transportation availability. Occidental records revenue net of certain taxes, such as sales taxes, that are assessed by governmental authorities on Occidental’s customers.
Occidental does not incur significant costs to obtain contracts. Incidental items that are immaterial in the context of the contract are recognized as expenses. Sales of hydrocarbons and chemicals to customers are invoiced and settled on a monthly basis. Occidental is not usually subject to obligations for warranties, rebates, returns or refunds except in the case of customer incentive payments as discussed for the chemical segment below. Occidental does not typically receive payment in advance of satisfying its obligations under the terms of its sales contracts with customers; therefore, liabilities related to such payment are immaterial to Occidental. Occidental does not disclose consideration for remaining performance obligations with an original expected duration of one year or less or for variable consideration related to unsatisfied
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
performance obligations. Revenue expected to be recognized from unsatisfied performance obligations as of December 31, 2020, was $103 million in 2021 and $59 million thereafter with the majority being recognized between 2022 and 2033.
OIL AND GAS SEGMENT
Revenue from oil and gas production is recognized when production is delivered and control passes to the customer. Revenues from the production of oil and gas properties in which Occidental has an interest with other producers are recognized on the basis of Occidental’s net revenue interest.
CHEMICALSCHEMICAL SEGMENT
Revenue from chemical product sales is recognized when control passes to the customer. Certain incentive programs may provide for payments or credits to be made to customers based on the volume of product purchased over a defined period. Customer incentives are estimated and recorded as a reduction to revenue ratably over the contract period. Such estimates are evaluated and revised as warranted. Revenue from exchange contracts is excluded from revenue from customers.
MIDSTREAM AND MARKETING SEGMENT
Revenue from pipeline and gas processing is recognized upon the completion of the transportation or processing service. Revenue from power sales is recognized upon delivery. Net marketing revenue is recognized upon completion of contract terms that are a prerequisite to payment and upon title transfer for physical deliveries. Unless the normal purchases and sales exception has been elected, net marketing revenue is classified as a derivative, reported on a net basis, recorded at fair value and changesvalue. Changes in fair value are reflected in net sales and excluded from revenue from customers in the table below.
DISAGGREGATION OF REVENUE FROM CONTRACTS WITH CUSTOMERS
The following table reconciles revenue from customers to total net sales for the years ended December 31:
| | millions | millions | | 2020 | | 2019 | millions | | 2022 | | 2021 | | 2020 |
| Revenue from customers | Revenue from customers | | $ | 17,130 | | | $ | 19,192 | | Revenue from customers | | $ | 36,234 | | | $ | 25,959 | | | $ | 17,130 | |
All other revenues (a) | All other revenues (a) | | 679 | | | 1,719 | | All other revenues (a) | | 400 | | | (3) | | | 679 | |
| Net sales | Net sales | | $ | 17,809 | | | $ | 20,911 | | Net sales | | $ | 36,634 | | | $ | 25,956 | | | $ | 17,809 | |
(a)Included net marketing derivatives, oil collars and calls and chemical exchange contracts.
| | | | | |
| 76 | OXY 20202022 FORM 10-K | 85 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
DISAGGREGATION OF REVENUE FROM CONTRACTS WITH CUSTOMERS
The table below presents Occidental's revenue from customers by segment, product and geographical area. The oil and gas segment typically sells its oil, NGL and natural gas at the lease or concession area. Chemical segment revenues are shown by geographic area based on the location of the sale. Excluding net marketing revenue, midstream and marketing segment revenues are shown by the location of sale.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | United States | | Middle East | | Latin America | | Other International | | Eliminations | | Total |
| Year ended December 31, 2020 | | | | | | | | | | | | |
| Oil and gas | | | | | | | | | | | | |
| Oil | | $ | 7,485 | | | $ | 1,949 | | | $ | 454 | | | $ | 0 | | | $ | 0 | | | $ | 9,888 | |
| NGL | | 838 | | | 217 | | | 0 | | | 0 | | | 0 | | | 1,055 | |
| Gas | | 660 | | | 313 | | | 13 | | | 0 | | | 0 | | | 986 | |
| Other | | 65 | | | 1 | | | 0 | | | 0 | | | 0 | | | 66 | |
| Segment total | | $ | 9,048 | | | $ | 2,480 | | | $ | 467 | | | $ | 0 | | | $ | 0 | | | $ | 11,995 | |
| Chemical | | $ | 3,524 | | | $ | 0 | | | $ | 137 | | | $ | 65 | | | $ | 0 | | | $ | 3,726 | |
| Midstream and marketing | | | | | | | | | | | | |
| Gas processing | | $ | 350 | | | $ | 294 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 644 | |
| Marketing | | 1,144 | | | 0 | | | 0 | | | 278 | | | 0 | | | 1,422 | |
| Power and other | | 101 | | | 0 | | | 0 | | | 0 | | | 0 | | | 101 | |
| Segment total | | $ | 1,595 | | | $ | 294 | | | $ | 0 | | | $ | 278 | | | $ | 0 | | | $ | 2,167 | |
| Eliminations | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | (758) | | | $ | (758) | |
| Consolidated | | $ | 14,167 | | | $ | 2,774 | | | $ | 604 | | | $ | 343 | | | $ | (758) | | | $ | 17,130 | |
| | | | | | | | | | | | |
| Year ended December 31, 2019 | | | | | | | | | | | | |
| Oil and gas | | | | | | | | | | | | |
| Oil | | $ | 8,411 | | | $ | 3,256 | | | $ | 683 | | | $ | 0 | | | $ | 0 | | | $ | 12,350 | |
| NGL | | 658 | | | 283 | | | 0 | | | 0 | | | 0 | | | 941 | |
| Gas | | 424 | | | 319 | | | 20 | | | 0 | | | 0 | | | 763 | |
| Other | | (1) | | | (5) | | | 0 | | | 0 | | | 0 | | | (6) | |
| Segment total | | $ | 9,492 | | | $ | 3,853 | | | $ | 703 | | | $ | 0 | | | $ | 0 | | | $ | 14,048 | |
| Chemical | | $ | 3,858 | | | $ | 0 | | | $ | 155 | | | $ | 67 | | | $ | 0 | | | $ | 4,080 | |
Midstream and marketing (a) | | | | | | | | | | | | |
Gas processing and CO2 | | $ | 395 | | | $ | 351 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 746 | |
| Marketing | | 436 | | | 0 | | | 0 | | | 0 | | | 0 | | | 436 | |
| WES - Gas processing | | 1,110 | | | 0 | | | 0 | | | 0 | | | 0 | | | 1,110 | |
| Power and other | | 36 | | | 0 | | | 0 | | | 0 | | | 0 | | | 36 | |
| Segment total | | $ | 1,977 | | | $ | 351 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 2,328 | |
| Eliminations | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | (1,264) | | | $ | (1,264) | |
| Consolidated | | $ | 15,327 | | | $ | 4,204 | | | $ | 858 | | | $ | 67 | | | $ | (1,264) | | | $ | 19,192 | |
(a)The midstream and marketing segment included revenues from customers from WES from the date of the Acquisition to December 31, 2019. See Note 1 - Summary of Significant Accounting Policies for more information. | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | United States | | International | | Eliminations | | Total |
| Year ended December 31, 2022 | | | | | | | | |
| Oil and gas | | | | | | | | |
| Oil | | $ | 17,421 | | | $ | 3,935 | | | $ | — | | | $ | 21,356 | |
| NGL | | 2,631 | | | 421 | | | — | | | 3,052 | |
| Gas | | 2,422 | | | 311 | | | — | | | 2,733 | |
| Other | | 20 | | | 4 | | | — | | | 24 | |
| Segment total | | $ | 22,494 | | | $ | 4,671 | | | $ | — | | | $ | 27,165 | |
| Chemical | | $ | 6,359 | | | $ | 379 | | | $ | — | | | $ | 6,738 | |
| Midstream and marketing | | $ | 3,167 | | | $ | 588 | | | $ | — | | | $ | 3,755 | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| Eliminations | | $ | — | | | $ | — | | | $ | (1,424) | | | $ | (1,424) | |
| Consolidated | | $ | 32,020 | | | $ | 5,638 | | | $ | (1,424) | | | $ | 36,234 | |
| | | | | | | | |
| Year ended December 31, 2021 | | | | | | | | |
| Oil and gas | | | | | | | | |
| Oil | | $ | 12,072 | | | $ | 2,844 | | | $ | — | | | $ | 14,916 | |
| NGL | | 2,203 | | | 325 | | | — | | | 2,528 | |
| Gas | | 1,524 | | | 291 | | | — | | | 1,815 | |
| Other | | 24 | | | 2 | | | — | | | 26 | |
| Segment total | | $ | 15,823 | | | $ | 3,462 | | | $ | — | | | $ | 19,285 | |
| Chemical | | $ | 4,995 | | | $ | 248 | | | $ | — | | | $ | 5,243 | |
| Midstream and marketing | | $ | 1,969 | | | $ | 556 | | | $ | — | | | $ | 2,525 | |
| Eliminations | | $ | — | | | $ | — | | | $ | (1,094) | | | $ | (1,094) | |
| Consolidated | | $ | 22,787 | | | $ | 4,266 | | | $ | (1,094) | | | $ | 25,959 | |
| | | | | | | | |
| Year ended December 31, 2020 | | | | | | | | |
| Oil and gas | | | | | | | | |
| Oil | | $ | 7,485 | | | $ | 2,403 | | | $ | — | | | $ | 9,888 | |
| NGL | | 838 | | | 217 | | | — | | | 1,055 | |
| Gas | | 660 | | | 326 | | | — | | | 986 | |
| Other | | 65 | | | 1 | | | — | | | 66 | |
| Segment total | | $ | 9,048 | | | $ | 2,947 | | | $ | — | | | $ | 11,995 | |
| Chemical | | $ | 3,524 | | | $ | 202 | | | $ | — | | | $ | 3,726 | |
| Midstream and marketing | | $ | 1,595 | | | $ | 572 | | | $ | — | | | $ | 2,167 | |
| Eliminations | | $ | — | | | $ | — | | | $ | (758) | | | $ | (758) | |
| Consolidated | | $ | 14,167 | | | $ | 3,721 | | | $ | (758) | | | $ | 17,130 | |
0 | | | | | |
86 | OXY 20202022 FORM 10-K | 77 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
Finished goods primarily represents oil, which is carried at the lower of weighted-average cost or net realizable value, and caustic soda and chlorine, which are valued under the LIFO method. Inventories consisted of the following atas of December 31:
| | millions | millions | | 2020 | | 2019 | millions | | 2022 | | 2021 |
| Raw materials | Raw materials | | $ | 70 | | | $ | 75 | | Raw materials | | $ | 120 | | | $ | 96 | |
| Materials and supplies | Materials and supplies | | 848 | | | 974 | | Materials and supplies | | 913 | | | 783 | |
| Commodity inventory and finished goods | Commodity inventory and finished goods | | 1,009 | | | 572 | | Commodity inventory and finished goods | | 1,147 | | | 1,066 | |
| | 1,927 | | | 1,621 | | | 2,180 | | | 1,945 | |
| Revaluation to LIFO | Revaluation to LIFO | | (29) | | | (40) | | Revaluation to LIFO | | (121) | | | (99) | |
| Total | Total | | $ | 1,898 | | | $ | 1,581 | | Total | | $ | 2,059 | | | $ | 1,846 | |
| | |
NOTE 74 - LONG-TERM DEBTINVESTMENTS AND RELATED-PARTY TRANSACTIONS |
AtEQUITY INVESTMENTS
Occidental’s significant equity investments are presented in investments in unconsolidated entities and in deferred credits and other liabilities - other. As of December 31, 20202022 and 2019,2021, investments in unconsolidated entities were $3.2 billion and $2.9 billion, respectively. Occidental’s long-term debt consistedequity investments presented in investments in unconsolidated entities primarily consist of the following:
| | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | | | |
| 4.850% senior notes due 2021 | | $ | 147 | | | $ | 677 | | | | | |
| 2.600% senior notes due 2021 | | 224 | | | 1,500 | | | | | |
| 4.100% senior note due 2021 | | 0 | | | 1,249 | | | | | |
| Variable rate bonds due 2021 (1.193% and 2.854% as of December 31, 2020 and 2019, respectively) | | 27 | | | 500 | | | | | |
| Variable rate bonds due 2021 (3.151% as of December 31, 2019) | | 0 | | | 500 | | | | | |
| 2-year variable rate Term Loan due 2021 (3.111% as of December 31, 2019) | | 0 | | | 1,956 | | | | | |
| 2.700% senior notes due 2022 | | 629 | | | 2,000 | | | | | |
| 3.125% senior notes due 2022 | | 276 | | | 814 | | | | | |
| 2.600% senior notes due 2022 | | 101 | | | 400 | | | | | |
| Variable rate bonds due 2022 (1.730% and 3.360% as of December 31, 2020 and 2019, respectively) | | 1,052 | | | 1,500 | | | | | |
| 2.700% senior notes due 2023 | | 927 | | | 1,191 | | | | | |
| 8.750% medium-term notes due 2023 | | 22 | | | 22 | | | | | |
| 2.900% senior notes due 2024 | | 3,000 | | | 3,000 | | | | | |
| 6.950% senior notes due 2024 | | 650 | | | 650 | | | | | |
| 3.450% senior notes due 2024 | | 248 | | | 248 | | | | | |
| 8.000% senior notes due 2025 | | 500 | | | 0 | | | | | |
| 5.875% senior notes due 2025 | | 900 | | | 0 | | | | | |
| 3.500% senior notes due 2025 | | 750 | | | 750 | | | | | |
| 5.500% senior notes due 2025 | | 750 | | | 0 | | | | | |
| 5.550% senior notes due 2026 | | 1,100 | | | 1,100 | | | | | |
| 3.200% senior notes due 2026 | | 1,000 | | | 1,000 | | | | | |
| 3.400% senior notes due 2026 | | 1,150 | | | 1,150 | | | | | |
| 7.500% debentures due 2026 | | 112 | | | 112 | | | | | |
| 8.500% senior notes due 2027 | | 500 | | | 0 | | | | | |
| 3.000% senior notes due 2027 | | 750 | | | 750 | | | | | |
| 7.125% debentures due 2027 | | 150 | | | 150 | | | | | |
| 7.000% debentures due 2027 | | 48 | | | 48 | | | | | |
| 6.625% debentures due 2028 | | 14 | | | 14 | | | | | |
| | | | | | | | | | | | | | |
| millions | % Economic Interest | | Carrying amount |
WES (a) | | 51.7 | % | | $ | 2,006 | |
| OxyChem Ingleside Facility | | 50.0 | % | | 566 | |
| OLCV - related | | various | | 416 | |
| Other | | various | | 188 | |
Total Investments in unconsolidated entities (b) | | | | $ | 3,176 | |
| | | | |
(b) Not presented in investments in unconsolidated entities is Occidental’s 24.5% ownership in DEL, which had a carrying value of $213 million and is presented in deferred credits and other liabilities - other. Refer to the discussion below regarding the presentation of Occidental’s equity investment in DEL.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
| | | | | | | | | | | | | | | | | | |
| 7.150% debentures due 2028 | | 235 | | | 235 | | | | | |
| 7.200% senior debentures due 2028 | | 82 | | | 82 | | | | | |
| 6.375% senior notes due 2028 | | 600 | | | 0 | | | | | |
| 7.200% debentures due 2029 | | 135 | | | 135 | | | | | |
| 7.950% debentures due 2029 | | 116 | | | 116 | | | | | |
| 8.450% senior debentures due 2029 | | 116 | | | 116 | | | | | |
| 3.500% senior notes due 2029 | | 1,500 | | | 1,500 | | | | | |
| Variable rate bonds due 2030 (4.210% and 1.705% as of December 31, 2020 and 2019, respectively) | | 68 | | | 68 | | | | | |
| 8.875% senior notes due 2030 | | 1,000 | | | 0 | | | | | |
| 6.625% senior notes due 2030 | | 1,500 | | | 0 | | | | | |
| 6.125% senior notes due 2031 | | 1,250 | | | 0 | | | | | |
| 7.500% senior notes due 2031 | | 900 | | | 900 | | | | | |
| 7.875% senior notes due 2031 | | 500 | | | 500 | | | | | |
| 6.450% senior notes due 2036 | | 1,750 | | | 1,750 | | | | | |
| Zero Coupon senior notes due 2036 | | 2,269 | | | 2,271 | | | | | |
| 6.500% note payable to WES due 2038 | | 0 | | | 260 | | | | | |
| 4.300% senior notes due 2039 | | 750 | | | 750 | | | | | |
| 7.950% senior notes due 2039 | | 325 | | | 325 | | | | | |
| 6.200% senior notes due 2040 | | 750 | | | 750 | | | | | |
| 4.500% senior notes due 2044 | | 625 | | | 625 | | | | | |
| 4.625% senior notes due 2045 | | 750 | | | 750 | | | | | |
| 6.600% senior notes due 2046 | | 1,100 | | | 1,100 | | | | | |
| 4.400% senior notes due 2046 | | 1,200 | | | 1,200 | | | | | |
| 4.100% senior notes due 2047 | | 750 | | | 750 | | | | | |
| 4.200% senior notes due 2048 | | 1,000 | | | 1,000 | | | | | |
| 4.400% senior notes due 2049 | | 750 | | | 750 | | | | | |
| 7.730% debentures due 2096 | | 60 | | | 60 | | | | | |
| 7.500% debentures due 2096 | | 78 | | | 78 | | | | | |
| 7.250% debentures due 2096 | | 49 | | | 49 | | | | | |
| Total borrowings at face value | | $ | 35,235 | | | $ | 37,401 | | | | | |
| Adjustments to book value: | | | | | | | | |
| Unamortized premium, net | | 748 | | | 914 | | | | | |
| Debt issuance costs | | (156) | | | (125) | | | | | |
| Long-term finance leases | | 316 | | | 347 | | | | | |
| Current finance leases | | 42 | | | 51 | | | | | |
| Total debt and finance leases | | $ | 36,185 | | | $ | 38,588 | | | | | |
| Less current maturities of financing leases | | (42) | | | (51) | | | | | |
| Less current maturities of long-term debt | | (398) | | | 0 | | | | | |
| Long-term Debt, net | | $ | 35,745 | | | $ | 38,537 | | | | | |
DEBT MATURITIES
AtAs of December 31, 2022 and 2021, Occidental’s significant equity investments consisted of investments in WES, OxyChem Ingleside Facility, Net Power and DEL.
As a result of a refinancing transaction at DEL in November 2021, Occidental received cash distributions comprised of $110 million in dividends and $450 million in excess distributions. Since Occidental may be requested to provide financial support to DEL in the future, the excess distributions were recorded against the carrying amount of the equity investment and in deferred credits and other liabilities - other. The $110 million in dividends were recorded as a return on investment in cash flow from operations and the $450 million excess distribution was recorded as a return of investment in cash flow from investing.
Equity investments in certain oil and gas properties and gathering and processing assets and associated notes payable were presented net on the Consolidated Balance Sheets. The notes payable were net settled in 2022. The carrying value of the investment and note payable were $2.9 billion as of December 31, 2021.
Dividends received from equity investments were $643 million, $652 million and $678 million to Occidental in 2022, 2021 and 2020, future principal payments on long-term debt aggregatedrespectively. As of December 31, 2022 and 2021, cumulative undistributed earnings of equity-method investees since they were acquired was $475 million and $242 million, respectively. As of December 31, 2022, Occidental’s investments in equity investees exceeded the underlying equity in net assets by approximately $35.2 billion,$640 million, of which, $398 million is due in 2021, $2.1 billion is due in 2022, $0.9 billion is due in 2023, $3.9 billion is due in 2024, and $27.9 billion is due in 2025 and thereafter.
| | | | | |
8878 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
$373 million represented PP&E and equity investments with the remainder comprised of intangibles, both are subject to amortization over their estimated average lives.
DEBT ISSUED, REPAID AND EXCHANGED - 2020
The following table summarizes Occidental’s debt issuances, repurchases, repayments and exchangespresents the summarized financial information of its equity-method investments combined for the twelve monthsyears ended and as of December 31, 2020:31:
| | | | | | | | |
millions | | Borrowings at face value |
Total borrowings at face value as of December 31, 2019 | | $ | 37,401 | |
Issuance of July 2020 notes: | | |
8.000% senior notes due 2025 | | 500 | |
8.500% senior notes due 2027 | | 500 | |
8.875% senior notes due 2030 | | 1,000 | |
July tender and purchase: | | |
4.100% senior notes due February 2021 | | (943) | |
Variable rate bonds due February 2021 | | (473) | |
4.850% senior notes due March 2021 | | (530) | |
2.600% senior notes due August 2021 | | (51) | |
Issuance of August 2020 notes: | | |
5.875% senior notes due 2025 | | 900 | |
6.375% senior notes due 2028 | | 600 | |
6.625% senior notes due 2030 | | 1,500 | |
August and September tender and purchase: | | |
4.100% senior notes due February 2021 | | (139) | |
Variable rate bonds due August 2021 | | (123) | |
2.600% senior notes due August 2021 | | (1,099) | |
Variable rate bonds due August 2022 | | (448) | |
2.600% senior notes due April 2022 | | (171) | |
2.700% senior notes due August 2022 | | (102) | |
2.700% senior notes due February 2023 | | (52) | |
August WES exchange: | | |
6.500% note payable to WES due 2038 | | (260) | |
September Term Loan repayment: | | |
2-year variable rate term loan due 2021 | | (500) | |
October Term Loan and note repayment: | | |
2-year variable rate bonds due August 2021 | | (377) | |
0.00% senior notes due October 2036 | | (2) | |
2-year variable rate term loan due September 2021 | | (1,010) | |
November Term Loan repayment: | | |
2-year variable rate term loan due September 2021 | | (232) | |
Issuance of December 2020 notes: | | |
5.500% senior notes due 2025 | | 750 | |
6.125% senior notes due 2031 | | 1,250 | |
December tender and purchase: | | |
2.600% senior notes due August 2021 | | (126) | |
3.125% senior notes due February 2022 | | (538) | |
2.600% senior notes due April 2022 | | (128) | |
2.700% senior notes due August 2022 | | (1,269) | |
2.700% senior notes due February 2023 | | (212) | |
December Term Loan and note repayment: | | |
2-year variable rate term loan due September 2021 | | (214) | |
4.100% senior notes due February 2021 | | (167) | |
Total borrowings at face value as of December 31, 2020 | | $ | 35,235 | |
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Summarized Results of Operations | | | | | | |
| Revenues and other income | | $ | 6,342 | | | $ | 6,252 | | | $ | 5,455 | |
| Costs and expenses | | 4,514 | | | 4,569 | | | 5,455 | |
| Net income | | $ | 1,828 | | | $ | 1,683 | | | $ | — | |
| | | | | | |
| Summarized Balance Sheet | | | | | | |
| Current assets | | $ | 3,482 | | | $ | 3,387 | | | $ | 1,419 | |
| Non-current assets | | $ | 15,282 | | | $ | 19,341 | | | $ | 18,693 | |
| Current liabilities | | $ | 1,342 | | | $ | 1,976 | | | $ | 1,549 | |
| Long-term debt | | $ | 9,512 | | | $ | 9,464 | | | $ | 7,860 | |
| Other non-current liabilities | | $ | 1,289 | | | $ | 1,187 | | | $ | 866 | |
| Stockholders’ equity | | $ | 6,621 | | | $ | 10,101 | | | $ | 9,837 | |
RELATED-PARTY TRANSACTIONS
Occidental sells oil, NGL, natural gas, chemicals, power and steam to and purchases oil, NGL and chemicals from its equity method investees and other related parties. Occidental is charged service fees primarily related to gathering, processing, oil, NGL and natural gas treatment by certain of its equity investees and other related parties. Berkshire Hathaway is a related party of Occidental due to its ownership of Occidental's common stock. Occidental has, from time to time, contracted with Berkshire Hathaway for the provision of electricity, rail and insurance. In addition, certain Berkshire Hathaway subsidiaries purchase various chemicals from our chemical segment. During 2022, 2021 and 2020, Occidental entered into the following related-party transactions and had the following amounts due from or to its related parties for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
Sales (a) | | $ | 337 | | | $ | 261 | | | $ | 301 | |
Purchases (b) | | $ | 948 | | | $ | 773 | | | $ | 1,112 | |
Services (c) | | $ | 1,006 | | | $ | 942 | | | $ | 1,101 | |
| Advances and amounts due from related parties | | $ | 40 | | | $ | 57 | | | $ | 62 | |
| Amounts due to related parties | | $ | 306 | | | $ | 280 | | | $ | 296 | |
(a)In 2022 and 2021 and 2020 sales of Occidental-produced oil and NGL to WES accounted for 42% and 58% and 70% of these totals, respectively.
(b)In 2022 and 2021 and 2020, purchases of gas and NGL marketed on behalf of WES accounted for 24% and 27% and 59% of related party purchases, respectively, while purchases of ethylene from the OxyChem Ingleside Facility accounted for 64% and 70% in 2022 and 2021 respectively, and, in 2020, for 41% of related party purchases.
(c)In 2022 and 2021 and 2020, services primarily related to fees charged by WES to gather, process and treat Occidental produced oil, NGL and natural gas. Excluded charges to WES for shared corporate services.
| | | | | |
OXY 20202022 FORM 10-K | 8979 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
| | |
| NOTE 5 - ACQUISITIONS, DIVESTITURES AND OTHER TRANSACTIONS |
ACQUISITIONS, DIVESTITURES AND OTHER TRANSACTIONS
2022
Throughout 2022, Occidental entered into non-monetary exchange agreements, primarily in the Permian Basin. These exchanges were recorded as acquisitions and divestitures at a total combined fair value of $340 million.
In 2022, Occidental acquired additional interests in emerging low-carbon businesses to advance net-zero pathway for a combined net purchase price of approximately $350 million.
In November 2022 and December 2022, Occidental acquired additional primarily producing assets in the Permian Basin for a combined net purchase price of approximately $400 million.
In November 2021, Occidental entered into an agreement to sell certain non-strategic assets in the Permian Basin. The transaction closed in January 2022 for net cash proceeds of approximately $190 million. The difference in the proved assets' net book value and adjusted purchase price was treated as a normal retirement, which resulted in no gain or loss being recognized. The difference in the unproved assets' net book value and adjusted purchase price resulted in a gain on sale of approximately $123 million. The gain has been presented within gains on sales of assets and equity investments, net in the Consolidated Statements of Operations.
2021
In November 2021, Occidental acquired additional working interests in certain assets in the Permian EOR business for a net purchase price of approximately $285 million.
In October 2021, Occidental closed the sale of its Ghana assets. See below discussion on Discontinued Operations for additional information. This divestiture completed Occidental's large-scale asset divestiture program.
In June 2021, Occidental entered into an agreement to sell certain non-strategic assets in the Permian Basin. The transaction closed in July August,2021 for net cash proceeds of approximately $475 million. The difference in the assets' net book value and adjusted purchase price was treated as a recovery of cost and normal retirement, which resulted in no gain or loss being recognized.
In March 2021, Occidental completed the sale of certain non-operated assets in the DJ Basin for net cash proceeds of approximately $280 million. The difference in the assets' net book value and adjusted purchase price was treated as a recovery of cost and normal retirement, which resulted in no gain or loss being recognized.
2020
In November 2020 and December 2020, Occidental issued $7.0 billiondivested of certain non-core, largely non-operated proved and unproved acreage in senior unsecured notes, in aggregate, with maturities ranging from 2025 to 2031 and used the net proceeds to tender $3.5 billion of 2021, $2.7 billion of 2022 and $264 million of 2023 maturities. In addition, Occidental used proceeds from the sale of mineral and surface acres located in Wyoming, Colorado and Utah; the Colombian asset sale and proceeds from other divestitures and cash on hand to repay $2.5 billion of 2021 and $2 million of 2036 maturities.
In August 2020, Occidental exchanged approximately 27.9 million WES common units to retirePermian for a $260 million note payable to WES, resulting in a net loss of $46 million, which includes a $76 million gain on debt extinguished associated with an unamortized premium on the note payable to WES. This net loss on exchange hasapproximately $820 million. The losses have been presented inwithin gains (losses) gains on sale of assets, net in the Consolidated Statement of Operations.
Interest on the notes issued in JulyIn October 2020, will be paid semi-annually on July 15 and January 15 of each year, commencing on January 15, 2021. Interest on the notes issued in August 2020 will be paid semi-annually on September 1 and March 1 of each year, commencing on March 1, 2021. Interest on the December 2025 notes issued in December 2020 will be paid semi-annually on June 1 and December 1 of each year, commencing on June 1, 2021. Interest on the January 2031 notes issued in December 2020 will be paid semi-annually on July 1 and January 1 of each year, commencing on July 1, 2021.
REVOLVING CREDIT FACILITY
In March 2020, Occidental amended the sole financial covenant in its RCF by revising the definition of “Total Capitalization” to exclude any non-cash write downs, impairments and related charges occurring after September 30, 2019.
On June 30, 2019, Occidental entered into an amendmentagreement to sell its existing $3.0onshore oil and gas Colombia assets. The transaction closed in December 2020, and Occidental recorded a loss on sale of approximately $353 million. The loss has been presented within gains (losses) on sale of assets, net in the Consolidated Statement of Operations.
In August 2020, Occidental entered into an agreement to sell approximately 4.5 million mineral acres and 1 million fee surface acres located in Wyoming, Colorado and Utah for approximately $1.33 billion. The transaction closed in October 2020 for net cash proceeds of approximately $1.0 billion, RCF pursuantafter satisfying $329 million of liabilities associated with the sale of future royalties. Occidental recorded a loss on sale of $440 million. The loss has been presented within gains (losses) on sale of assets, net in the Consolidated Statement of Operations.
DISCONTINUED OPERATIONS
In October 2021, Occidental closed the sale of its Ghana assets for $750 million and net proceeds of $555 million, after closing adjustments to which, among other things,reflect an April 1, 2021 effective date. In addition, Occidental settled certain tax claims related to historical operations in Ghana for $170 million. Prior to the commitments undersale, 2021 operations in Ghana resulted in an after-tax loss of $31 million.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
The following table presents the RCF were increasedamounts reported in discontinued operations, net of income taxes, related to $5.0 billion at the closingGhana assets for the years ended December 31, 2021 and 2020:
| | | | | | | | |
| millions | 2021 | 2020 |
| Revenues and other income | | |
| Net sales | $ | 458 | | $ | 419 | |
| | |
| Costs and other deductions | | |
| Oil and gas lease operating expense | 71 | | 117 | |
Fair value adjustment on assets held for sale (a) | 409 | | 2,263 | |
| Other | 24 | | 48 | |
| Total costs and other deductions | $ | 504 | | $ | 2,428 | |
| | |
| Income (loss) before income taxes | $ | (46) | | $ | (2,009) | |
| Income tax benefit (expense) | 15 | | 711 | |
| Discontinued operations, net of tax | $ | (31) | | $ | (1,298) | |
(a) For 2021, included effective date to close date adjustments as well as settlements of certain tax claims.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
As of December 31, 2022 and 2021, Occidental’s debt consisted of the Acquisition. Borrowings under the RCF bear interest at various benchmark rates, including LIBOR, plus a margin basedfollowing:
| | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | | | |
| 2.600% senior notes due 2022 | | — | | | 101 | | | | | |
| 2.700% senior notes due 2023 | | — | | | 442 | | | | | |
8.750% medium-term notes due 2023 (a) | | 22 | | | 22 | | | | | |
| 2.900% senior notes due 2024 | | 654 | | | 949 | | | | | |
| 6.950% senior notes due 2024 | | 291 | | | 650 | | | | | |
| 3.450% senior notes due 2024 | | 111 | | | 127 | | | | | |
| 8.000% senior notes due 2025 | | — | | | 500 | | | | | |
| 5.875% senior notes due 2025 | | 606 | | | 900 | | | | | |
| 3.500% senior notes due 2025 | | 137 | | | 326 | | | | | |
| 5.500% senior notes due 2025 | | 465 | | | 750 | | | | | |
| 5.550% senior notes due 2026 | | 870 | | | 1,100 | | | | | |
| 3.200% senior notes due 2026 | | 182 | | | 797 | | | | | |
| 3.400% senior notes due 2026 | | 284 | | | 779 | | | | | |
| 7.500% debentures due 2026 | | 112 | | | 112 | | | | | |
| 8.500% senior notes due 2027 | | 489 | | | 500 | | | | | |
| 3.000% senior notes due 2027 | | 216 | | | 634 | | | | | |
| 7.125% debentures due 2027 | | 150 | | | 150 | | | | | |
| 7.000% debentures due 2027 | | 48 | | | 48 | | | | | |
| 6.625% debentures due 2028 | | 14 | | | 14 | | | | | |
| 7.150% debentures due 2028 | | 232 | | | 235 | | | | | |
| 7.200% senior debentures due 2028 | | 82 | | | 82 | | | | | |
| 6.375% senior notes due 2028 | | 578 | | | 600 | | | | | |
| 7.200% debentures due 2029 | | 135 | | | 135 | | | | | |
| 7.950% debentures due 2029 | | 116 | | | 116 | | | | | |
| 8.450% senior debentures due 2029 | | 116 | | | 116 | | | | | |
| 3.500% senior notes due 2029 | | 286 | | | 1,477 | | | | | |
| Variable rate bonds due 2030 (5.32% and 0.900% as of December 31, 2022 and 2021, respectively) | | 68 | | | 68 | | | | | |
| 8.875% senior notes due 2030 | | 1,000 | | | 1,000 | | | | | |
| 6.625% senior notes due 2030 | | 1,449 | | | 1,500 | | | | | |
| 6.125% senior notes due 2031 | | 1,143 | | | 1,250 | | | | | |
| 7.500% senior notes due 2031 | | 900 | | | 900 | | | | | |
| 7.875% senior notes due 2031 | | 500 | | | 500 | | | | | |
| 6.450% senior notes due 2036 | | 1,727 | | | 1,750 | | | | | |
| Zero Coupon senior notes due 2036 | | 673 | | | 2,269 | | | | | |
| 4.300% senior notes due 2039 | | 247 | | | 693 | | | | | |
| 7.950% senior notes due 2039 | | 325 | | | 325 | | | | | |
| 6.200% senior notes due 2040 | | 737 | | | 750 | | | | | |
| 4.500% senior notes due 2044 | | 191 | | | 608 | | | | | |
| 4.625% senior notes due 2045 | | 296 | | | 634 | | | | | |
| 6.600% senior notes due 2046 | | 1,117 | | | 1,157 | | | | | |
| 4.400% senior notes due 2046 | | 424 | | | 976 | | | | | |
| 4.100% senior notes due 2047 | | 258 | | | 663 | | | | | |
| (continued on next page) | | | | | | | | |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
| | | | | | | | | | | | | | | | | | |
| millions (continued) | | 2022 | | 2021 | | | | |
| 4.200% senior notes due 2048 | | 304 | | | 961 | | | | | |
| 4.400% senior notes due 2049 | | 280 | | | 704 | | | | | |
| 7.730% debentures due 2096 | | 58 | | | 58 | | | | | |
| 7.500% debentures due 2096 | | 60 | | | 60 | | | | | |
| 7.250% debentures due 2096 | | 5 | | | 5 | | | | | |
| Total borrowings at face value | | $ | 17,958 | | | $ | 28,493 | | | | | |
| Adjustments to book value: | | | | | | | | |
| Unamortized premium, net | | 1,261 | | | 670 | | | | | |
| Debt issuance costs | | (73) | | | (135) | | | | | |
| Net book value of debt | | $ | 19,146 | | | $ | 29,028 | | | | | |
| Long-term finance leases | | 546 | | | 504 | | | | | |
| Current finance leases | | 143 | | | 85 | | | | | |
| Total debt and finance leases | | $ | 19,835 | | | $ | 29,617 | | | | | |
| Less current maturities of financing leases | | (143) | | | (85) | | | | | |
| Less current maturities of long-term debt | | (22) | | | (101) | | | | | |
| Long-term debt, net | | $ | 19,670 | | | $ | 29,431 | | | | | |
(a) The 8.750% senior notes due 2023 were repaid in January 2023.
DEBT MATURITIES
As of December 31, 2022, future principal payments on Occidental’s senior debt ratings. The facility has similar terms to other debt agreementswere less than $18.0 billion, of which, $22 million is due in 2023, $1.1 billion is due in 2024, $1.2 billion is due in 2025, $1.4 billion is due in 2026, and does not contain material adverse change clauses or debt ratings triggers that could restrict Occidental’s ability to borrow, or that would permit lenders to terminate their commitments or accelerate debt repayment. The facility provides for the termination of loan commitments$14.2 billion is due in 2027 and requires immediate repayment of any outstanding amounts if certain events of default occur. Occidental has not drawn down any amounts under the RCF. In 2020, Occidental paid average annual facility fees of 0.275% on the total commitment amount.thereafter.
ZERO COUPON NOTES DUE 2036COUPONS
The Zero Coupons have an aggregate principal amount due at the 2036 maturity of approximately $2.3 billion, reflecting an accretion rate of 5.24%.$673 million. The Zero Coupons can be put to Occidental in October of each year, in whole or in part, for the then-accreted value of the outstanding Zero Coupons. The Zero Coupons can next be put to Occidental in October 2021,2023, which, if put in whole, would be $1.0 billion$344 million at such date. Occidental currently has the ability to meet this obligation and intent to refinance these obligationsmay use available capacity under the RCF or other committed facilities.
DEBT GUARANTEES
As of December 31, 2020, and 2019, Occidental had provided limited recourse guarantees of approximately $242 million, primarily related to Dolphin Energy Limited’s debt, which are limited to certain political and other events.satisfy the put should it be exercised.
FAIR VALUE OF DEBT
Occidental estimates the fair value of fixed-rate debt based on the quoted market prices for those instruments or on quoted market yields for similarly rated debt instruments, taking into account such instruments’ maturities. The estimated fair values of Occidental’s debt atas of December 31, 2020,2022, and 2019, substantially all2021, the majority of which were classified as Level 1, were approximately $33.8$17.6 billion and $38.8$31.1 billion, respectively. Occidental’s exposure to changes in interest rates relates primarily to its variable-rate, long-term debt obligations, and is not material. As of December 31, 2020,2022 and 2019,2021, variable-rate debt constituted approximately 3%0.4% and 12%0.2% of Occidental’s total debt, respectively.
DEBT RATINGS
In connection with the Senior Notes Offerings, Occidental's long-term debt credit ratings were reviewed by the three major rating agencies. As of December 31, 2020,2022, Occidental’s long-term debt was rated BBBB+ by Fitch Ratings, Ba2Ba1 by Moody’s Investors Service and BB-BB+ by Standard and Poor’s. Any additional downgrade in credit ratings could impact Occidental's ability to access capital markets and increase its cost of capital. In addition, given that Occidental’s current debt ratings are non-investment grade, Occidental may be requested, and in some cases required, to provide collateral in the form of cash, letters of credit, surety bonds or other acceptable support as financial assurance of its performance and payment obligations under certain contractual arrangements such as pipeline transportation contracts, environmental remediation obligations, oil and gas purchase contracts and certain derivative instruments.
As of the date of this filing, Occidental hashad provided required financial assurances through a combination of cash, letters of credit and surety bonds and hashad not issued any letters of credit under the RCF or other committed facilities. For additional information, see Risk Factors in Part I, Item IA of this Form 10-K.
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90 | OXY 20202022 FORM 10-K | 83 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
DEBT ACTIVITY
| | |
NOTE 8 - LEASE COMMITMENTS |
For the twelve months ended December 31, 2022, Occidental repaid debt with a face value of more than $10.5 billion, reducing the face value of Occidental’s debt to less than $18.0 billion. The net book value of the full year repayments was $9.8 billion, which resulted in a gain of $149 million.For the twelve months ended December 31, 2021, Occidental repaid debt with a face value of $6.7 billion, reducing the face value of Occidental’s debt to $28.5 billion. The net book value of the full year repayments was $6.8 billion which resulted in a loss of $118 million.
Occidental identifies leases through its accounts payable and contract monitoring process. Since the adoption of ASC 842, operating lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. The ROU assets include the discounted obligation in addition to any upfront payments or costs incurred during the contract execution of the lease and amortized on a straight-line basis over the course of the lease term. Except for leases with explicitly defined contract terms, Occidental utilizes judgment to assess likelihood of renewals, terminations and purchase options, in order to determine the lease term. Occidental uses the incremental borrowing rate at commencement date to determine the present value of lease payments. The incremental borrowing rate equates to the rate of interest that Occidental would have to pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Certain leases include variable lease payments which are over and above the minimum lease liability used to derive the ROU asset and lease liability and are based on the underlying asset’s operations. These variable lease costs are reported in the lease cost classification table.DEBT ACTIVITY - 2022
Occidental’s operating lease agreements include lease liability for oil and gas exploration and development equipment, including offshore and onshore drilling rigs of $45 million, compressors of $140 million, storage facilities of $253 million, office space $406 million and other field equipment of $57 million, which are recorded gross on the Consolidated Balance Sheet and in the lease cost disclosures below. Contract expiration terms generally range from two to eight years. Further, actual expenditures are netted against joint-interest recoveries on the income statement through the normal joint-interest billing process. Occidental’s leases also include pipelines, rail cars, easements, aircraft and real estate of $213 million, which typically are not associated with joint-interest recoveries. Real estate and rail cars leases have contract expiration terms ranging from one to 13 years.
Occidental’s finance lease agreements include leases for oil and gas exploration and development equipment, as well as real estate offices, compressors and field equipment of approximately $358 million. The following table presents lease balances and their location onsummarizes Occidental’s debt activity for the Consolidated Balance Sheet atyear ended December 31, 2020 and 2019:2022:
| | | | | | | | | | | | | | | | | |
| millions | | Balance sheet location | 2020 | | 2019 |
| Assets: | | | | | |
| Operating | | Operating lease assets | $ | 1,062 | | | $ | 1,411 | |
| Finance | | Property, plant and equipment | 365 | | | 397 | |
| Total lease assets | | | $ | 1,427 | | | $ | 1,808 | |
| | | | | |
| Liabilities: | | | | | |
| Current | | | | | |
| Operating | | Current operating lease liabilities | $ | 473 | | | $ | 579 | |
| Finance | | Current maturities of long-term debt | 42 | | | 51 | |
| Non-current | | | | | |
| Operating | | Deferred credits and other liabilities - Operating lease liabilities | 641 | | | 872 | |
| Finance | | Long-term debt, net | 316 | | | 347 | |
| Total lease liabilities | | | $ | 1,472 | | | $ | 1,849 | |
At December 31, 2020, Occidental’s leases expire based on the following schedule:
| | | | | | | | | | | | | | | | | | | | |
| millions | | Operating Leases (a) | | Finance Leases (b) | | Total |
| 2021 | | $ | 456 | | | $ | 44 | | | $ | 500 | |
| 2022 | | 182 | | | 43 | | | 225 | |
| 2023 | | 108 | | | 41 | | | 149 | |
| 2024 | | 87 | | | 46 | | | 133 | |
| 2025 | | 71 | | | 30 | | | 101 | |
| Thereafter | | 385 | | | 231 | | | 616 | |
| Total lease payments | | 1,289 | | | 435 | | | 1,724 | |
| Less: Interest | | (175) | | | (77) | | | (252) | |
| Total lease liabilities | | $ | 1,114 | | | $ | 358 | | | $ | 1,472 | |
(a)The weighted-average remaining lease term is 6.2 years and the weighted-average discount rate is 4.73%.
(b)The weighted-average remaining lease term is 10.6 years and the weighted-average discount rate is 3.47%.
| | | | | | | | |
| millions | FINANCIAL STATEMENTS
FOOTNOTES
| Borrowings at face value |
| Total borrowings at face value as of December 31, 2021 | | $ | 28,493 | |
| Repayments: | | |
| 2.600% senior notes due 2022 | | $ | (101) | |
| 2.700% senior notes due 2023 | | (442) | |
| 6.950% senior notes due 2024 | | (359) | |
| 3.450% senior notes due 2024 | | (16) | |
| 2.900% senior notes due 2024 | | (295) | |
| 3.500% senior notes due 2025 | | (189) | |
| 8.000% senior notes due 2025 | | (500) | |
| 5.875% senior notes due 2025 | | (294) | |
| 5.500% senior notes due 2025 | | (285) | |
| 5.550% senior notes due 2026 | | (230) | |
| 3.200% senior notes due 2026 | | (615) | |
| 3.400% senior notes due 2026 | | (495) | |
| 3.000% senior notes due 2027 | | (418) | |
| 8.500% senior notes due 2027 | | (11) | |
| 7.150% debentures due 2028 | | (3) | |
| 6.375% senior notes due 2028 | | (22) | |
| 3.500% senior notes due 2029 | | (1,191) | |
| 6.625% senior notes due 2030 | | (51) | |
| 6.125% senior notes due 2031 | | (107) | |
| 6.450% senior notes due 2036 | | (23) | |
| Zero Coupon senior notes due 2036 | | (1,596) | |
| 4.300% senior notes due 2039 | | (446) | |
| 6.200% senior notes due 2040 | | (13) | |
| 4.500% senior notes due 2044 | | (417) | |
| 4.625% senior notes due 2045 | | (338) | |
| 6.600% senior notes due 2046 | | (40) | |
| 4.400% senior notes due 2046 | | (552) | |
| 4.100% senior notes due 2047 | | (405) | |
| 4.200% senior notes due 2048 | | (657) | |
| 4.400% senior notes due 2049 | | (424) | |
| Total borrowings at face value as of December 31, 2022 | | $ | 17,958 | |
The following tables present Occidental’s total lease cost and classifications, as well as cash paid for amounts included in the measurement of operating and finance lease liabilities for the years ended December 31:
| | | | | | | | |
| millions | | |
Lease cost classification (a) | 2020 | 2019 |
Operating lease costs (b) | | |
| Property, plant and equipment, net | $ | 197 | | $ | 449 | |
| Operating expense and cost of sales | 557 | | 391 | |
| Selling, general and administrative expenses | 107 | | 92 | |
| Finance lease cost | | |
| Amortization of ROU assets | 29 | | 19 | |
| Interest on lease liabilities | 14 | | 2 | |
| Total lease cost | $ | 904 | | $ | 953 | |
(a)Amounts reflected are gross before joint-interest recoveries.
(b)Included short-term lease cost of $207 million and $404 million and variable lease cost of $95 million and $162 million for the years ended December 31, 2020 and 2019, respectively.
| | | | | | | | |
| | |
| millions | 2020 | 2019 |
| Operating cash flows | $ | 506 | | $ | 262 | |
| Investing cash flows | $ | 89 | | $ | 112 | |
Financing cash flows (a) | $ | 29 | | $ | 19 | |
OBJECTIVE AND STRATEGY
Occidental uses a variety of derivative financial instruments and physical contracts to manage its exposure to commodity price fluctuations, interest rate risks and transportation commitments and to fix margins on the future sale of stored commodity volumes. Occidental also enters into derivative financial instruments for trading purposes.
Occidental may elect normal purchases and normal sales exclusions when physically delivered commodities are purchased or sold to a customer. Occidental occasionally applies cash flow hedge accounting treatment to derivative financial instruments to lock in margins on the forecasted sales of its natural gas storage volumes, and at times for other strategies, such as to lock rates on forecasted debt issuances. Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty. See Note 1 - Summary of Significant Accounting Policies for Occidental’s accounting policy on derivatives.
DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
As of December 31, 2020, Occidental’s derivatives not designated as hedges consist of oil call options, natural gas collars, interest rate swaps and marketing derivatives.
Derivative instruments that are derivatives not designated as hedging instruments are required to be recorded on the balance sheet at fair value. Changes in fair value will impact Occidental’s earnings through mark-to-market adjustments until the physical commodity is delivered or the financial instrument is settled. The fair value does not reflect the realized or cash value of the instrument.
COLLARS AND OIL CALL OPTIONS
In 2019, Occidental entered into 2020 Brent-priced 3-way collars combined with 2021 call options on the same volume to manage its near-term exposure to cash flow variability from oil price risks in 2020. The 2021 call options were sold to enhance the upside retention in 2020. In 2020, management elected to hedge a portion of Occidental’s expected 2021 natural gas production to enhance cash flow stability. The majority of the collars settled in 2020 with the receipt of cash of $960 million. The remaining $52 million settled in 2021.The 2021 call options were entered into to substantially improve the terms for the ceiling price that Occidental received for the contracted commodity volumes in 2020.
In September, 2020, Occidental entered into natural gas two-way collar derivative instruments for 2021 to manage its near-term exposure to cash flow variability from natural gas price risk. A two-way collar is a combination of two options: a
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9284 | OXY 20202022 FORM 10-K |
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| | FINANCIAL STATEMENTS FOOTNOTES | |
DEBT ACTIVITY - 2021
sold call and a purchased put. The sold call establishes the ceiling price that Occidental will receivefollowing table summarizes Occidental’s debt activity for the contracted commodity volume for a defined period of time. The purchased put establishes the floor price that Occidental will receive for the contracted volumes. Net gains and losses associated with collars and calls are recognized currently in net sales.
Occidental had the following collars and calls outstanding atyear ended December 31, 2020:2021:
| | | | | | | | |
| millions | | Borrowings at face value |
| Total borrowings at face value as of December 31, 2020 | | $ | 35,235 | |
Collars and Calls, not designated as hedgesActivity: | | |
| 4.850% senior notes due 2021 | | 2021 Settlement - oil$ | (147) | |
Call options sold (MMbbl)Variable rate bonds due 2021 | | 127.8(27) | |
| 2.600% senior notes due 2021 | | Average price per barrel (Brent oil pricing)(224) | |
| 3.125% senior notes due 2022 | | (276) | |
| 2.700% senior notes due 2022 | | (629) | |
| Floating interest rate notes due August 2022 | | (1,052) | |
| 2.700% senior notes due 2023 | | (484) | |
| 3.450% senior notes due 2024 | | (121) | |
| 2.900% senior notes due 2024 | | (2,051) | |
| 3.500% senior notes due 2025 | | (424) | |
| 3.400% senior notes due 2026 | | (371) | |
| 3.200% senior notes due 2026 | | (203) | |
| 3.000% senior notes due 2027 | | (116) | |
| 3.500% senior notes due 2029 | | (23) | |
| 4.300% senior notes due 2039 | | (57) | |
| 4.500% senior notes due 2044 | | (17) | |
| 4.625% senior notes due 2045 | | (116) | |
| 6.600% senior notes due 2046 | | 57 | |
| 4.400% senior notes due 2046 | | (224) | |
| 4.100% senior notes due 2047 | | (87) | |
| 4.200% senior notes due 2048 | | (39) | |
| 4.400% senior notes due 2049 | | (46) | |
| 7.730% debentures due 2096 | | (3) | |
| 7.500% debentures due 2096 | | (18) | |
| 7.250% debentures due 2096 | | (44) | |
| | |
| | |
Ceiling sold price (call)Total borrowings at face value as of December 31, 2021 | | $ | 74.16 | |
| | | | |
2021 Settlement - natural gas | | |
Natural Gas Collars (millions of MMbtu) | | 177.0 |
| Volume weighted average price per MMbtu (NYMEX) | | |
| | Ceiling sold price (call) | | $ | 3.64 | |
| | Floor purchased price (put) | | $ | 2.5028,493 | |
INTEREST RATE SWAPS
Occidental acquired interest rate swap contracts in the Acquisition. The contracts lock in a fixed interest rate in exchange for a floating interest rate indexed to three-month London Inter-Bank Offered Rate (LIBOR) throughout the reference period. Net gains and losses associated with interest rate derivative instruments not designated as hedging instruments are recognized currently in gains (losses) on interest rate swaps and warrants, net.
Occidental had the following outstanding interest rate swaps at December 31, 2020:
| | | | | | | | | | | | | | | | | | | | | | | |
| millions except percentages | | | | Mandatory | | Weighted-Average |
| Notional Principal Amount | | Reference Period | | Termination Date | | Interest Rate |
| $ | 400 | | | | September 2016 - 2046 | | September 2021 | | 6.348 | % |
| $ | 350 | | | | September 2017 - 2047 | | September 2021 | | 6.662 | % |
| $ | 275 | | | | September 2016 - 2046 | | September 2022 | | 6.709 | % |
| $ | 450 | | | | September 2017 - 2047 | | September 2023 | | 6.445 | % |
| | | | | | | |
| | | | | | | |
In December 2021, Occidental entered into the Second Amended and Restated Credit Agreement in which the total committed borrowing capacity of $4.0 billion is based on a SOFR benchmark. The interest rate margin and the facility fee rates are subject to adjustments based on Occidental’s performance on specified sustainability target thresholds with respect to absolute reductions in GHG emissions from its worldwide operated assets. The RCF maturity date is June 30, 2025.
Borrowings under the RCF bear interest at SOFR benchmark rates, plus a margin based on Occidental’s senior debt ratings. The facility has similar terms to other debt agreements and does not contain material adverse change clauses or debt ratings triggers that could restrict Occidental’s ability to borrow, or that would permit lenders to terminate their commitments or accelerate debt repayment. The facility provides for the termination of loan commitments and requires immediate repayment of any outstanding amounts if certain events of default occur. As of the date of this filing, Occidental had no drawn amounts under the RCF. In 2022, Occidental paid average annual facility fees of 0.302% on the total commitment amount.
Depending on market conditions, liability management actions or other factors,RECEIVABLES SECURITIZATION FACILITY
In December 2021, Occidental may enter into offsetting interest rate swap positions or settle or amend certain or allamended and extended its existing receivables securitization facility to December 2024. As of December 31, 2022, the currently outstanding interest rate swaps. Occidental settled interest rate swaps with a notional valuefacility had $400 million of $125 million in October 2019. In the first quarter of 2020, Occidental extended all 2020 mandatory termination datesavailable borrowing capacity and no drawn amounts. Subsequent to 2021 or thereafter.
Derivative settlements and collateralization are classified as cash flows from operating activities unless the derivatives contain an other-than-insignificant financing element, in which case the settlements and collateralization are classified as cash flows from financing activities. Due to the liability position of the interest rate derivatives atDecember 31, 2022, but before the date of this filing, Occidental amended the Acquisition,facility to expand its available borrowing capacity to $600 million. The amended facility includes adjustments based on the interest rate derivatives in Occidental’s portfolio contain an other-than-insignificant financing element, and therefore, any settlements, collateralization or cash payments related to interest rate derivatives are classifiedsame specified sustainability target thresholds as cash flow from financing activities. Net cash payments related to settlements were $93 million for the twelve months ended December 31, 2020. Collateral with respect to interest rate swap agreements was paidcontained in the amount of $270 million for the twelve months ended December 31, 2020.RCF.
MARKETING DERIVATIVES
Occidental’s marketing derivative instruments not designated as hedges are short-duration physical and financial forward contracts. A substantial majority of Occidental’s physically settled derivative contracts are index-based and carry no mark-to-market valuation in earnings. These instruments settle at a weighted-average contract price of $46.05 per barrel and $2.58 per Mcf for oil and natural gas, respectively, at December 31, 2020. The weighted-average contract price was $60.60 per barrel and $2.17 per Mcf for oil and natural gas, respectively, at December 31, 2019. Net gains and losses associated with marketing derivative instruments not designated as hedging instruments are recognized currently in net sales.
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| | FINANCIAL STATEMENTS FOOTNOTES | |
The following table summarizes net long/(short) volumes associated with the outstanding marketing commodity derivatives not designated as hedging instruments as of December 31, 2020, and 2019:
| | | | | | | | | | | | | | |
| | |
| | 2020 | | 2019 |
| Oil Commodity Contracts | | | | |
| Volume (MMbbl) | | (31) | | | 55 | |
| | | | |
| Natural gas commodity contracts | | | | |
| Volume (Bcf) | | (117) | | | (128) | |
THE BERKSHIRE WARRANTS
Warrants for 80 million shares of Occidental stock, with an initial exercise price of $62.50, were issued in connection with the financing of the Acquisition (the Berkshire Warrants). The Berkshire Warrants are exercisable at the holder’s option, in whole or in part, until the first anniversary of the date on which no shares of Preferred Stock remain outstanding, at which time the Berkshire Warrants expire. The holders of the Berkshire Warrants could have required net cash settlement if certain shareholder and regulatory approvals to issue shares of Occidental’s common stock underlying the Berkshire Warrants were not obtained. Prior to these approvals, the fair value of the Berkshire Warrants was remeasured each reporting date with gains and losses being recorded on the income statement.
At Occidental’s May 29, 2020 annual shareholders meeting, all remaining approvals were obtained and the Berkshire Warrants can no longer be cash settled. Upon these approvals, the fair value of the Berkshire Warrants was remeasured at May 29, 2020, using the Black-Scholes option model. The reclassification from liabilities to “Additional paid-in capital” was $103 million.
The following inputs were used in the Black-Scholes option model: the expected life of the Berkshire Warrants, a volatility factor and the exercise price. The expected life is based on the estimated term of the Berkshire Warrants, the volatility factor is based on historical volatilities of Occidental common stock and the initial exercise price of $62.50.
The Berkshire Warrants contain an anti-dilution provision that adjusts the exercise price and the number of shares of Occidental’s common stock issuable on exercise upon the occurrence of certain distributions to common shareholders. On June 26, 2020, Occidental’s Board of Directors declared a distribution to its common shareholders of warrants to purchase additional shares of common stock, See Note 13 - Stockholders’ Equity. This distribution to common shareholders resulted in an anti-dilution adjustment to the Berkshire Warrants, which lowered its exercise price to $59.624 and increased the number of shares of Occidental’s common stock issuable on exercise of the Berkshire Warrants by approximately 3.9 million shares.
DERIVATIVES DESIGNATED AS HEDGING INSTRUMENTS
Net gains and losses attributable to derivative instruments subject to cash flow hedge accounting reside in accumulated other comprehensive loss and are reclassified to earnings as the transactions to which the derivatives relate, primarily interest expense on debt issued to partially finance the Acquisition, are recognized in earnings.
FAIR VALUE OF DERIVATIVES
Occidental has categorized its assets and liabilities that are measured at fair value in a three-level fair value hierarchy, based on the inputs to the valuation techniques: Level 1 – using quoted prices in active markets for the assets or liabilities; Level 2 – using observable inputs other than quoted prices for the assets or liabilities; and Level 3 – using unobservable inputs. Transfers between levels, if any, are reported at the end of each reporting period. The following table presents the fair values of Occidental’s outstanding derivatives. Fair values are presented at gross amounts below, including when derivatives are subject to netting arrangements, and are presented on a net basis in the Consolidated Balance Sheets.
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| FINANCIAL STATEMENTS
FOOTNOTES
| |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | Fair Value Measurements Using | | | | Total Fair Value |
| Balance Sheet Classification | | Level 1 | | Level 2 | | Level 3 | | Netting (a) | |
| December 31, 2020 | | | | | | | | | | |
| Collars and Calls | | | | | | | | | | |
| Other current assets | | $ | 0 | | | $ | 25 | | | $ | 0 | | | $ | 0 | | | $ | 25 | |
| Accrued liabilities | | 0 | | | (42) | | | 0 | | | 0 | | | (42) | |
| Marketing Derivatives | | | | | | | | | | |
| Other current assets | | 1,155 | | | 80 | | | 0 | | | (1,204) | | | 31 | |
| Long-term receivables and other assets, net | | 7 | | | 2 | | | 0 | | | (7) | | | 2 | |
| Accrued liabilities | | (1,252) | | | (81) | | | 0 | | | 1,204 | | | (129) | |
| Deferred credits and other liabilities - other | | (7) | | | 0 | | | 0 | | | 7 | | | 0 | |
| Interest Rate Swaps | | | | | | | | | | |
| Accrued liabilities | | 0 | | | (936) | | | 0 | | | 0 | | | (936) | |
| Deferred credits and other liabilities - other | | 0 | | | (822) | | | 0 | | | 0 | | | (822) | |
| | | | | | | | | | |
| December 31, 2019 | | | | | | | | | | |
| Collars and Calls | | | | | | | | | | |
| Other current assets | | $ | 0 | | | $ | 92 | | | $ | 0 | | | $ | 0 | | | $ | 92 | |
| Deferred credits and other liabilities - other | | 0 | | | (160) | | | 0 | | | 0 | | | (160) | |
| Marketing Derivatives | | | | | | | | | | |
| Other current assets | | 945 | | | 79 | | | 0 | | | (973) | | | 51 | |
| Long-term receivables and other assets, net | | 4 | | | 12 | | | 0 | | | (4) | | | 12 | |
| Accrued liabilities | | (1,008) | | | (44) | | | 0 | | | 973 | | | (79) | |
| Deferred credits and other liabilities - other | | (4) | | | (1) | | | 0 | | | 4 | | | (1) | |
| Interest Rate Swaps | | | | | | | | | | |
| Other current assets | | 0 | | | 5 | | | 0 | | | 0 | | | 5 | |
| Long-term receivables and other assets, net | | 0 | | | 5 | | | 0 | | | 0 | | | 5 | |
| Accrued liabilities | | 0 | | | (657) | | | 0 | | | 0 | | | (657) | |
| Deferred credits and other liabilities - other | | 0 | | | (776) | | | 0 | | | 0 | | | (776) | |
| Berkshire Warrants | | | | | | | | | | |
| Deferred credits and other liabilities - other | | 0 | | | (107) | | | 0 | | | 0 | | | (107) | |
(a)These amounts do not include collateral. As of December 31, 2020, $374 million of collateral has been netted against derivative liabilities related to interest rate swaps. Occidental had $85 million and $65 million of initial margin deposited with brokers as of December 31, 2020 and 2019, respectively, related to marketing derivatives.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
GAINS AND LOSSES ON DERIVATIVES
The following table presents gains and (losses) related to Occidental’s derivative instruments on the Consolidated Statements of Operations:
| | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | | | December 31, |
| Income Statement Classification | | | | | | 2020 | | 2019 | | 2018 |
| | | | | | | | | | |
| Collars and Calls | | | | | | | | | | |
| Net sales | | | | | | $ | 1,064 | | | $ | (107) | | | $ | 0 | |
| Marketing Derivatives | | | | | | | | | | |
Net sales (a) | | | | | | (393) | | | 1,804 | | | 2,254 | |
| Interest Rate Swaps (Excluding WES) | | | | | | | | | | |
| Gains (losses) on interest rate swaps and warrants, net | | | | | | (428) | | | 122 | | | 0 | |
Other (b) | | | | | | | | | | |
| Gains on interest rate swaps and warrants, net | | | | | | 5 | | | 111 | | | 0 | |
(a)Includes derivative and non-derivative marketing activity.
(b)Primarily includes losses and gains on Berkshire Warrants prior to the May 29, 2020 reclassification to equity.
CREDIT RISK
The majority of Occidental’s counterparty credit risk is related to the physical delivery of energy commodities to its customers and their inability to meet their settlement commitments. Occidental manages credit risk by selecting counterparties that it believes to be financially strong, by entering into netting arrangements with counterparties and by requiring collateral or other credit risk mitigants, as appropriate. Occidental actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. Occidental also enters into futures contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk as a significant portion of these transactions settle on a daily margin basis.
Certain of Occidental’s OTC derivative instruments contain credit-risk-contingent features, primarily tied to credit ratings for Occidental or its counterparties, which may affect the amount of collateral that each party would need to post. The aggregate fair value of derivative instruments with credit-risk-contingent features for which a net liability position existed at December 31, 2020 was $104 million (net of $374 million collateral), primarily related to acquired interest rate swaps, and $787 million (net of $169 million of collateral) existed at December 31, 2019.
| | |
NOTE 107 - ENVIRONMENTAL LIABILITIES AND EXPENDITURESLEASE COMMITMENTS |
Occidental identifies leases through its accounts payable and contract monitoring processes. Lease assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. Lease assets include the lease liability, upfront payments and costs incurred to execute the lease and are amortized on a straight-line basis over the lease term. Occidental assesses the likelihood of exercising renewal, termination and purchase options to determine the lease term. Occidental uses its incremental borrowing rate at commencement date to determine the present value of lease payments. The incremental borrowing rate is the rate of interest that Occidental would pay to borrow an amount equal to the lease payments over a similar term on a collateralized basis in a similar economic environment. Certain leases include variable lease payments based on the underlying asset’s operations that are not included in the lease asset and liability.
Occidental has operating leases for oil and gas exploration and development equipment, including office space of $352 million, offshore and onshore drilling rigs of $169 million, compressors of $113 million and $60 million consisting of storage facilities and other field equipment. Operating lease terms generally range from one to eight years. Operating leases also include pipelines, rail cars, easements, aircraft and real estate of $236 million. These operating leases have contract expiration terms ranging from one to 10 years.
Occidental’s operations are subject to stringent federal, state, localfinance leases include compressors of $378 million, real estate offices of $266 million and international laws$45 million consisting of drilling rigs, vehicles and regulations related to improving or maintaining environmental quality. The laws that require or address environmental remediation, including CERCLA and similar federal, state, local and international laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership or control of sites. OPC or certain of its subsidiaries participate in or actively monitor a range of remedial activities and government or private proceedings under these laws with respect to alleged past practices at operating, closed and third-party sites. Remedial activities may include one or more of the following: investigation involving sampling, modeling, risk assessment or monitoring; cleanup measures including removal, treatment or disposal; or operation and maintenance of remedial systems. The environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties, injunctive relief and government oversight costs.aircraft leases.
ENVIRONMENTAL REMEDIATIONThe following table presents lease balances and their classification on the Consolidated Balance Sheets as of December 31:
| | | | | | | | | | | | | | | | | |
| millions | | Balance sheet classification | 2022 | | 2021 |
| Assets: | | | | | |
| Operating | | Operating lease assets | $ | 903 | | | $ | 726 | |
| Finance | | Property, plant and equipment | 686 | | | 581 | |
| Total lease assets | | | $ | 1,589 | | | $ | 1,307 | |
| Liabilities: | | | | | |
| Current | | | | | |
| Operating | | Current operating lease liabilities | $ | 273 | | | $ | 186 | |
| Finance | | Current maturities of long-term debt | 143 | | | 85 | |
| Non-current | | | | | |
| Operating | | Deferred credits and other liabilities - Operating lease liabilities | 657 | | | 585 | |
| Finance | | Long-term debt, net | 546 | | | 504 | |
| Total lease liabilities | | | $ | 1,619 | | | $ | 1,360 | |
As of December 31, 2020, Occidental participated in or monitored remedial activities or proceedings at 170 sites. 2022, Occidental’s outstanding lease payments, excluding variable component, consisted of the following:
| | | | | | | | | | | | | | | | | | | | |
| millions | | Operating Leases (a) | | Finance Leases (b) | | Total |
| 2023 | | $ | 287 | | | $ | 146 | | | $ | 433 | |
| 2024 | | 226 | | | 109 | | | 335 | |
| 2025 | | 108 | | | 95 | | | 203 | |
| 2026 | | 89 | | | 84 | | | 173 | |
| 2027 | | 81 | | | 66 | | | 147 | |
| Thereafter | | 250 | | | 277 | | | 527 | |
| Total lease payments | | 1,041 | | | 777 | | | 1,818 | |
| Less: Interest | | (111) | | | (88) | | | (199) | |
| Total lease liabilities | | $ | 930 | | | $ | 689 | | | $ | 1,619 | |
(a)The following table presents Occidental’s current and non-current environmental remediation liabilities as of December 31, 2020 and 2019, the current portion of whichweighted-average remaining lease term is included in accrued liabilities ($123 million in 2020 and $162 million in 2019)5.4 years and the remainder in deferred creditsweighted-average discount rate is 3.84%.
(b)The weighted-average remaining lease term is 7.7 years and other liabilities - environmental remediation liabilities ($1.03 billion in 2020 and $1.04 billion in 2019).
Occidental’s environmental remediation sites are grouped into four categories: NPL sites listed or proposed for listing by the EPA on the CERCLA NPL and three categories of non-NPL sites — third-party sites, Occidental-operated sites and closed or non-operated Occidental sites.weighted-average discount rate is 3.05%.
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| | FINANCIAL STATEMENTS FOOTNOTES | |
The following tables present Occidental’s total lease cost classifications for operating and finance lease liabilities for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 2020 | | 2019 |
| millions, except number of sites | | Number of Sites | | Remediation Balance | | Number of Sites | | Remediation Balance |
| NPL sites | | 35 | | | $ | 447 | | | 36 | | | $ | 463 | |
| Third-party sites | | 69 | | | 293 | | | 74 | | | 311 | |
| Occidental-operated sites | | 17 | | | 144 | | | 17 | | | 154 | |
| Closed or non-operated Occidental sites | | 49 | | | 267 | | | 50 | | | 269 | |
| Total | | 170 | | | $ | 1,151 | | | 177 | | | $ | 1,197 | |
| | | | | | | | |
| millions | | |
Lease cost classification (a) | 2022 | 2021 |
Operating lease costs (b) | | |
| Property, plant and equipment, net | $ | 246 | | $ | 222 | |
| Operating expense and cost of sales | 234 | | 487 | |
| Selling, general and administrative expenses | 78 | | 109 | |
| Finance lease cost | | |
| Amortization of ROU assets | 83 | | 39 | |
| Interest on lease liabilities | 20 | | 13 | |
| Total lease cost | $ | 661 | | $ | 870 | |
As (b)Included short-term lease cost of December 31, 2020, Occidental’s environmental liabilities exceeded $10 million each at 19 of the 170 sites described above, and 96 of the sites had liabilities from $0 to $1 million each. As of December 31, 2020, 2 sites — the Diamond Alkali Superfund Site and a former chemical plant in Ohio (both of which are indemnified by Maxus Energy Corporation, as discussed further below) — accounted for 92% of its liabilities associated with NPL sites. 17 of the 35 NPL sites are indemnified by Maxus.
NaN of the 69 third-party sites — a Maxus-indemnified chrome site in New Jersey, a former copper mining and smelting operation in Tennessee, a former oil field and a landfill in California and an active refinery in Louisiana where Occidental reimburses the current owner for certain remediation activities — accounted for 76% of Occidental’s liabilities associated with these sites. 9 of the 69 third-party sites are indemnified by Maxus.
NaN sites — oil and gas operations in Colorado and chemical plants in Kansas, Louisiana, New York and Texas — accounted for 70% of the liabilities associated with the Occidental-operated sites. NaN other sites — a landfill in Western New York, a former refinery in Oklahoma, former chemical plants in California, Michigan, Tennessee and Washington and a closed coal mine in Pennsylvania — accounted for 70% of the liabilities associated with closed or non-operated Occidental sites.
Environmental remediation liabilities vary over time depending on factors such as acquisitions or divestitures, identification of additional sites and remedy selection and implementation. Occidental recorded environmental remediation expenses of $36 million, $112$184 million and $47$238 million and variable lease cost of $101 million and $120 million for the years ended December 31, 2020, 2019,2022 and 2018,2021, respectively. Environmental remediation expenses primarily relate to changes to existing conditions from past operations. Based on current estimates, Occidental expects to expend funds corresponding to approximately 45% of the year-end remediation balance over the next three to four years with the remainder over the subsequent 10 or more years. Occidental believes its range of reasonably possible additional losses beyond those amounts currently recorded for environmental remediation for all of its environmental sites could be up to $1.1 billion.
MAXUS ENVIRONMENTAL SITES
When Occidental acquired Diamond Shamrock Chemicals Company (DSCC) in 1986, Maxus agreed to indemnify OccidentalThe following tables present Occidental’s total cash paid for a number of environmental sites, including the Diamond Alkali Superfund Site (Site) along a portion of the Passaic River. On June 17, 2016, Maxusoperating and several affiliated companies filed for Chapter 11 bankruptcy in Federal District Court in the State of Delaware. Prior to filing for bankruptcy, Maxus defended and indemnified Occidental in connection with clean-up and other costs associated with the sites subject to the indemnity, including the Site.
In March 2016, the EPA issued a Record of Decision (ROD) specifying remedial actions requiredfinance lease liabilities for the lower 8.3 miles of the Lower Passaic River. The ROD does not address any potential remedial action for the upper 9 miles of the Lower Passaic River or Newark Bay. During the third quarter of 2016, and following Maxus’s bankruptcy filing, Occidental and the EPA entered into an Administrative Order on Consent (AOC) to complete the design of the proposed clean-up plan outlined in the ROD at an estimated cost of $165 million. The EPA announced that it will pursue similar agreements with other potentially responsible parties.years ended December 31
Occidental has accrued a reserve relating to its estimated allocable share of the costs to perform the design and remediation called for in the AOC and the ROD, as well as for certain other Maxus-indemnified sites. Occidental's accrued estimated environmental reserve does not consider any recoveries for indemnified costs. Occidental’s ultimate share of this liability may be higher or lower than the reserved amount and is subject to final design plans and the resolution of Occidental's allocable share with other potentially responsible parties. Occidental continues to evaluate the costs to be incurred to comply with the AOC, the ROD and to perform remediation at other Maxus-indemnified sites in light of the Maxus bankruptcy and the share of ultimate liability of other potentially responsible parties. In June 2018, Occidental filed a complaint under CERCLA in Federal District Court in the State of New Jersey against numerous potentially responsible parties for reimbursement of amounts incurred or to be incurred to comply with the AOC, the ROD, or to perform other remediation activities at the Site.
In June 2017, the court overseeing the Maxus bankruptcy approved a Plan of Liquidation (Plan) to liquidate Maxus and create a trust to pursue claims against current and former parents YPF and each of its respective subsidiaries and affiliates (YPF) and Repsol, S.A. and each of its respective subsidiaries and affiliates (Repsol), as well as others to satisfy claims by Occidental and other creditors for past and future cleanup and other costs. In July 2017, the court-approved Plan became final and the trust became effective. The trust is pursuing claims against YPF, Repsol and others and is expected to
| | | | | | | | |
| millions | 2022 | 2021 |
| Operating cash flows | $ | 211 | | $ | 401 | |
| Investing cash flows | $ | 81 | | $ | 73 | |
| Financing cash flows | $ | 83 | | $ | 39 | |
| | | | | |
OXY 20202022 FORM 10-K | 9787 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
distribute assets to Maxus' creditors in accordance with the trust agreement and Plan. In June 2018, the trust filed its complaint against YPF and Repsol in Delaware bankruptcy court asserting claims based upon, among other things, fraudulent transfer and alter ego. During 2019, the bankruptcy court denied Repsol's and YPF's motions to dismiss the complaint as well as their motions to move the case away from the bankruptcy court. Discovery remains ongoing at the time of this report.
| | |
NOTE 118 - LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIESDERIVATIVES |
LEGAL MATTERSOBJECTIVE AND STRATEGY
Occidental uses a variety of derivative financial instruments and physical contracts to manage its exposure to commodity price fluctuations, transportation commitments and to fix margins on the future sale of stored commodity volumes. Occidental also enters into derivative financial instruments for trading purposes. Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty.
Occidental may elect normal purchases and normal sales exclusions when physically delivered commodities are purchased or certainsold to a customer. Occidental occasionally applies cash flow hedge accounting treatment to derivative financial instruments to lock in margins on the forecasted sales of its subsidiaries are involved, in the normal coursenatural gas storage volumes. The value of business, in lawsuits, claims and other legal proceedings that seek, among other things, compensationcash flow hedges was insignificant for alleged personal injury, breachall periods presented. See Note 1 - Summary of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. Occidental or certainSignificant Accounting Policies for Occidental’s accounting policy on derivatives.
DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
As of its subsidiaries also are involved in proceedings under CERCLA and similar federal, state, local and foreign environmental laws. These environmental proceedings seek funding or performanceDecember 31, 2022, Occidental’s derivatives not designated as hedges consisted of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties and injunctive relief. Usually Occidental or such subsidiaries are among many companies in these environmental proceedings and have to date been successful in sharing response costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or disposed assets with respect to which a third party or Occidental retains liability or indemnifies the other party for conditions that existedmarketing derivatives. All interest rate swaps were settled prior to December 31, 2022.
Derivative instruments that are not designated as hedging instruments are required to be recorded on the transaction.balance sheet at fair value. Changes in fair value will impact Occidental’s earnings through mark-to-market adjustments until the physical commodity is delivered or the financial instrument is settled.
In accordance with applicable accounting guidance, Occidental accrues reserves
MARKETING DERIVATIVES
Occidental’s marketing derivative instruments not designated as hedges are short-duration physical and financial forward contracts. A substantial majority of Occidental’s physically settled derivative contracts are index-based and carry no mark-to-market valuation in earnings. As of December 31, 2022, the weighted-average settlement price of these forward contracts was $81.37/Bbl and $7.89/Mcf for outstanding lawsuits, claimscrude oil and proceedings when it is probable that a liability has been incurrednatural gas, respectively. The weighted-average settlement price was $74.85/Bbl and the liability can be reasonably estimated. Reserves$4.61/Mcf for matters, other than for environmental remediation, that satisfy this criteriacrude oil and natural gas, respectively, as of December 31, 20202021. Net gains and 2019, werelosses associated with marketing derivative instruments not material to Occidental’s Consolidated Balance Sheets.designated as hedging instruments are recognized currently in net sales.
In 2016, Occidental received payments from the Republic of Ecuador of approximately $1.0 billion pursuant to a November 2015 arbitration award for Ecuador’s 2006 expropriation of Occidental’s Participation Contract for Block 15. The awarded amount represented a recovery of 60% of the value of Block 15. In 2017, Andes Petroleum Ecuador Ltd. (Andes) filed a demand for arbitration, claiming it is entitled to a 40% share of the judgment amount obtained by Occidental. Occidental contends that Andes is not entitled to any of the amounts paid under the 2015 arbitration award because Occidental’s recovery was limited to Occidental’s own 60% economic interest in the block. The merits hearing occurred in September 2020 and an arbitration decision is expected within the next six months.
In August 2019, Sanchez Energy Corporation and certain of its affiliates (Sanchez) filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code. Sanchez is a party to agreements with Anadarko as a result of its 2017 purchase of Anadarko's Eagle Ford Shale assets. Sanchez is attempting to reject some of the agreements related to the purchase of Anadarko’s Eagle Ford Shale assets. If Sanchez is permitted to reject certain of those agreements, then Anadarko may owe deficiency payments to various third parties. Occidental intends to defend vigorously any attempt by Sanchez to reject the agreements. Occidental expects a ruling on Sanchez's purported contract rejection in the first half of 2021.
On May 26, 2020, a putative securities class action captioned City of Sterling Heights General Employees’ Retirement System, et al. v. Occidental Petroleum Corporation, et al., No. 651994/2020 (City of Sterling), was filed in the Supreme Court of the State of New York. The complaint asserts claims under Sections 11, 12 and 15 of the Securities Act of 1933, as amended (the Securities Act), based on alleged misstatements in the Securities Act filings, including the registration statement filed in connectionfollowing table summarizes net short volumes associated with the Anadarko Acquisition and Occidental’s related issuanceoutstanding marketing commodity derivatives not designated as hedging instruments as of common stock and debt securities offerings that took place in August 2019. The lawsuit was filed against Occidental, certain current and former officers and directors and certain underwriters of the debt securities offerings and seeks damages in an unspecified amount, plus attorneys’ fees and expenses. Two additional putative class actions were filed in the same court (together with City of Sterling, the State Cases) and the State Cases were consolidated into In re Occidental Petroleum Corporation Securities Litigation, No. 651830/2020. Occidental intends to vigorously defend itself in all respects in regard to the State Cases.
The ultimate outcome and impact of outstanding lawsuits, claims and proceedings on Occidental cannot be predicted. Management believes that the resolution of these matters will not, individually or in the aggregate, have a material adverse effect on Occidental’s Consolidated Balance Sheets. If unfavorable outcomes of these matters were to occur, future results of operations or cash flows for any particular quarterly or annual period could be materially adversely affected. Occidental’s estimates are based on information known about the legal matters and its experience in contesting, litigating and settling similar matters. Occidental reassesses the probability and estimability of contingent losses as new information becomes available.December 31:
TAX MATTERS | | | | | | | | | | | | | | |
| | |
| | 2022 | | 2021 |
| Oil commodity contracts | | | | |
| Volume (MMbbl) | | (33) | | | (28) | |
| | | | |
| Natural gas commodity contracts | | | | |
| Volume (Bcf) | | (112) | | | (136) | |
During
INTEREST RATE SWAPS
Occidental retired all remaining outstanding interest rate swaps in the coursetwelve months ended December 31, 2022. Occidental's interest rate swap contracts locked in a fixed interest rate in exchange for a floating interest rate indexed to the three-month LIBOR throughout the reference period. Net gains and losses associated with interest rate swaps and warrants, were recognized currently in gains (losses) on interest rate swaps, net in the Consolidated Statements of Operations.
Interest rate swaps and collateralization are classified as cash flows from financing activities. For the twelve months ended December 31, 2022, the interest rate swaps were terminated through the application of $144 million of collateral and cash payments of $255 million. Prior to termination, Occidental paid $35 million of periodic settlements and $179 million of collateral was returned.
FAIR VALUE OF DERIVATIVES
Occidental has categorized its operations, Occidental isassets and liabilities that are measured at fair value in a three-level fair value hierarchy, based on the inputs to the valuation techniques: Level 1 – using quoted prices in active markets for the assets or liabilities; Level 2 – using observable inputs other than quoted prices for the assets or liabilities; and Level 3 – using unobservable inputs. Transfers between levels, if any, are reported at the end of each reporting period. The following table presents the fair values of Occidental’s outstanding derivatives. Fair values are presented at gross amounts below, including when derivatives are subject to audit by tax authorities for varying periodsnetting arrangements, and are presented on a net basis in various federal, state, local and foreign tax jurisdictions. Taxable years through 2017 for U.S. federal income tax purposes have been audited by the U.S. Internal Revenue Service (IRS) pursuant to its Compliance Assurance Program and subsequent taxable
Consolidated Balance Sheets. | | | | | |
9888 | OXY 20202022 FORM 10-K |
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| | FINANCIAL STATEMENTS FOOTNOTES | |
years are currently under review. Taxable years through 2009 have been audited for state income tax purposes. All other significant audit matters in foreign jurisdictions have been resolved through 2010. During the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law. Occidental believes that the resolution of outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations.
For Anadarko, its taxable years through 2014 and tax year 2016 for U.S. federal and state income tax purposes have been audited by the IRS and respective state taxing authorities. There are outstanding significant audit matters in one foreign jurisdiction. As stated above, during the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law. Other than the matter discussed below, Occidental believes that the resolution of these outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations.
Anadarko received an $881 million tentative refund in 2016 related to its $5.2 billion Tronox Adversary Proceeding settlement payment in 2015. In September 2018, Anadarko received a statutory notice of deficiency from the IRS disallowing the net operating loss carryback and rejecting Anadarko’s refund claim. As a result, Anadarko filed a petition with the U.S. Tax Court to dispute the disallowances in November 2018. The case was in the IRS appeals process until the second quarter of 2020, however it has since been returned to the U.S. Tax Court where Occidental expects to continue pursuing resolution.
In accordance with ASC 740’s guidance on the accounting for uncertain tax positions, Occidental has recorded no tax benefit on the tentative cash tax refund of $881 million. As a result, should Occidental not ultimately prevail on the issue, there would be no additional tax expense recorded relative to this position for financial statement purposes other than future interest. However, in that event Occidental would be required to repay approximately $925 million ($898 million in federal taxes and $27 million in state taxes) plus accrued interest of approximately $255 million. A liability for this amount plus interest is included in deferred credits and other liabilities-other.
INDEMNITIES TO THIRD PARTIES | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | Fair Value Measurements Using | | | | Total Fair Value |
| Balance Sheet Classification | | Level 1 | | Level 2 | | Level 3 | | Netting (a) | |
| December 31, 2022 | | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| Marketing Derivatives | | | | | | | | | | |
| Other current assets | | $ | 920 | | | $ | 127 | | | $ | — | | | $ | (980) | | | $ | 67 | |
| Long-term receivables and other assets, net | | 1 | | | 2 | | | — | | | (1) | | | 2 | |
| Accrued liabilities | | (938) | | | (96) | | | — | | | 980 | | | (54) | |
| Deferred credits and other liabilities - other | | (1) | | | (1) | | | — | | | 2 | | | — | |
| | | | | | | | | | |
| December 31, 2021 | | | | | | | | | | |
| Marketing Derivatives | | | | | | | | | | |
| Other current assets | | $ | 1,516 | | | $ | 173 | | | $ | — | | | $ | (1,645) | | | $ | 44 | |
| Long-term receivables and other assets, net | | 4 | | | 1 | | | — | | | (4) | | | 1 | |
| Accrued liabilities | | (1,608) | | | (196) | | | — | | | 1,645 | | | (159) | |
| Deferred credits and other liabilities - other | | (4) | | | — | | | — | | | 4 | | | — | |
| Interest Rate Swaps | | | | | | | | | | |
| Accrued liabilities | | — | | | (315) | | | — | | | — | | | (315) | |
| Deferred credits and other liabilities - other | | — | | | (436) | | | — | | | — | | | (436) | |
| | | | | | | | | | |
| | | | | | | | | | |
Occidental, its subsidiaries, or both, have indemnified various parties against specified liabilities those parties might incur in the future in connection with purchases and other transactions that they have entered into with Occidental. (a)These indemnities usually are contingent upon the other party incurring liabilities that reach specified thresholds.amounts do not include collateral. As of December 31, 2020,2021, $323 million of collateral related to interest rate swaps had been netted against derivative liabilities. Occidental is not awarenetted $15 million and $110 million of circumstances that it believes would reasonably be expectedcollateral deposited with brokers against derivative liabilities related to lead to indemnity claims that would result in payments materially in excessmarketing derivatives as of reserves.
PURCHASE OBLIGATIONS AND COMMITMENTS
Occidental, its subsidiaries, or both, have entered into agreements providing for future payments, primarily to secure terminal and pipeline capacity, and also for drilling rigs and services, electrical power, steam and certain chemical raw materials. Occidental has certain other commitments under contracts, guarantees and joint ventures, including purchase commitments for goods and services at market-related prices and certain other contingent liabilities. At December 31, 2020, total purchase obligations were $13.2 billion, which included approximately $2.8 billion in 2021, $4.4 billion in 2022, and 2023, $3.0 billion in 2024 and 2025, and $3.0 billion in 2026 and thereafter.
GAINS AND LOSSES ON DERIVATIVES
The following table presents gains and (losses) related to Occidental’s derivative instruments in the Consolidated Statements of Operations for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | | | |
| Income Statement Classification | | | | | | 2022 | | 2021 | | 2020 |
| | | | | | | | | | |
Collars and Calls(a) | | | | | | | | | | |
| Net sales | | | | | | $ | — | | | $ | (344) | | | $ | 1,064 | |
| Marketing Derivatives | | | | | | | | | | |
Net sales (b) | | | | | | 381 | | | 338 | | | (393) | |
| Interest Rate Swaps | | | | | | | | | | |
| Gains (losses) on interest rate swaps and warrants, net | | | | | | 317 | | | 122 | | | (428) | |
(a)All of Occidental’s collars and calls expired on or before December 31, 2021.
(b)Includes derivative and non-derivative marketing activity.
CREDIT RISK
The majority of Occidental’s counterparty credit risk is related to the physical delivery of energy commodities to its customers and their inability to meet their settlement commitments. Occidental manages credit risk by selecting counterparties that it believes to be financially strong, by entering into netting arrangements with counterparties and by requiring collateral or other credit risk mitigants, as appropriate. Occidental actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. Occidental also enters into futures contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk, if any.
Certain of Occidental’s OTC derivative instruments contain credit-risk-contingent features, primarily tied to credit ratings for Occidental or its counterparties, which may affect the amount of collateral that each party would need to post. The aggregate fair value of derivative instruments with credit-risk-contingent features for which a net liability position existed as of December 31, 2022 was $18 million. The aggregate fair value of derivative instruments with credit-risk-contingent features for which a net liability position existed as of December 31, 2021 was $107 million (net of $323 million of collateral), which was primarily related to interest rate swaps.
| | | | | |
OXY 20202022 FORM 10-K | 9989 |
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| | FINANCIAL STATEMENTS FOOTNOTES | |
| | |
NOTE 129 - FAIR VALUE MEASUREMENTS |
FAIR VALUES – NONRECURRING
There were no significant non-recurring fair value measurements during the year ended December 31, 2022.
For the year ended December 31, 2021, Occidental recorded pre-tax impairments of $276 million related to undeveloped leases that either expired or were set to expire in the near-term, where Occidental had no plans to pursue exploration activities.
The table below summarizes the significant impairments and other charges incurred to measure assets to their fair value on a nonrecurring basis throughout the year ended December 31, 2020:
| | | | | | | | |
| millions | | Total Fair Value |
| Asset impairments and other charges | | |
| Goodwill | | $ | 1,153 | |
| Oil and gas properties - proved | | $ | 2,436 | |
| Oil and gas properties - unproved | | $ | 4,591 | |
| Oil and gas properties - discontinued operations | | $ | 2,191 | |
| WES equity investment | | $ | 2,673 | |
GOODWILL
In the first quarter of 2020, Occidental impaired $1.2 billion in goodwill related to Occidental’s ownership in WES, which was previously included in long-term receivables and other assets, net. The market value of WES’ publicly traded units is considered a Level 1 input.
OIL AND GAS PROPERTIES
In the second quarter of 2020, as a result of the expected prolonged period of lower commodity prices brought on by the COVID-19 pandemic’s impact on oil demand, Occidental tested substantially all of its oil and gas assets for impairment. Occidental recognized total pre-tax impairments to its oil and gas proved and unproved properties of $8.6 billion, of which $6.4 billion was included in oil and gas segment results and $2.2 billion ($1.4 billion net of tax) related to Ghana was included in discontinued operations.
In the second quarter of 2020, Occidental recorded proved property pre-tax impairments of $1.2 billion primarily related to certain assets for its domestic onshore and Gulf of Mexico assets and $0.9 billion to adjust the Algeria oil and gas proved properties to their fair value. The fair value of the proved properties was measured based on the income approach.
Unproved property pre-tax impairments of $4.3 billion were primarily related to domestic onshore unproved acreage. The fair value of this acreage was measured based on a market approach using an implied acreage valuation derived from domestic onshore market participants excluding the fair value assigned to proved properties.
Income approaches are considered Level 3 fair value estimates and include significant assumptions of future production and timing of production, commodity price assumptions and operating and capital cost estimates, discounted using a 10 percent weighted average cost of capital. Taxes were based on current statutory rates. Future production and timing of production is based on internal reserves estimates and internal economic models for a specific oil and gas asset. Internal reserve estimates consist of proved reserves and unproved reserves, the latter adjusted for uncertainty based on reserve category. Price assumptions were based on a combination of market information and published industry resources adjusted for historical differentials. Price assumptions ranged from approximately $40 per barrel of oil in 2020 increasing to approximately $70 per barrel of oil in 2034, with an unweighted arithmetic average price of $59.17 and $62.42 for WTI and Brent indexed assets for the 15 year period, respectively. Natural gas prices ranged from approximately $2.00 per Mcf in 2020 to approximately $3.60 per Mcf in 2034, with an unweighted arithmetic average price of $3.13 for NYMEX based assets for the 15 year period. Both oil and natural gas commodity prices were held flat after 2034 and were adjusted for location and quality differentials. Operating and capital cost estimates were based on current observable costs and were further escalated 1 percent in every period where commodity prices exceeded $50 per barrel and 2 percent in every period where commodity prices exceeded $60 per barrel. The weighted average cost of capital is calculated based on industry peers and best approximates the cost of capital an external market participant would expect to obtain.
In the first quarter of 2020, Occidental's oil and gas segment recognized pre-tax impairment and related charges of $581 million primarily related to both proved and unproved oil and gas properties and a lower of cost or net realizable value adjustment for crude inventory. Occidental recorded proved property impairments of $293 million related to certain international assets and the Gulf of Mexico. Occidental recorded unproved property impairments, of approximately $241 million, primarily related to domestic onshore undeveloped leases and offshore Gulf of Mexico where Occidental no
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
longer intends to pursue exploration, appraisal or development activities primarily due to the reduction in near-term capital plans.
If there is an adverse downturn of the macroeconomic conditions and if such downturn is expected to or does persist for a prolonged period of time, Occidental’s oil and gas properties may be subject to further testing for impairment, which could result in additional non-cash asset impairments. Such impairments could be material to the financial statements.
WES EQUITY INVESTMENT
At the end of the third quarter of 2020, Occidental recorded an other-than-temporary impairment of $2.7 billion, as the fair value of Occidental’s investment in WES had remained significantly lower than its book value for the majority of the nine months ended September 30, 2020. Occidental concluded that the difference between the fair value and book value of WES was not temporary, primarily given both the magnitude and the duration that the fair value was below its book value. This other-than-temporary impairment was calculated based on the closing market price of WES as of September 30, 2020. The market value of WES’ publicly traded common units is considered a Level 1 input.
FINANCIAL INSTRUMENTS FAIR VALUE
The carrying amounts of cash, cash equivalents, restricted cash, restricted cash equivalents and other on-balance sheet financial instruments, other than fixed-rate debt, approximate fair value. See Note 6 - Long-Term Debt for the fair value of long-term debt.
LEGAL ENTITY REORGANIZATION
To align Occidental’s legal entity structure with the nature of its business activities after completing the acquisition of Anadarko and subsequent large scale post-acquisition divestiture program, management undertook a legal entity reorganization that was completed in the first quarter of 2022.
As a result of this legal entity reorganization, management made an adjustment to the tax basis in a portion of its operating assets, thus reducing Occidental’s deferred tax liabilities. Accordingly, in 2022, Occidental recorded a tax benefit of $2.7 billion in connection with this reorganization. The timing of any reduction in Occidental’s future cash taxes as a result of this legal entity reorganization will be dependent on a number of factors, including prevailing commodity prices, capital activity level and production mix. The legal entity reorganization transaction is currently under IRS review as part of the Company’s 2022 federal tax audit.
INFLATION REDUCTION ACT
In August 2022, Congress passed the Inflation Reduction Act that contains, among other provisions, a corporate book minimum tax on financial statement income, an excise tax on stock buybacks, a methane emissions fee and certain tax incentives related to climate change and clean energy. Occidental is currently evaluating the provisions of this act. The ultimate impact of the Inflation Reduction Act to Occidental will depend on a number of factors including future commodity prices, interpretations and assumptions as well as additional regulatory guidance.
The following summarizes domestic and foreign components of income (loss) from continuing operations before domestic and foreign income taxes for the years ended December 31:
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Domestic | Domestic | | $ | (15,322) | | | $ | (1,632) | | | $ | 3,431 | | Domestic | | $ | 11,314 | | | $ | 1,966 | | | $ | (15,322) | |
| Foreign | Foreign | | (383) | | | 1,986 | | | 2,177 | | Foreign | | 2,803 | | | 1,739 | | | (383) | |
| Total | Total | | $ | (15,705) | | | $ | 354 | | | $ | 5,608 | | Total | | $ | 14,117 | | | $ | 3,705 | | | $ | (15,705) | |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
The following summarizes components of income tax expense (benefit) on continuing operations for the years ended December 31:
| | millions | millions | | 2020 | | 2019 | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Current | Current | | Current | |
| Federal | Federal | | $ | (126) | | | $ | 33 | | | $ | (23) | | Federal | | $ | 1,272 | | | $ | 173 | | | $ | (126) | |
| State and Local | | 6 | | | 46 | | | 52 | | |
| State and local | | State and local | | 105 | | | 36 | | | 6 | |
| Foreign | Foreign | | 465 | | | 1,809 | | | 1,077 | | Foreign | | 1,080 | | | 660 | | | 465 | |
| Total current tax expense | Total current tax expense | | $ | 345 | | | $ | 1,888 | | | $ | 1,106 | | Total current tax expense | | $ | 2,457 | | | $ | 869 | | | $ | 345 | |
| Deferred | Deferred | | Deferred | |
| Federal | Federal | | (2,384) | | | (130) | | | 422 | | Federal | | (1,569) | | | 191 | | | (2,384) | |
| State and Local | | (103) | | | 17 | | | 12 | | |
| State and local | | State and local | | (57) | | | (153) | | | (103) | |
| Foreign | Foreign | | (30) | | | (914) | | | (63) | | Foreign | | (18) | | | 8 | | | (30) | |
| Total deferred tax expense (benefit) | Total deferred tax expense (benefit) | | $ | (2,517) | | | $ | (1,027) | | | $ | 371 | | Total deferred tax expense (benefit) | | $ | (1,644) | | | $ | 46 | | | $ | (2,517) | |
| Total income tax expense (benefit) | Total income tax expense (benefit) | | $ | (2,172) | | | $ | 861 | | | $ | 1,477 | | Total income tax expense (benefit) | | $ | 813 | | | $ | 915 | | | $ | (2,172) | |
The following reconciliation of the U.S federal statutory income tax rate to Occidental’s worldwide effective tax rate on income from continuing operations for the years ended December 31 is stated as a percentage of income (loss) from continuing operations before income taxes:
| | | 2020 | | 2019 | | 2018 | | 2022 | | 2021 | | 2020 |
| U.S. federal statutory tax rate | U.S. federal statutory tax rate | | 21 | % | | 21 | % | | 21 | % | U.S. federal statutory tax rate | | 21 | % | | 21 | % | | 21 | % |
| Legal entity reorganization | | Legal entity reorganization | | (18) | | | — | | | — | |
| Enhanced oil recovery credit and other general business credits | Enhanced oil recovery credit and other general business credits | | 0 | | | (2) | | | (3) | | Enhanced oil recovery credit and other general business credits | | — | | | (3) | | | — | |
| Goodwill impairment | Goodwill impairment | | (3) | | | 0 | | | 0 | | Goodwill impairment | | — | | | — | | | (3) | |
| Tax benefit due to reversal of indefinite reinvestment assertion | | 0 | | | 0 | | | (2) | | |
| Capital loss | | Capital loss | | — | | | (2) | | | — | |
| Tax impact from foreign operations | Tax impact from foreign operations | | (4) | | | 135 | | | 11 | | Tax impact from foreign operations | | 3 | | | 8 | | | (4) | |
| State income taxes, net of federal benefit | State income taxes, net of federal benefit | | 0 | | | 14 | | | 1 | | State income taxes, net of federal benefit | | — | | | (2) | | | — | |
| Uncertain tax positions | | 0 | | | 7 | | | 0 | | |
| Transaction costs | | 0 | | | 10 | | | 0 | | |
| Non-controlling interest | | 0 | | | (8) | | | 0 | | |
| Executive compensation limitation | | 0 | | | 12 | | | 0 | | |
| Stock warrants | | 0 | | | (5) | | | 0 | | |
| WES loss of control | | 0 | | | 58 | | | 0 | | |
| | Other | Other | | 0 | | | 1 | | | (2) | | Other | | — | | | 3 | | | — | |
| Worldwide effective tax rate | Worldwide effective tax rate | | 14 | % | | 243 | % | | 26 | % | Worldwide effective tax rate | | 6 | % | | 25 | % | | 14 | % |
In 2020,2022, Occidental’s worldwide effective tax rate was 6%, which was lower than the U.S. statutory rate of 21% and primarily driven by a tax benefit associated with Occidental's legal entity reorganization, as described above, partially offset by higher tax rates in the foreign jurisdictions in which Occidental operates.
In 2021, Occidental’s worldwide effective tax rate was 14%25%, which was largely a result higher than the U.S. statutory rate of 21% due to higher tax rates in the impairment of the WES goodwill and certain international assets forforeign jurisdictions in which Occidental received nooperates, partially offset by the tax benefitimpact of business credits, state tax revaluations and higher-taxed foreign operations which generally caused Occidental’sother domestic tax rate to vary significantly from the U.S. corporate tax rate.benefits.
| | | | | |
10092 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
The tax effects of temporary differences resulting in deferred income taxes atas of December 31, 2020, and 2019 were as follows:31:
| | millions | millions | | 2020 | | 2019 | millions | | 2022 | | 2021 |
| Deferred tax liabilities | Deferred tax liabilities | | Deferred tax liabilities | |
| Property, plant and equipment differences | Property, plant and equipment differences | | $ | (10,744) | | | $ | (12,375) | | Property, plant and equipment differences | | $ | (7,218) | | | $ | (9,905) | |
| Equity investments, partnerships and foreign subsidiaries | | (658) | | | (989) | | |
| Equity investments, partnerships and international subsidiaries | | Equity investments, partnerships and international subsidiaries | | (441) | | | (571) | |
| Gross long-term deferred tax liabilities | Gross long-term deferred tax liabilities | | (11,402) | | | (13,364) | | Gross long-term deferred tax liabilities | | (7,659) | | | (10,476) | |
| | Deferred tax assets | Deferred tax assets | | Deferred tax assets | |
| Environmental reserves | Environmental reserves | | 257 | | | 261 | | Environmental reserves | | 229 | | | 242 | |
| Postretirement benefit accruals | Postretirement benefit accruals | | 398 | | | 441 | | Postretirement benefit accruals | | 235 | | | 285 | |
| Deferred compensation and benefits | Deferred compensation and benefits | | 186 | | | 266 | | Deferred compensation and benefits | | 207 | | | 286 | |
| Asset retirement obligations | Asset retirement obligations | | 942 | | | 906 | | Asset retirement obligations | | 799 | | | 850 | |
| Foreign tax credit carryforwards | Foreign tax credit carryforwards | | 4,465 | | | 4,379 | | Foreign tax credit carryforwards | | 3,622 | | | 3,904 | |
| General business credit carryforwards | General business credit carryforwards | | 607 | | | 443 | | General business credit carryforwards | | 30 | | | 698 | |
| Net operating loss carryforward | Net operating loss carryforward | | 1,797 | | | 692 | | Net operating loss carryforward | | 1,058 | | | 1,628 | |
| Interest expense carryforward | Interest expense carryforward | | 668 | | | 492 | | Interest expense carryforward | | 11 | | | 28 | |
| All other | All other | | 720 | | | 782 | | All other | | 771 | | | 689 | |
| Gross long-term deferred tax assets | Gross long-term deferred tax assets | | 10,040 | | | 8,662 | | Gross long-term deferred tax assets | | 6,962 | | | 8,610 | |
| Valuation allowance | Valuation allowance | | $ | (5,695) | | | $ | (4,959) | | Valuation allowance | | (4,785) | | | (5,136) | |
| Net long-term deferred tax assets | Net long-term deferred tax assets | | $ | 4,345 | | | $ | 3,703 | | Net long-term deferred tax assets | | $ | 2,177 | | | $ | 3,474 | |
| Total deferred income taxes, net | | $ | (7,057) | | | $ | (9,661) | | |
| Total deferred income tax liability, net | | Total deferred income tax liability, net | | $ | (5,482) | | | $ | (7,002) | |
| Less: foreign deferred tax asset in long-term receivables and other assets, net | Less: foreign deferred tax asset in long-term receivables and other assets, net | | $ | (56) | | | $ | (56) | | Less: foreign deferred tax asset in long-term receivables and other assets, net | | (30) | | | (37) | |
| Total deferred income taxes | | $ | (7,113) | | | $ | (9,717) | | |
| Total deferred income tax liability, gross | | Total deferred income tax liability, gross | | $ | (5,512) | | | $ | (7,039) | |
Total deferred tax assets, after valuation allowances, were $4.3were $2.2 billion and $3.7$3.5 billion as of December 31, 2020,2022 and 2019,2021, respectively. Occidental expects to realize the recorded deferred tax assets, net of any allowances, through future operating income and reversal of temporary differences. The total deferred tax liabilities were $11.4$7.7 billion and $13.4 $10.5 billion as of December 31, 20202022 and 2019,2021, respectively. The decrease in the net deferred tax liability in 2020 over 2019 is2022 compared to 2021 was primarily driven by domestic asset impairments for which Occidental does not receive an immediatea tax benefit associated with Occidental's legal entity reorganization, as well as an increase indescribed above, partially offset by the utilization of net operating loss carryforwards.losses and other tax attributes.
As of December 31, 2020,2022, Occidental had foreign tax credit carryforwards of $4.5$3.6 billion federal general business credits carryforwards of $607 million andand state tax credit carryforwards of $39$30 million. Occidental hashad recorded a valuation allowance for $4.4for $3.6 billion of the foreign tax credit carryforwards and $30and $27 million of the state tax credit carryforwards.
As of December 31, 2020,2022, Occidental had tax-effected federal net operating loss carryforwards of $631$3 million, foreign net operating loss carryforwards of $850$841 million and state net operating loss carryforwards of $316$214 million. TheThe carryforward balances have varyingvarying carryforward periods through 2040,2042, excluding certain attributes for which there is an indefinite carryforward period. A valuation allowance was recorded for $251$184 million of the tax-effected state net operating loss carryforwards and $795$801 million of the tax-effected foreign net operating loss carryforwards. Occidental hashad an additional valuation allowance of $145 million against other foreign deferred tax assets.
Occidental had ano tax-effected federal interest expense carryforward of $569 million and tax-effected state interest expense carryforward of $99$11 million as of December 31, 2020.2022. Occidental recorded a valuation allowance for $64$9 million of the state interest expense carryforward.carryforward.
A deferred tax liability hashad not been recognized for temporary differences related to unremitted earnings of certain consolidated international subsidiaries aggregating approximately $930$924 million atas of December 31, 2020,2022, as it is Occidental’s intention to reinvest such earnings indefinitely. If the earnings of these international subsidiaries were not indefinitely reinvested, an additional deferred tax liability of approximately $214$221 million would be required.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 | | 2020 |
| Balance as of January 1 | | $ | 2,026 | | | $ | 2,045 | | | $ | 2,173 | |
| | | | | | |
| Increases related to prior-year positions | | 2 | | | 75 | | | 14 | |
| Settlements | | — | | | (80) | | | (42) | |
| Reductions for tax positions of prior years | | (18) | | | (14) | | | (100) | |
| Balance as of December 31 | | $ | 2,010 | | | $ | 2,026 | | | $ | 2,045 | |
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
| Balance at January 1 | | $ | 2,173 | | | $ | 0 | | | $ | 22 | |
| Increase related to Anadarko Acquisition | | 0 | | | 2,143 | | | 0 | |
| Increases related to current-year positions | | 14 | | | 30 | | | 0 | |
| Settlements | | (42) | | | 0 | | | (22) | |
| Reductions for tax positions of prior years | | (100) | | | 0 | | | 0 | |
| Balance at December 31 | | $ | 2,045 | | | $ | 2,173 | | | $ | 0 | |
The December 31, 20202022 balance of unrecognized tax benefits of $2.0 billion included potential benefits of $2.0 billion of which, if recognized, $1.6$1.5 billion would affect the effective tax rate on income. Also included arewere benefits of $84$45 million related to tax positions for which the ultimate deductibility is highly certain, but the timing of such deductibility is uncertain. Unrecognized tax benefits are included in deferred credits and other liabilities - other. Occidental records estimated potential interest and penalties related to liabilities for unrecognized tax benefits in the provisions for domestic and foreign income taxes. During 2020,2022, Occidental recorded interest related to liabilities for unrecognized tax benefits of $67$95 million, for a cumulative accrued interest related to liabilities for unrecognized tax benefits of $263$416 million as of December 31, 2020.2022. There were 0 interest andno penalties associated with liabilities for unrecognized tax benefits recorded for the years ended December 31, 20202022 and 2019.2021. Over the next 12 months, it is reasonably possible that the total amount of unrecognized tax benefits could decrease by $70$50 million to $80$60 million due to settlements with taxing authorities or lapselapses in statutes of limitation.
Occidental recognized $110$280 million and $86$105 million in federal and state income tax receivables atas of December 31, 2020,2022 and 2019,2021, respectively, which was recorded in other current assets. In addition, Occidental recognized $24$33 million in receivables associated with audits and $36 million in federal alternative minimum tax non-current receivables atthe December 31, 2020 and 2019, respectively, both of2021 audit, which werewas recorded in long-term receivables and other assets, net.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
| | |
NOTE 1311 - STOCKHOLDERS’ EQUITY |
The following is a summary of common stock issuances:
| | | | | | | | |
Shares in thousands | | Common Stock |
Balance, December 31, 2017 | | 893,469 | |
Issued | | 1,628 | |
Options exercised and other, net | | 19 | |
Balance, December 31, 2018 | | 895,116 | |
Issued | | 3,188 | |
Issued as part of the Acquisition (a)
| | 146,131 | |
Balance, December 31, 2019 | | 1,044,435 | |
Issued | | 36,130 | |
Options exercised and other, net | | 0 | |
Balance, December 31, 2020 | | 1,080,565 | |
(a)Included approximately 2 million shares of common stock issued to a benefits trust for former Anadarko employees treated as treasury stock at December 31, 2019. These shares were sold from the trust in the first quarter of 2020.
TREASURY STOCK
The total number of shares authorized for Occidental’s share repurchase program is 185 million shares of which 44.2 million may yet be purchased under the repurchase program. However, the program does not obligate Occidental to acquire any specific number of shares and may be discontinued at any time. In 2020, 0 shares were purchased under the program. In 2019, 2.7 million shares were purchased at an average price of $66.94. In 2018, 16.9 million shares were purchased at an average price of $74.92. Additionally, Occidental purchased shares from the trustee of its defined contribution savings plan in 2020 and 2018. As of December 31, 2020, 2019 and 2018, treasury stock shares numbered 149.1 million, 150.3 million and 145.7 million, respectively.
PREFERRED STOCK
In connection with the Acquisition, Occidental issued 100,000 shares of series A preferred stock (the Preferred Stock), having a face value of $100,000 per share and a liquidation preference of $105,000 per share plus unpaid accrued dividends. In connection with the preferred stock issuance, Occidental also issued the Warrant. The holder of the Warrant and the Preferred Stock may redeem the Preferred Stock as payment for the exercise price of the Warrant in lieu of cash payment upon exercise. The Preferred Stock is redeemable at Occidental’s option after the 10th anniversary of issuance. Dividends on the Preferred Stock will accrue on the face value at a rate per annum of 8%, but will be paid only when, as and if declared by Occidental’s Board of Directors. At any time, when such dividends have not been paid in full, the unpaid amounts will accrue dividends, compounded quarterly, at a rate per annum of 9%. Following the payment in full of any accrued but unpaid dividends, the dividend rate will remain at 9% per annum.
If preferred dividends are not paid in full, Occidental is prohibited from paying dividends on common stock. In March and June 2020, the Board of Directors elected to declare its quarterly dividend on the Preferred Stock in shares of common stock. In accordance with the Certificate of Designations, the number of shares issued was calculated based on 90 percent of the average of the volume weighted average price over each of the 10 consecutive trading days following the dividend declaration date. In April and July 2020, Occidental issued approximately 17.3 million and 11.6 million shares, respectively, of common stock to the holders of the Preferred Stock. In October 2020 and January 2021, Occidental paid $200 million cash in Preferred Stock dividends for the Q3 and Q4 dividends, respectively.
At December 31, 2020 and 2019, Occidental had 100,000 shares of preferred stock issued and outstanding, and 0ne were outstanding in 2018.
COMMON STOCK WARRANTS
On June 26, 2020, the Board of Directors declared a distribution of warrants to holders of Occidental common stock, at a rate of 0.125 warrants per share of Occidental common stock (the Common Stock Warrants). Occidental issued approximately 116 million Common Stock Warrants on August 3, 2020 to holders of record of outstanding shares of Occidental’s common stock as of the close of business on July 6, 2020, and pursuant to Occidental’s outstanding equity-based incentive awards in connection with anti-dilution adjustments resulting from such distribution. The Common Stock Warrants have an exercise price of $22.00 per share and will expire on August 3, 2027. The Common Stock Warrants are listed on the New York Stock Exchange and trade under the symbol "OXY WS".
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
The Common Stock Warrants were measured at fair value on the declaration date using the Black-Scholes option model and were classified as equity in "Additional paid-in capital". The following level 2 inputs were used in the Black-Scholes option model: the expected life of the Common Stock Warrants, a volatility factor and the exercise price. The expected life is based on the estimated term of the Common Stock Warrants, the volatility factor is based on historical volatilities of Occidental common stock and the exercise of $22.00 per share of Occidental common stock. As of the declaration date, the fair value of the Common Stock Warrants was determined to be $767 million.
EARNINGS PER SHARE
The following table presents the calculation of basic and diluted earnings per share for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | |
| millions except per share amounts | | 2020 | | 2019 | | 2018 |
| Income (loss) from continuing operations | | $ | (13,533) | | | $ | (507) | | | $ | 4,131 | |
| Loss from discontinued operations | | (1,298) | | | (15) | | | 0 | |
| Net income (loss) | | $ | (14,831) | | | $ | (522) | | | $ | 4,131 | |
| Less: Net income attributable to noncontrolling interest | | 0 | | | (145) | | | 0 | |
| Less: Preferred stock dividends | | (844) | | | (318) | | | 0 | |
| Net income (loss) attributable to common stock | | $ | (15,675) | | | $ | (985) | | | $ | 4,131 | |
| Less: Net income allocated to participating securities | | 0 | | | 0 | | | (17) | |
| Net income (loss), net of participating securities | | $ | (15,675) | | | $ | (985) | | | $ | 4,114 | |
| Weighted-average number of basic shares | | 918.7 | | | 809.5 | | | 761.7 | |
| Basic earnings (loss) per common share | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.40 | |
| Net income (loss), net of participating securities | | $ | (15,675) | | | $ | (985) | | | $ | 4,114 | |
| Weighted-average number of basic shares | | 918.7 | | | 809.5 | | | 761.7 | |
| Dilutive securities | | 0 | | | 0 | | | 1.6 | |
| Total diluted weighted-average common shares | | 918.7 | | | 809.5 | | | 763.3 | |
| Diluted earnings (loss) per common share | | $ | (17.06) | | | $ | (1.22) | | | $ | 5.39 | |
ACCUMULATED OTHER COMPREHENSIVE LOSS
Accumulated other comprehensive loss consisted of the following after-tax amounts at December 31:
| | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 |
| Foreign currency translation adjustments | | $ | (6) | | | $ | (7) | |
| Losses on derivatives | | (119) | | | (122) | |
Pension and postretirement adjustments (a) | | (163) | | | (92) | |
| Total | | $ | (288) | | | $ | (221) | |
| | |
NOTE 14 - STOCK-BASED INCENTIVERETIREMENT AND POSTRETIREMENT BENEFIT PLANS |
Occidental issues stock-based awardshas various defined contribution and defined benefit plans for its salaried, domestic union and nonunion hourly and certain foreign national employees. In addition, Occidental also provides medical and other benefits for certain active, retired and disabled employees and their eligible dependents.
In 2021, Occidental settled a significant portion of retiree liability through an annuity purchase. This annuity purchase applied to participants in certain defined benefit plans. The impact of this settlement transaction was approximately $109 million and is reflected in the December 31, 2021 projected benefit obligation.
DEFINED CONTRIBUTION PLANS
All domestic employees and certain foreign national employees are eligible to participate in accordance with the termsone or more of the shareholder approved 2015 Long-Term Incentive Plan. An aggregate of 133defined contribution retirement or savings plans that provide for periodic contributions by Occidental based on plan-specific criteria, such as base pay, level and employee contributions. Certain salaried employees participate in a supplemental retirement plan that restores benefits lost due to governmental limitations on qualified retirement benefits. The accrued liabilities for the supplemental retirement plan were $288 million shares of Occidental common stock were authorized for issuance and approximately 11.6$249 million shares had been allocated to employee awards through December 31, 2020. Asas of December 31, 2022 and 2021, respectively. Occidental expensed $202 million in 2022, $166 million in 2021 and $192 million in 2020 approximately 88.3under the provisions of these defined contribution and supplemental retirement plans.
DEFINED BENEFIT PLANS
Participation in defined benefit plans is limited. Approximately 400 domestic and 300 foreign national employees, mainly union, nonunion hourly and certain employees that joined Occidental from acquired operations with grandfathered benefits, are currently accruing benefits under these plans.
Pension costs for Occidental’s defined benefit pension plans, determined by independent actuarial valuations, are generally funded by payments to trust funds, which are administered by independent trustees.
POSTRETIREMENT AND OTHER BENEFIT PLANS
Occidental provides medical and dental benefits and life insurance coverage for certain active, retired and disabled employees and their eligible dependents. Occidental generally funds the benefits as they are paid during the year. These benefit costs, including the postretirement costs for the years ended December 31, were $211 million shares were available for grants of future awards. The plan requires each share covered by an award (other than options) to be counted as if 3 shares were issued in determining the number of shares that are available for future awards. Accordingly, the number of shares available for future awards may be less than 88.32022, $211 million depending on the type of award granted,in 2021 and shares available for future awards may increase by the number of shares that are forfeited, canceled, or correspond to the portion of any stock-based awards settled$235 million in cash, including awards that were issued under a previous plan that remain outstanding. Current outstanding awards include RSUs, stock options, CROCEIs and TSRIs.2020.
During 2020, non-employee directors were granted awards for 144,603 shares of common stock. Compensation expense for these awards was measured using the closing quoted market price of Occidental’s common stock on the grant date and was fully recognized at that time.
| | | | | |
10494 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
OBLIGATIONS AND FUNDED STATUS
ForThe following tables show the year ended December 31, 2020, Occidental incurred expenses of $202 millionamounts recognized in Occidental’s Consolidated Balance Sheets related to stock-based incentiveits pension and postretirement benefit plans as of which $59 million wasDecember 31:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2022 | | 2021 | | 2022 | | 2021 |
| Amounts recognized in the Consolidated Balance Sheet: | | | | | | | | |
| Long-term receivables and other assets, net | | $ | 102 | | | $ | 192 | | | $ | — | | | $ | — | |
| Accrued liabilities | | (3) | | | (4) | | | (62) | | | (71) | |
| Deferred credits and other liabilities — pension and postretirement obligations | | (344) | | | (391) | | | (711) | | | (1,149) | |
| | | $ | (245) | | | $ | (203) | | | $ | (773) | | | $ | (1,220) | |
| Accumulated other comprehensive loss included the following after-tax balances: | | | | | | | | |
| Net (gain) loss | | $ | 17 | | | $ | (17) | | | $ | (190) | | | $ | 163 | |
| Prior service credit | | — | | | — | | | (52) | | | (50) | |
| | | $ | 17 | | | $ | (17) | | | $ | (242) | | | $ | 113 | |
The following tables show the funding status, obligations and plan asset fair values of Occidental related to the Acquisition. For the year ended December 31, 2019, expense related to stock-based incentiveits pension and postretirement benefit plans was $208 million of which $31 million was related to the Acquisition. For the year ended December 31, 2018, Occidental incurred expenses of $180 million related to stock-based incentive plans. The income tax benefit associated with this expense was $42 million, $43 million and $47 million infor the years ended December 31, 2020, 2019, and 2018, respectively.
As of December 31, 2020, unrecognized compensation expense for all unvested stock-based incentive awards was $254 million. This expense is expected to be recognized over a weighted-average period of 1.7 years. Occidental accounts for forfeitures as they occur.31:
RSUs
Certain employees are awarded the right to receive RSUs, some of which have performance criteria, and are in the form of, or equivalent in value to, actual shares of Occidental common stock. Depending on their terms, RSUs may be settled in stock or may be cash settled liabilities. These awards vest from one to four years following the grant date, however, certain of the RSUs are forfeitable if performance objectives are not satisfied by the seventh anniversary of the grant date. For certain RSUs, dividend equivalents are paid during the vesting period. | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2022 | | 2021 | | 2022 | | 2021 |
| Changes in the benefit obligation: | | | | | | | | |
| Benefit obligation — beginning of year | | $ | 1,273 | | | $ | 1,613 | | | $ | 1,220 | | | $ | 1,259 | |
| Service cost — benefits earned during the period | | 7 | | | 8 | | | 38 | | | 42 | |
| Interest cost on projected benefit obligation | | 36 | | | 35 | | | 33 | | | 33 | |
| Actuarial gain | | (297) | | | (55) | | | (468) | | | (54) | |
| Benefits paid | | (123) | | | (219) | | | (58) | | | (67) | |
| Settlement due to annuity purchase | | — | | | (109) | | | — | | | — | |
| Other | | (10) | | | — | | | 8 | | | 7 | |
| Benefit obligation — end of year | | $ | 886 | | | $ | 1,273 | | | $ | 773 | | | $ | 1,220 | |
| | | | | | | | |
| Changes in plan assets: | | | | | | | | |
| Fair value of plan assets — beginning of year | | $ | 1,070 | | | $ | 1,193 | | | $ | — | | | $ | — | |
| Actual return on plan assets | | (304) | | | 44 | | | — | | | — | |
| Employer contributions | | 16 | | | 162 | | | 49 | | | 59 | |
| Benefits paid | | (123) | | | (219) | | | (57) | | | (67) | |
| Payments due to annuity purchase | | — | | | (109) | | | — | | | — | |
| Other | | (18) | | | (1) | | | 8 | | | 8 | |
| Fair value of plan assets — end of year | | $ | 641 | | | $ | 1,070 | | | $ | — | | | $ | — | |
| Unfunded status: | | $ | (245) | | | $ | (203) | | | $ | (773) | | | $ | (1,220) | |
CASH-SETTLED RSU LIABILITY AWARDS
The weighted-average, grant-date fair values of cash-settled RSUs granted in 2020, 2019 and 2018 were $40.86, $42.62 and $75.86 per share, respectively. Cash-Settled RSUs resulted in payments of $3 million, $4 million and $18 million, during the years ended December 31, 2020, 2019 and 2018, respectively.
STOCK-SETTLED RSU EQUITY AWARDS
The weighted-average, grant-date fair values of the stock-settled RSUs granted in 2020, 2019, and 2018 were $41.60, $58.73 and $69.87, respectively. The fair value of RSUs settled in shares during the years ended December 31, 2020, 2019 and 2018 was $62 million, $148 million and $109 million, respectively.
A summary of changes in Occidental’s unvested cash- and stock-settled RSUs during the year ended December 31, 2020, is presented below:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Cash-Settled | | Stock-Settled |
| thousands, except fair values | | RSUs | | Weighted-Average
Grant-Date
Fair Value | | RSUs | | Weighted-Average
Grant-Date
Fair Value |
| Unvested at January 1 | | 4,347 | | | | $ | 43.46 | | | 4,395 | | | | $ | 65.88 | |
| Granted | | 1,500 | | | | $ | 40.86 | | | 4,299 | | | | $ | 41.60 | |
| Vested | | (114) | | | | $ | 61.61 | | | (2,328) | | | | $ | 64.19 | |
| Forfeitures | | (276) | | | | $ | 42.68 | | | (510) | | | | $ | 48.89 | |
| Unvested at December 31 | | 5,457 | | | | $ | 42.41 | | | 5,856 | | | | $ | 50.21 | |
TSRIs
Certain executives are awarded TSRIs that vest at the end of a three-year period following the grant date. Payout is based upon Occidental’s absolute total shareholder return and performance relative to its peers. TSRIs have payouts that range from 0% to 200% of the target award and settle in stock once certified. Dividend equivalents for TSRIs are accumulated and paid upon certification of the award. The fair value of TSRIs settled in shares during the years ended December 31, 2020, 2019 and 2018 was $9 million, $4 million and $12 million, respectively.
The fair values of TSRIs are initially determined on the grant date using a Monte Carlo simulation model based on Occidental’s assumptions, noted in the following table, and the volatility from corresponding peer group companies. The expected life is based on the vesting period (Term). The risk-free interest rate is the implied yield available on zero coupon T-notes (U.S. Treasury Strip) at the time of grant with a remaining term equal to the Term. The dividend yield is the expected annual dividend yield over the Term, expressed as a percentage of the stock price on the grant date. Estimates of fair value may not accurately predict the value ultimately realized by the employees who receive the awards, and the ultimate value may not be indicative of the reasonableness of the original estimates of fair value made by Occidental.
| | | | | |
OXY 20202022 FORM 10-K | 10595 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
The grant-date assumptions usedChanges in actuarial gains and losses in the Monte Carlo simulation modelsprojected benefit obligation are primarily driven by discount rate movement.
The following table sets forth details of the obligations and assets of Occidental’s defined benefit pension plans for the estimated payout level of TSRIs were as follows:years ended December 31:
| | | | | | | | | | | | | | | | | | | | |
| | | TSRIs |
| | 2020 | | 2019 | | 2018 |
| Assumptions used: | | | | | | |
| Risk-free interest rate | | 1.4% | | 2.5% | | 2.3% |
| Volatility factor | | 26% | | 22% | | 24% |
| Expected life (years) | | 3 | | 3 | | 3 |
| Grant-date fair value of underlying Occidental common stock | | $ | 41.60 | | $ | 67.19 | | $ | 69.87 |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Accumulated Benefit
Obligation in Excess of
Plan Assets | | Plan Assets in
Excess of Accumulated
Benefit Obligation |
| millions | | 2022 | | 2021 | | 2022 | | 2021 |
| Projected benefit obligation | | $ | 738 | | | $ | 963 | | | $ | 148 | | | $ | 310 | |
| Accumulated benefit obligation | | $ | 736 | | | $ | 960 | | | $ | 146 | | | $ | 308 | |
| Fair value of plan assets | | $ | 458 | | | $ | 656 | | | $ | 183 | | | $ | 414 | |
A summaryCOMPONENTS OF NET PERIODIC BENEFIT COST
The following table sets forth the components of Occidental’s unvested TSRIs as of December 31, 2020 and changes duringnet periodic benefit costs for the yearyears ended December 31, 2020 is presented below:31:
| | | | | | | | | | | | | | | | | |
| | | TSRIs |
| thousands, except fair values | | Awards | | Weighted-Average
Grant-Date Fair Value
of Occidental Stock |
| Unvested at January 1 | | 1,537 | | | | $ | 67.70 | |
| Granted | | 641 | | | | $ | 41.60 | |
Vested (a) | | (563) | | | | $ | 67.21 | |
| Forfeitures | | (81) | | | | $ | 52.47 | |
| Unvested at December 31 | | 1,534 | | | | $ | 58.02 | |
(a)Presented at the target payouts. The weighted-average payout at vesting was 40% of the target, resulting in the issuance of approximately 223,000 shares of Occidental common stock. | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2022 | | 2021 | | 2020 | | 2022 | | 2021 | | 2020 |
| Net periodic benefit costs: | | | | | | | | | | | | |
| Service cost — benefits earned during the period | | $ | 7 | | | $ | 8 | | | $ | 37 | | | $ | 38 | | | $ | 42 | | | $ | 39 | |
| Interest cost on projected benefit obligation | | 36 | | | 35 | | | 52 | | | 33 | | | 33 | | | 37 | |
| Expected return on plan assets | | (38) | | | (59) | | | (73) | | | — | | | — | | | — | |
| Recognized actuarial loss | | 1 | | | 2 | | | 5 | | | 5 | | | 15 | | | 11 | |
| Recognized prior service credit | | — | | | — | | | — | | | (9) | | | (9) | | | (8) | |
| (Gain) loss due to curtailment | | — | | | — | | | (124) | | | — | | | — | | | 2 | |
| Gain due to settlement | | (1) | | | (19) | | | (19) | | | — | | | — | | | — | |
| Special termination benefits | | — | | | — | | | 22 | | | — | | | — | | | — | |
| Other costs and adjustments | | — | | | — | | | 1 | | | — | | | — | | | — | |
| Net periodic benefit cost | | $ | 5 | | | $ | (33) | | | $ | (99) | | | $ | 67 | | | $ | 81 | | | $ | 81 | |
STOCK OPTIONS
In 2020, certain employees were granted options that vest over three years, expireThe service cost component of net periodic benefit cost is included in selling, general and administrative, oil and gas operating expense, chemical and midstream costs and exploration expense on the tenth anniversaryOccidental’s Consolidated Statements of the grant date,Operations. All other components of net periodic benefit cost are included in other operating and settle in stock or cash. Exercise prices of the options were equal to the quoted market value of Occidental’s stock on the grant date. These options had a grant date fair value of $3.19, as estimated by the Black Scholes model. The inputs to this model are presented below:non-operating expense.
| | | | | | | | | | | |
| | | Options |
| | 2020 | |
| Assumptions used: | | | |
| Risk-free interest rate | | 1.5% | |
| Volatility factor | | 25% | |
| Expected life (years) | | 6 | |
| Dividend yield | | 7.6% | |
| Grant-date fair value of underlying Occidental common stock | | $ | 41.60 | |
The following table sets forth the weighted-average assumptions used to determine Occidental’s benefit obligation and net periodic benefit cost for domestic plans for the years ended December 31:
A summary of Occidental’s outstanding stock options as of December 31, 2020 and changes during the year ended December 31, 2020 is presented below: | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Pension Benefits | | Postretirement Benefits |
| | 2022 | | 2021 | | 2022 | | 2021 |
| Benefit Obligation Assumptions: | | | | | | | | |
| Discount rate | | 5.27 | % | | 2.67 | % | | 5.43 | % | | 2.94 | % |
| Rate of increase in compensation levels | | 3.95 | % | | 3.98 | % | | — | | | — | |
| Net Periodic Benefit Cost Assumptions: | | | | | | | | |
| Discount rate | | 2.65 | % | | 2.19 | % | | 2.94 | % | | 3.05 | % |
| Rate of increase in compensation levels | | 3.98 | % | | 5.07 | % | | — | | | — | |
| Assumed long-term rate of return on assets | | 4.36 | % | | 4.92 | % | | — | | | — | |
| | | | | | | | | | | | | | | | | | | | |
| | | Vested | | Unvested |
| thousands, except fair values | | Options | Weighted Average Strike Price | | Options | Weighted Average Strike Price |
| January 1 | | 530 | | $ | 79.98 | | | 0 | | |
| Granted | | 0 | | | | 2,573 | | $ | 41.60 | |
| Anti-dilution adjustment | | 21 | | $ | 76.96 | | | 101 | | $ | 40.03 | |
| Vested | | 0 | | | | 0 | | |
| Expirations and Forfeitures, respectively | | 0 | | | | 0 | | |
| December 31 | | 551 | | $ | 76.96 | | | 2,674 | | $ | 40.03 | |
For domestic pension plans and postretirement benefit plans, Occidental based the discount rate on a AA-AAA Universe yield curve in 2022 and 2021. The assumed long-term rate of return on assets is estimated with regard to current market factors but within the context of historical returns for the asset mix that exists at year end. Assumed rates of compensation increases for active participants in certain plans and vary by age group. | | | | | |
10696 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
In 2021, Occidental adopted the Society of Actuaries Pri-2012 Private Retirement Plans Mortality Tables with MP-2021 Mortality Improvement Scale, which updated the mortality assumptions that private defined-benefit plans in the United States use in the actuarial valuations that determine a plan sponsor’s pension obligations. The new mortality assumption reflects additional data that the Social Security Administration has released since the previous mortality tables and improvement scales were released.
The postretirement benefit obligation was determined by application of the terms of medical and dental benefits and life insurance coverage, including the effect of established maximums on covered costs, together with relevant actuarial assumptions and health care cost trend rates. Health care cost trend rates for medicare advantaged prescription drug plans of 9.2% starting in 2022, then grading down to 4.5% in 2028 and beyond. Health care cost trend rates used for non-medicare advantaged prescription drug plans are 6.0% to 6.5% in 2022, then grading down to 4.5% in 2028 and beyond.
The actuarial assumptions used could change in the near-term as a result of changes in expected future trends and other factors that, depending on the nature of the changes, could cause increases or decreases in the plan assets and liabilities.
FAIR VALUE OF PENSION PLAN ASSETS
Qualified defined benefit plan assets are monitored by Occidental’s Pension and Retirement Trust and Investment Committee in its role as a fiduciary. The Investment Committee selects and employs various external professional investment management firms to manage specific investments across the spectrum of asset classes. The Investment Committee employs a liability driven investment approach that uses a diversified blend of investments (equity securities, fixed-income securities, and alternative investments) along a glide path to optimize the long-term return of plan assets relative to plan liabilities, at a prudent level of risk. Equity investments are diversified across U.S. and non-U.S. stocks, as well as differing styles and market capitalizations. Investment performance is measured and monitored on an ongoing basis through quarterly investment portfolio and manager guideline compliance reviews, annual liability measurements and periodic studies.
The fair values of Occidental’s pension plan assets by asset category were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | Level 1 | | Level 2 | | Level 3 | | Total |
| December 31, 2022 | | | | | | | | |
| Asset Class: | | | | | | | | |
| Cash and cash equivalents | | $ | 8 | | | $ | — | | | $ | — | | | $ | 8 | |
| Government securities | | 29 | | | — | | | — | | | 29 | |
Corporate bonds (a) | | — | | | 16 | | | — | | | 16 | |
Equity securities (b) | | 34 | | | — | | | — | | | 34 | |
| Other | | — | | | 46 | | | — | | | 46 | |
| Investments measured at fair value | | $ | 71 | | | $ | 62 | | | $ | — | | | $ | 133 | |
Investments measured at net asset value (c) | | — | | | — | | | — | | | 509 | |
Total pension plan assets (d) | | $ | 71 | | | $ | 62 | | | $ | — | | | $ | 642 | |
| | | | | | | | |
| December 31, 2021 | | | | | | | | |
| Asset Class: | | | | | | | | |
| Cash and cash equivalents | | $ | 19 | | | $ | — | | | $ | — | | | $ | 19 | |
| Government securities | | 63 | | | — | | | — | | | 63 | |
Corporate bonds (a) | | — | | | 36 | | | — | | | 36 | |
Equity securities (b) | | 46 | | | — | | | — | | | 46 | |
| Other | | — | | | 76 | | | — | | | 76 | |
| Investments measured at fair value | | $ | 128 | | | $ | 112 | | | $ | — | | | $ | 240 | |
Investments measured at net asset value (c) | | — | | | — | | | — | | | 836 | |
Total pension plan assets (d) | | $ | 128 | | | $ | 112 | | | $ | — | | | $ | 1,076 | |
(a)This category represents investment grade bonds of U.S. and non-U.S. issuers from diverse industries.
(b)This category represents direct investments in mutual funds and common and preferred stocks from diverse U.S. and non-U.S. industries.
(c)Certain investments measured at fair value using the NAV per share (or its equivalent) have not been categorized in the fair value hierarchy. Amounts presented in this table are intended to reconcile the fair value hierarchy to the pension plan assets.
(d)Amounts exclude net payables of approximately $1 million as of December 31, 2022 and $6 million as of December 31, 2021.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
Occidental expects to contribute approximately $100 million to its defined benefit pensions plans during 2023.
Estimated future benefit payments, which reflect expected future service, as appropriate, are as follows for the years ended December 31:
| | | | | | | | | | | | | | |
| millions | Pension Benefits | Postretirement Benefits |
| 2023 | | $ | 75 | | | $ | 64 | |
| 2024 | | 78 | | | 62 | |
| 2025 | | 70 | | | 59 | |
| 2026 | | 67 | | | 57 | |
| 2027 | | 68 | | | 55 | |
| 2028 - 2032 | | 303 | | | 261 | |
| | |
| NOTE 12 - ENVIRONMENTAL LIABILITIES AND EXPENDITURES |
Occidental and its subsidiaries and their respective operations are subject to stringent federal, state, local and international laws and regulations related to improving or maintaining environmental quality. The laws that require or address environmental remediation, including CERCLA and similar federal, state, local and international laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership or control of sites. Occidental or certain of its subsidiaries participate in or actively monitor a range of remedial activities and government or private proceedings under these laws with respect to alleged past practices at Third-Party, Currently Operated, and Closed or Non-operated Sites. Remedial activities may include one or more of the following: investigation involving sampling, modeling, risk assessment or monitoring; clean-up measures including removal, treatment or disposal; or operation and maintenance of remedial systems. The environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, natural resource damages, punitive damages, civil penalties, injunctive relief and government oversight costs.
ENVIRONMENTAL REMEDIATION
As of December 31, 2022, certain Occidental subsidiaries participated in or monitored remedial activities or proceedings at 162 sites. The following table presents the current and non-current environmental remediation liabilities of such subsidiaries on a consolidated basis as of December 31, 2022 and 2021, the current portion of which is included in accrued liabilities ($141 million in 2022 and $155 million in 2021) and the remainder in deferred credits and other liabilities - environmental remediation liabilities ($0.9 billion in 2022 and $0.9 billion in 2021).
These environmental remediation sites are grouped into NPL sites and the following three categories of non-NPL sites —Third-Party Sites, Currently Operated Sites and Closed or Non-operated Sites.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 |
| millions, except number of sites | | Number of Sites | | Remediation Balance | | Number of Sites | | Remediation Balance |
| NPL sites | | 30 | | | $ | 445 | | | 30 | | | $ | 427 | |
| Third-Party Sites | | 68 | | | 238 | | | 69 | | | 273 | |
| Currently Operated Sites | | 13 | | | 106 | | | 15 | | | 122 | |
| Closed or Non-operated Sites | | 51 | | | 257 | | | 51 | | | 277 | |
| Total | | 162 | | | $ | 1,046 | | | 165 | | | $ | 1,099 | |
As of December 31, 2022, environmental remediation liabilities of Occidental subsidiaries exceeded $10 million each at 17 of the 162 sites described above, and 94 of the sites had liabilities from $0 to $1 million each.
The Diamond Alkali Superfund Site (DASS) in Newark, New Jersey accounted for a significant portion of the liabilities associated with the category of NPL sites.
Five of the 68 Third-Party Sites — a chrome site in New Jersey, a former copper mining and smelting operation in Tennessee, a former oil field and a landfill in California and an active refinery in Louisiana where Occidental reimburses the current owner for certain remediation activities — accounted for nearly two-thirds of the liabilities associated with this category.
Three Currently Operated Sites — oil and gas operations in Colorado and chemical plants in Kansas and Louisiana — accounted for approximately two-thirds of the liabilities associated with this category.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
Eight Closed or Non-operated Sites — a landfill in Western New York, a former refinery in Oklahoma, former chemical plants in California, Michigan, Ohio, Tennessee and Washington, and a closed coal mine in Pennsylvania — accounted for more than two-thirds of the liabilities associated with this category.
The intrinsic valueconsolidated estimate of options exercised duringenvironmental remediation liabilities in the table above varies over time depending on factors such as acquisitions or divestitures, identification of additional sites, remedy selection and implementation and changes in applicable laws or regulations, among other factors. Occidental’s subsidiaries recorded environmental remediation expenses of $65 million, $28 million and $36 million for the years ended December 31, 2022, 2021, and 2020, 2019 and 2018 were insignificant. The issuancerespectively, on a consolidated basis. Environmental remediation expenses primarily relate to changes to existing conditions from past operations. Based on current estimates, Occidental expects its subsidiaries to expend funds corresponding to approximately 40% of the Common Stock Warrants,year-end remediation balance over the next three to four years with the remainder over the subsequent 10 or more years.
Occidental believes its range of reasonably possible additional losses of its subsidiaries beyond those amounts currently recorded for environmental remediation for the 162 environmental sites in the table above could be up to $2.7 billion.
MAXUS ENVIRONMENTAL SITES
A significant portion of aggregate estimates of environmental remediation liabilities and reasonably possible additional losses described above relates to the former Diamond Alkali Chemicals Company (DSCC). When OxyChem acquired DSCC in 1986, Maxus agreed to indemnify OxyChem for a number of environmental sites, including the DASS. In June 2016, Maxus and several affiliated companies filed for Chapter 11 bankruptcy in the U.S. Bankruptcy Court for the District of Delaware. Prior to filing for bankruptcy, Maxus defended and indemnified OxyChem in connection with remediation costs and other liabilities associated with the sites subject to the indemnity. Any additional recovery of indemnified costs would come from the proceeds of litigation brought by the Maxus Liquidating Trust. For additional information on the Maxus Liquidating Trust, see NoteNote 13 - Stockholders’ EquityLawsuits, Claims, Commitments and Contingencies, triggered certain anti-dilution provisions for both vested and unvested options, which resulted in an increase of the number of options exercisable and a decrease in the exercise price. As of December 31, 2020, the remaining life of fully vested options was 1.1 years..
CROCEIDIAMOND ALKALI SUPERFUND SITE
Certain executivesThe EPA has organized the DASS into four Operable Units (OUs) for evaluating, selecting and implementing remediation under CERCLA. OxyChem’s current activities in each OU are awarded CROCEI awardssummarized below, many of which are performed on OxyChem’s behalf by Glenn Springs Holdings, Inc.
OU1 – The Former Diamond Alkali Plant at 80-120 Lister Avenue in Newark: Maxus and its affiliates implemented an interim remedy of OU1 pursuant to a 1990 Consent Decree, for which OxyChem currently performs maintenance and monitoring. The EPA is conducting a periodic evaluation of the interim remedy for OU1.
OU2 – The Lower 8.3 Miles of the Lower Passaic River: In March 2016, the EPA issued a Record of Decision (ROD) specifying remedial actions required for OU2. During the third quarter of 2016, and following Maxus’s bankruptcy filing, OxyChem and the EPA entered into an Administrative Order on Consent (AOC) to complete the design of the remedy selected in the ROD. At that vesttime, the EPA sent notice letters to approximately 100 parties notifying them that they were potentially responsible to pay the costs to implement the remedy in OU2 and announced that it would pursue similar agreements with other potentially responsible parties. In June 2018, OxyChem filed a complaint under CERCLA in Federal District Court in the State of New Jersey against numerous potentially responsible parties seeking contribution and cost recovery of amounts incurred or to be incurred to comply with the AOC and the OU2 ROD, or to perform other remediation activities related to the DASS. That action remains pending and the District Court has not adjudicated OxyChem’s relative share of responsibility for those costs. The EPA has estimated the cost to remediate OU2 to be approximately $1.4 billion.
OU3 – Newark Bay Study Area, including Newark Bay and Portions of the Hackensack River, Arthur Kill, and Kill van Kull: Maxus and its affiliates initiated a remedial investigation and feasibility study of OU3 pursuant to a 2004 AOC which was amended in 2010. OxyChem is currently performing feasibility study activities in OU3.
OU4 – The 17-mile Lower Passaic River Study Area, comprising OU2 and the Upper 9 Miles of the Lower Passaic River: In September 2021, the EPA issued a ROD selecting an interim remedy for the portion of OU4 that excludes OU2, and is located upstream from the Lister Avenue Plant site for which OxyChem inherited legal responsibility. The EPA had estimated the cost to remediate OU4 to be approximately $440 million. At this time, OxyChem's role or responsibilities under the OU4 ROD, and those of other potentially responsible parties, have not been adjudicated. To provide continued, efficient remediation progress, in January 2022, OxyChem offered to design and implement the interim remedy for OU4 subject to certain conditions, including a condition that the EPA would not seek to bar OxyChem’s right to seek contribution or cost recovery from any other parties that are potentially responsible to pay for the OU4 interim remedy. In March 2022, the EPA sent a notice letter to OxyChem and other parties requesting good faith offers to implement the selected remedies at OU2 and OU4. OxyChem submitted a good faith offer in June 2022, reaffirming the offer to design the remedy for OU4 and offering to enter into additional sequential agreements to remediate OU2 and OU4, subject to similar conditions, including that the EPA not seek to bar OxyChem from pursuing contribution or cost recovery from other responsible parties. The EPA did not accept OxyChem's June 2022 offer and, as such, OxyChem believes that the EPA may issue a Unilateral Administrative Order or commence CERCLA litigation against it, and potentially other parties, to require further design and/or implementation activities of the EPA’s selected remedies at the end of a three-year period if performance targets based on cash return on capital employed are met. These awards are settled in stock upon certificationDASS.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
Ongoing Assessment by Natural Resource Trustees: In addition to the activities of the performance target, with payouts that range from 0%EPA and OxyChem in the OUs described above, federal and state natural resources trustees are conducting an assessment of natural resources in the Lower Passaic River and Greater Newark Bay to 200% of the target award. Dividend equivalents are accumulated and paid upon certification of the award.evaluate potential claims for natural resource damages.
| | | | | | | | | | | | | | | | | |
| | | CROCEI |
| thousands, except fair values | | Awards | | Weighted-Average
Grant-Date
Fair Value of Occidental Stock |
| Unvested at January 1 | | 154 | | | | $ | 68.44 | |
| Granted | | 197 | | | | $ | 41.60 | |
Vested (a) | | (154) | | | | $ | 68.47 | |
| Forfeited | | 0 | | | | 0 |
| Unvested at December 31 | | 197 | | | | $ | 41.60 | |
In December 2022, the EPA and the DOJ filed a proposed Consent Decree in the Alden Leeds litigation seeking court approval to settle with 85 parties for a total of $150 million and release them from liability for remediation costs in DASS OU2 and OU4, which OxyChem believes is based on a disproportionate allocation of responsibility to OxyChem despite overwhelming evidence regarding the responsibility of others, and, among other infirmities, is contrary to site-specific sampling and other relevant evidence concerning the liability of the settling parties. The EPA and DOJ also seek entry of an order that would bar OxyChem from pursuing contribution against those parties for remediation costs OxyChem had incurred or may incur in the future to design and implement the remedies in OU2 and OU4.
(a)PresentedOxyChem intends to challenge the proposed settlement vigorously in the Alden Leeds litigation and to seek contribution and cost recovery from other potentially responsible parties for remediation costs it had incurred or may incur at the target payouts. The weighted-average payout at vesting was 58%DASS. If OxyChem is denied leave to intervene in the Alden Leeds litigation, its anticipated settlement objections are overruled by the Court or in any subsequent appeals, or the proposed settlement is approved by the Court and not overturned on appeal, then, notwithstanding OxyChem’s vigorous, good faith effort to contest the settlement proposed in the Alden Leeds litigation, the EPA could attempt to compel OxyChem to bear substantially all of the target resultingestimated cost to design and implement the OU2 and OU4 remedies, which would have a material adverse impact on OxyChem and Occidental’s consolidated results of operations in the issuanceperiod recorded. While the remedies for OU2 and OU4 are expected to take over ten years to complete, the EPA may seek to require OxyChem to provide financial assurance to secure its performance. The amount of approximately 89,700 shares.financial assurance is not subject to estimation at this time, as it is uncertain when or to what extent the EPA may take action to compel OxyChem to perform further remediation in OU2 or OU4 or the amount of assurance OxyChem would be required to post if the EPA takes such actions before the proposed settlement at issue in Alden Leeds is resolved. For further information on the Alden Leeds litigation, see Note 13 - Lawsuits, Claims, Commitments and Contingencies.
OTHER INFORMATION
For the DASS, OxyChem has accrued a reserve relating to its estimated allocable share of the costs to perform the maintenance and monitoring required in the OU1 Consent Decree, the design and implementation of remedies selected in the OU2 ROD and AOC and the OU4 ROD, and the remedial investigation and feasibility study required in the OU3.
OxyChem’s accrued environmental remediation reserve does not reflect the potential for additional remediation costs or natural resource damages for the DASS that OxyChem believes are not reasonably estimable. OxyChem’s ultimate liability at the DASS may be higher or lower than the reserved amount and the reasonably possible additional losses, and is subject to final design plans, further action by the EPA and natural resource trustees, and the resolution of OxyChem's allocable share with other potentially responsible parties, among other factors.
OxyChem continues to evaluate the estimated costs currently recorded for remediation at the DASS and other Maxus-indemnified sites, as well as the range of reasonably possible additional losses beyond those amounts currently recorded. Given the complexity and extent of the remediation efforts, estimates of the remediation costs may increase or decrease over time as new information becomes available.
| | |
NOTE 1513 - RETIREMENTLAWSUITS, CLAIMS, COMMITMENTS AND POSTRETIREMENT BENEFIT PLANSCONTINGENCIES |
LEGAL MATTERS
Occidental has various defined contribution and defined benefit plans foror certain of its salaried, domestic union and nonunion hourly and certain foreign national employees. In addition, Occidental also provides medicalsubsidiaries are involved, in the normal course of business, in lawsuits, claims and other benefitslegal proceedings that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. Occidental or certain active, retiredof its subsidiaries also are involved in proceedings under CERCLA and disabled employeessimilar federal, regional, state, provincial, tribal, local and their eligible dependents.international environmental laws. These environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, natural resource damages, punitive damages, civil penalties, injunctive relief and government oversight costs. Usually Occidental or such subsidiaries are among many companies in these environmental proceedings and have to date been successful in sharing remediation costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or disposed assets with respect to which a third party or Occidental or its subsidiary retains liability or indemnifies the other party for conditions that existed prior to the transaction.
In conjunctionaccordance with applicable accounting guidance, Occidental or its subsidiaries accrue reserves for outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the Acquisition, Occidental acquired certain Anadarko contributory and non-contributory defined benefit pension plans, which include both qualified and supplemental plans and plans that provide health care and life insurance benefitsliability can be reasonably estimated. Reserves for certain retired employees. The Anadarko pension and postretirement obligations were remeasured as of the Acquisition date. The remeasurement resulted in an increase to the benefit obligation of $193 million.
Effective as of June 30, 2020 the defined benefit pension plans and certain of the supplemental plans covering active Anadarko employees were frozen. This resulted in a decrease to the benefit obligation of approximately $278 million, including a curtailment gain of approximately $124 million and a corresponding offset to accumulatedmatters, other comprehensive income of approximately $154 million.
DEFINED CONTRIBUTION PLANS
All domestic employees and certain foreign national employees are eligible to participate in one or more of the defined contribution retirement or savings plans that provide for periodic contributions by Occidental based on plan-specific criteria, such as base pay, level and employee contributions. Certain salaried employees participate in a supplemental retirement plan that restores benefits lost due to governmental limitations on qualified retirement benefits. The accrued liabilitiesthan for the supplemental retirement plan were $239 million and $261 millionarbitration award (disclosed below), tax matters or environmental remediation, that satisfy these criteria as of December 31, 2020,2022 and 2019, respectively. Occidental expensed $192 million in 2020, $192 million in 2019 and $152 million in 2018 under the provisions of these defined contribution and supplemental retirement plans.
DEFINED BENEFIT PLANS
Participation in defined benefit plans is limited. Approximately 400 domestic and 300 foreign national employees, mainly union, nonunion hourly and certain employees that joined Occidental from acquired operations with grandfathered benefits, are currently accruing benefits under these plans.
Pension costs for2021, were not material to Occidental’s defined benefit pension plans, determined by independent actuarial valuations, are generally funded by payments to trust funds, which are administered by independent trustees.
POSTRETIREMENT AND OTHER BENEFIT PLANS
Occidental provides medical and dental benefits and life insurance coverage for certain active, retired and disabled employees and their eligible dependents. Occidental generally funds the benefits as they are paid during the year. These
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
benefit costs, including the postretirement costs, were approximately $235 million in 2020, $220 million in 2019 and $182 million in 2018.
OBLIGATIONS AND FUNDED STATUS
The following tables show the amounts recognized in Occidental’s consolidated balance sheets at December 31, 2020 and 2019, related to its pension and postretirement benefit plans:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2020 | | 2019 | | 2020 | | 2019 |
| Amounts recognized in the consolidated balance sheet: | | | | | | | | |
| Long-term receivables and other assets, net | | $ | 167 | | | $ | 149 | | | $ | 0 | | | $ | 0 | |
| Accrued liabilities | | (9) | | | (96) | | | (74) | | | (72) | |
| Deferred credits and other liabilities — pension and postretirement obligations | | (578) | | | (720) | | | (1,185) | | | (1,103) | |
| | | $ | (420) | | | $ | (667) | | | $ | (1,259) | | | $ | (1,175) | |
| Accumulated other comprehensive loss included the following after-tax balances: | | | | | | | | |
| Net (gain) loss | | $ | (3) | | | $ | (20) | | | $ | 226 | | | $ | 184 | |
| Prior service credit | | 0 | | | 0 | | | (60) | | | (67) | |
| | | $ | (3) | | | $ | (20) | | | $ | 166 | | | $ | 117 | |
The following tables show the funding status, obligations and plan asset fair values of Occidental related to its pension and postretirement benefit plans for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2020 | | 2019 | | 2020 | | 2019 |
| Changes in the benefit obligation: | | | | | | | | |
| Benefit obligation — beginning of year | | $ | 2,508 | | | $ | 499 | | | $ | 1,175 | | | $ | 808 | |
| Service cost — benefits earned during the period | | 37 | | | 47 | | | 39 | | | 24 | |
| Interest cost on projected benefit obligation | | 52 | | | 40 | | | 37 | | | 36 | |
| Actuarial (gain) loss | | 251 | | | (41) | | | 73 | | | 45 | |
| Curtailment (gain) loss | | (278) | | | (136) | | | 2 | | | 10 | |
| Special termination benefits | | 23 | | | 49 | | | 0 | | | 0 | |
| Benefits paid | | (948) | | | (99) | | | (73) | | | (51) | |
| Sale of Colombia assets | | (24) | | | 0 | | | 0 | | | 0 | |
| Additions due to the Acquisition | | 0 | | | 2,136 | | | 0 | | | 301 | |
| Other | | (8) | | | 13 | | | 6 | | | 2 | |
| Benefit obligation — end of year | | $ | 1,613 | | | $ | 2,508 | | | $ | 1,259 | | | $ | 1,175 | |
| | | | | | | | |
| Changes in plan assets: | | | | | | | | |
| Fair value of plan assets — beginning of year | | $ | 1,841 | | | $ | 539 | | | $ | 0 | | | $ | 0 | |
| Actual return on plan assets | | 161 | | | 110 | | | 0 | | | 0 | |
| Employer contributions | | 146 | | | 41 | | | 67 | | | 49 | |
| Benefits paid | | (948) | | | (99) | | | (73) | | | (51) | |
| Additions due to the Acquisition | | 0 | | | 1,233 | | | 0 | | | 0 | |
| Other | | (7) | | | 17 | | | 6 | | | 2 | |
| Fair value of plan assets — end of year | | $ | 1,193 | | | $ | 1,841 | | | $ | 0 | | | $ | 0 | |
| Unfunded status: | | $ | (420) | | | $ | (667) | | | $ | (1,259) | | | $ | (1,175) | |
| | | | | |
108100 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
ChangesIf unfavorable outcomes of these matters were to occur, future results of operations or cash flows for any particular quarterly or annual period could be materially adversely affected. Occidental’s estimates are based on information known about the legal matters and its experience in actuarial gainscontesting, litigating and settling similar matters. Occidental reassesses the probability and estimability of contingent losses in the projected benefit obligation are primarily driven by discount rate movement.
The following table sets forth details of the obligations and assets of Occidental’s defined benefit pension plans for the years December 31:as new information becomes available.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Accumulated Benefit
Obligation in Excess of
Plan Assets | | Plan Assets in
Excess of Accumulated
Benefit Obligation |
| millions | | 2020 | | 2019 | | 2020 | | 2019 |
| Projected benefit obligation | | $ | 1,226 | | | $ | 2,191 | | | $ | 387 | | | $ | 317 | |
| Accumulated benefit obligation | | $ | 1,221 | | | $ | 1,931 | | | $ | 379 | | | $ | 311 | |
| Fair value of plan assets | | $ | 670 | | | $ | 1,375 | | | $ | 523 | | | $ | 466 | |
In 2016, Occidental received payments from the Republic of Ecuador of approximately $1.0 billion pursuant to a November 2015 arbitration award for Ecuador’s 2006 expropriation of Occidental’s Participation Contract for Block 15. The awarded amount represented a recovery of Occidental’s 60% of the value of Block 15. In 2017, Andes commenced an arbitration, against OEPC, claiming it is entitled to a 40% share of the judgment amount obtained by Occidental. Occidental contended that Andes is not entitled to any of the amounts paid under the 2015 arbitration award because Occidental’s recovery was limited to Occidental’s own 60% economic interest in the block. On March 26, 2021, the arbitration tribunal issued an award in favor of Andes and against OEPC in the amount of $391 million plus interest. In June 2021, OEPC filed a motion to vacate the award due to concerns regarding the validity of the award. In December 2021, the U.S. District Court for the Southern District of New York confirmed the arbitration award, plus prejudgment interest, in the aggregate amount of $558 million. OEPC has appealed the judgment. Oral argument with respect to OEPC’s appeal occurred on February 2, 2023, and a ruling is expected later this year. Andes has filed state court claims in New York and Delaware against OEPC, OPC, and OXY USA to attempt to recover on its judgment against OEPC during the pendency of the appeal. All Occidental entities are vigorously defending against these actions. In addition, OEPC commenced an arbitration against Andes to recover significant additional claims not addressed by the prior arbitration tribunal relating to Andes' 40% share of costs, liabilities, losses and expenses due under the parties’ agreements. A hearing on these claims occurred in December 2022. A ruling from the arbitration tribunal is expected in the first half of 2023.
COMPONENTS OF NET PERIODIC BENEFIT COSTALDEN LEEDS LITIGATION
In December 2022, the EPA and the DOJ filed a proposed Consent Decree with the Federal District Court in New Jersey in the Alden Leeds litigation seeking court approval of a proposed settlement in which the EPA seeks to release 85 potentially responsible parties from all remediation costs in OU2 and OU4 of the DASS for approximately $150 million. OxyChem believes the proposed settlement relies, improperly, on an allocation report prepared by an EPA contractor in which the contractor purports to assign a disproportionate share of the responsibility for remediation costs in OU2 and OU4 to OxyChem. In the proposed settlement, the EPA also seeks to bar OxyChem from pursuing contribution claims against the 85 settling parties for remediation costs in OU2 and OU4. The settlement does not address the liability of any party with respect to OU3 or natural resource damages. OxyChem intends to contest the proposed settlement vigorously.
The following table sets forthproposed EPA settlement is subject to a public comment process that closes in March 2023. OxyChem believes the componentsproposed settlement exceeds the EPA’s statutory authority and is based on a flawed allocation process. OxyChem also believes that process was unreasonably limited in scope and unreliably based on voluntary reporting by the settling parties, instead of net periodic benefitsworn evidence, publicly available sampling results, and historical documents reflecting the operating history and disposal practices of the 85 parties that the EPA proposes to release as part of this settlement. OxyChem expects to show that the EPA’s proposed settlement does not fairly and reasonably reflect the settling parties’ contribution of hazardous substances to the DASS, and, among other things, incorrectly attributes to OxyChem substances that were contributed by one or more of the 85 settling parties.
OxyChem has sought to intervene in the Alden Leeds proceeding to protect its rights under federal law to challenge the proposed settlement, seek contribution and cost recovery from potentially responsible parties, and obtain a judicial allocation of responsibility under CERCLA. It is unclear when the Court will rule on OxyChem’s request to intervene or will address whether the underlying settlement will be approved. In the related CERCLA litigation, OxyChem also intends to defend and prosecute vigorously its right to seek contribution and cost recovery from all potentially responsible parties to pay remediation costs forin the years ended December 31:DASS. As the Alden Leeds case is in its early stages, OxyChem is unable to estimate the timing of the Court’s decision, its outcome, or the outcome of any appeals from the Court’s decision.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Benefits | | Postretirement Benefits |
| millions | | 2020 | | 2019 | | 2018 | | 2020 | | 2019 | | 2018 |
| Net periodic benefit costs: | | | | | | | | | | | | |
| Service cost — benefits earned during the period | | $ | 37 | | | $ | 47 | | | $ | 5 | | | $ | 39 | | | $ | 24 | | | $ | 23 | |
| Interest cost on projected benefit obligation | | 52 | | | 40 | | | 15 | | | 37 | | | 36 | | | 34 | |
| Expected return on plan assets | | (73) | | | (52) | | | (25) | | | 0 | | | 0 | | | 0 | |
| Recognized actuarial loss | | 5 | | | 9 | | | 7 | | | 11 | | | 8 | | | 14 | |
| Recognized prior service credit | | 0 | | | 0 | | | 0 | | | (8) | | | (8) | | | 0 | |
| (Gain) loss due to curtailment | | (124) | | | (91) | | | 0 | | | 2 | | | 6 | | | 0 | |
| Gain due to settlement | | (19) | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | |
| Special termination benefits | | 22 | | | 49 | | | 0 | | | 0 | | | 0 | | | 0 | |
| Other costs and adjustments | | 1 | | | (2) | | | 1 | | | 0 | | | 0 | | | (2) | |
| Net periodic benefit cost | | $ | (99) | | | $ | 0 | | | $ | 3 | | | $ | 81 | | | $ | 66 | | | $ | 69 | |
The service cost componentNote 12 – Environmental Liabilities and Expenditures, Maxus was contractually obligated to indemnify, defend, and hold harmless OxyChem against environmental liabilities arising from the former operations of net periodic benefit cost is includedDSCC. In June 2016, Maxus filed for bankruptcy protection in selling, general and administrative, oil and gas operating expense, chemical and midstream costs and exploration expense on Occidental’s Consolidated Statements of Operations. All other components of net periodic benefit cost are included in other operating and non-operating expense.
ADDITIONAL INFORMATION
The following table sets forth the weighted-average assumptions used to determine Occidental’s benefit obligation and net periodic benefit cost for domestic plansU.S. Bankruptcy Court for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Pension Benefits | | Postretirement Benefits |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Benefit Obligation Assumptions: | | | | | | | | |
| Discount rate | | 2.19 | % | | 3.09 | % | | 3.05 | % | | 3.26 | % |
| Rate of increase in compensation levels | | 5.07 | % | | 5.32 | % | | 0 | | | 0 | |
| Net Periodic Benefit Cost Assumptions: | | | | | | | | |
| Discount rate | | 3.04 | % | | 3.22 | % | | 3.26 | % | | 3.41 | % |
| Rate of increase in compensation levels | | 5.34 | % | | 5.35 | % | | 0 | | | 0 | |
| Assumed long-term rate of return on assets | | 6.02 | % | | 6.03 | % | | 0 | | | 0 | |
For domestic pension plansDistrict of Delaware. In June 2017, the Bankruptcy Court approved a Plan of Liquidation to liquidate Maxus and postretirement benefit plans, Occidental basedcreate the discount rate on a AA-AAA Universe yield curve in 2020 and 2019. The assumed long-term rate of return on assets is estimated with regard to current market
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
factors but within the context of historical returnsTrust for the asset mix that exists at year end. Assumed ratesbenefit of compensation increases for active participants inMaxus’ creditors, including OxyChem, to pursue claims against Maxus’ current and former parents, YPF and Repsol, certain plansof their respective subsidiaries and varyaffiliates, and others to satisfy claims by age group.
In 2020, Occidental adopted the Society of Actuaries Pri-2012 Private Retirement Plans Mortality Tables with MP-2020 Mortality Improvement Scale, which updated the mortality assumptions that private defined-benefit plans in the United States use in the actuarial valuations that determine a plan sponsor’s pension obligations. The new mortality assumption reflects additional data that the Social Security Administration has released since the previous mortality tables and improvement scales were released. The changes in the mortality improvement scale results in a decrease of $8 million and $12 million in the pension and postretirement benefit obligation, respectively, at December 31, 2020.
The postretirement benefit obligation was determined by application of the terms of medical and dental benefits and life insurance coverage, including the effect of established maximums on covered costs, together with relevant actuarial assumptions and health care cost trend rates. Health care cost trend rates for Medicare advantaged prescription drug (MAPD) plans of 9.6% starting in 2021, then grading down to 4.5% in 2028 and beyond. Health care cost trend rates used for non-MAPD plans are 6.5% to 7.0% in 2020, then grading down to 4.5% in 2028 and beyond.
The actuarial assumptions used could change in the near-term as a result of changes in expected future trendsOxyChem and other factors that, depending oncreditors for past and future remediation and other costs. In July 2017, the naturecourt-approved Plan of Liquidation became final and the changes, could cause increases or decreasesTrust became effective. Pursuant to the Plan, the Trust is governed by an independent trustee and is not controlled by OxyChem. The Plan authorizes the Trust to distribute any assets it recovers from such litigation claims to the Trust’s beneficiaries, which include OxyChem and other creditors, in accordance with the plan assetsPlan and liabilities.
FAIR VALUE OF PENSION PLAN ASSETS
Qualified defined benefit plan assets are monitored by Occidental’s Pension and Retirementgoverning Trust and Investment Committee in its role as a fiduciary. The Investment Committee selects and employs various external professional investment management firms to manage specific investments across the spectrum of asset classes. The Investment Committee employs a liability driven investment approach that uses a diversified blend of investments (equity securities, fixed-income securities, and alternative investments) along a glide path to optimize the long-term return of plan assets relative to plan liabilities, at a prudent level of risk. Equity investments are diversified across U.S. and non-U.S. stocks, as well as differing styles and market capitalizations. Investment performance is measured and monitored on an ongoing basis through quarterly investment portfolio and manager guideline compliance reviews, annual liability measurements and periodic studies.
The fair values of Occidental’s pension plan assets by asset category were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | Level 1 | | Level 2 | | Level 3 | | Total |
| December 31, 2020 | | | | | | | | |
| Asset Class: | | | | | | | | |
| Cash and cash equivalents | | $ | 38 | | | $ | 0 | | | $ | 0 | | | $ | 38 | |
| Government securities | | 65 | | | 0 | | | 0 | | | 65 | |
Corporate bonds (a) | | 0 | | | 39 | | | 0 | | | 39 | |
Equity securities (b) | | 138 | | | 0 | | | 0 | | | 138 | |
| Other | | 0 | | | 55 | | | 0 | | | 55 | |
| Investments measured at fair value | | $ | 241 | | | $ | 94 | | | $ | 0 | | | $ | 335 | |
Investments measured at net asset value (c) | | — | | | — | | | — | | | 861 | |
Total pension plan assets (d) | | $ | 241 | | | $ | 94 | | | $ | 0 | | | $ | 1,196 | |
| | | | | | | | |
| December 31, 2019 | | | | | | | | |
| Asset Class: | | | | | | | | |
| Cash and cash equivalents | | $ | 42 | | | $ | 0 | | | $ | 0 | | | $ | 42 | |
| Government securities | | 63 | | | 0 | | | 0 | | | 63 | |
Corporate bonds (a) | | 0 | | | 94 | | | 0 | | | 94 | |
Equity securities (b) | | 311 | | | 0 | | | 0 | | | 311 | |
| Other | | 0 | | | 81 | | | 0 | | | 81 | |
| Investments measured at fair value | | $ | 416 | | | $ | 175 | | | $ | 0 | | | $ | 591 | |
Investments measured at net asset value (c) | | — | | | — | | | — | | | 1,253 | |
Total pension plan assets (d) | | $ | 416 | | | $ | 175 | | | $ | 0 | | | $ | 1,844 | |
(a)This category represents investment grade bonds of U.S. and non-U.S. issuers from diverse industries.
(b)This category represents direct investments in mutual funds and common and preferred stocks from diverse U.S. and non-U.S. industries.
| | | | | |
110 | OXY 20202022 FORM 10-K | 101 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
In June 2018, the trust filed its complaint against YPF and Repsol in Delaware Bankruptcy Court asserting claims based upon, among other things, fraudulent transfer and alter ego. During 2019, the Bankruptcy Court denied Repsol's and YPF's motions to dismiss the complaint as well as their motions to move the case to a different court. These rulings were upheld on appeal. The Trust, YPF, and Repsol each filed motions for summary judgment, and the Bankruptcy Court denied all but one motion in the second quarter of 2022. The Bankruptcy Court’s summary judgment decision indicated that, at trial, the Trust must establish a causal link between its claimed damages and the alter ego conduct of Repsol and YPF. OxyChem is currently uncertain what amount of recovery it will ultimately obtain from the Trust. Trial is scheduled for March and April 2023.
(c)
Certain investments measured at fair value using
TAX MATTERS
During the course of its operations, Occidental is subject to audit by tax authorities for varying periods in various federal, state, local and international tax jurisdictions. Tax years through 2020 for U.S. federal income tax purposes have been audited by the IRS pursuant to its Compliance Assurance Program and subsequent taxable years are currently under review. Tax years through 2014 have been audited for state income tax purposes. Significant audit matters in international jurisdictions have been resolved through 2010. During the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law.
For Anadarko, its taxable years through 2014 and tax year 2016 for U.S. federal tax purposes have been audited by the IRS. Tax years through 2010 have been audited for state income tax purposes. There is one outstanding significant tax matter in an international jurisdiction related to a discontinued operation. As stated above, during the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law.
Other than the matter discussed below, Occidental believes that the resolution of these outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations.
Anadarko received an $881 million tentative refund in 2016 related to its $5.2 billion Tronox Adversary Proceeding settlement payment in 2015. In September 2018, Anadarko received a statutory notice of deficiency from the IRS disallowing the net asset value per share (oroperating loss carryback and rejecting Anadarko’s refund claim. As a result, Anadarko filed a petition with the U.S. Tax Court to dispute the disallowances in November 2018. In December 2022, the parties filed competing motions for partial summary judgment. The motions are not fully briefed. Trial is set for May 2023. Occidental expects to continue pursuing resolution.
In accordance with ASC 740’s guidance on the accounting for uncertain tax positions, Occidental has recorded no tax benefit on the tentative cash tax refund of $881 million. As a result, should Occidental not ultimately prevail on the issue, there would be no additional tax expense recorded relative to this position for financial statement purposes other than future interest. However, in that event, Occidental would be required to repay approximately $1.4 billion in federal taxes, $28 million in state taxes and accrued interest of $415 million. A liability for this amount plus interest is included in deferred credits and other liabilities - other.
INDEMNITIES TO THIRD PARTIES
Occidental, its equivalent)subsidiaries, or both, have not been categorizedindemnified various parties against specified liabilities those parties might incur in the fair value hierarchy. Amounts presentedfuture in this tableconnection with purchases and other transactions that they have entered into with Occidental or its subsidiaries. These indemnities usually are intendedcontingent upon the other party incurring liabilities that reach specified thresholds. As of December 31, 2022, Occidental is not aware of circumstances that it believes would reasonably be expected to reconcile the fair value hierarchylead to the pension plan assets.indemnity claims that would result in payments materially in excess of reserves.
(d)Amounts exclude net payables of approximately $3 millionPURCHASE OBLIGATIONS AND COMMITMENTS
Occidental, its subsidiaries, or both, have entered into agreements providing for future payments, primarily to secure terminal and pipeline capacity, and also for drilling rigs and services, electrical power, steam and certain chemical raw materials. Occidental has certain other commitments under contracts, guarantees and joint ventures, including purchase commitments for goods and services at market-related prices and certain other contingent liabilities. The amounts that will be paid for such outstanding off-balance sheet purchase obligations as of December 31, 20202022 are $3.0 billion in 2023, $4.2 billion in 2024 and 2019.2025, $2.5 billion in 2026 and 2027 and $2.2 billion in 2028 and thereafter.
Occidental expects to contribute at least approximately $170 million in cash to its defined benefit pensions plans during 2021.
Estimated future benefit payments, which reflect expected future service, as appropriate, are as follows for the years ended December 31:
| | | | | | | | | | | | | | |
| millions | | Pension
Benefits | Postretirement Benefits |
| 2021 | | $ | 251 | | | $ | 75 | |
| 2022 | | 96 | | | 73 | |
| 2023 | | 93 | | | 71 | |
| 2024 | | 95 | | | 69 | |
| 2025 | | 90 | | | 67 | |
| 2026 - 2030 | | 399 | | | 312 | |
| | |
NOTE 16 - INVESTMENTS AND RELATED-PARTY TRANSACTIONS |
EQUITY INVESTMENTS
As of December 31, 2020, and 2019, investments in unconsolidated entities were $3.3 billion and $6.4 billion, respectively. As of December 31, 2020, Occidental’s significant equity investments primarily consisted of the following:
| | | | | | | | | | | | | | |
| millions | | % Interest | | Carrying amount |
WES (a) | | 53.5 | % | | $ | 1,930 | |
| OxyChem Ingleside Facility | | 50.0 | % | | 635 | |
| Dolphin Energy Limited | | 24.5 | % | | 290 | |
| Other | | various | | 395 | |
| Total | | | | $ | 3,250 | |
(a) During most of 2019, WES was a consolidated variable interest entity. On December 31, 2019, Occidental unconsolidated WES. See Note 1 - Summary of Significant Accounting Policies for more information on the accounting treatment and resulting equity interest. In the first quarter of 2020, Occidental recorded an impairment of $1.2 billion in goodwill related to its ownership in WES and in the third quarter of 2020, recorded an other than temporary impairment of $2.7 billion related to the WES equity method investment. See Note 17 - Fair Value Measurements for more information on the impairments.
As of December 31, 2020 and 2019, Occidental’s significant equity investments consisted of investments in WES, OxyChem Ingleside Facility and Dolphin Energy Limited.
As part of the Acquisition, Occidental acquired equity investments in certain oil and gas properties and gathering and processing assets and assumed an associated notes payable which Occidental has the legal right of setoff and intends to net settle with its ownership interest in the equity investments. The notes payable can be net settled starting in 2022. The carrying value of the investment and note payable were $2.9 billion at December 31, 2020, respectively. Accordingly, the equity investments and the related notes payable are presented net on the Consolidated Balance Sheets.
Dividends received from equity investments were $678 million, $422 million and $329 million to Occidental in 2020, 2019 and 2018, respectively. As of December 31, 2020 and 2019, cumulative undistributed earnings of equity-method investees since they were acquired was $166 million and $40 million, respectively. As of December 31, 2020, Occidental’s investments in equity investees exceeded the underlying equity in net assets by approximately $649 million, of which, $326 million represented property, plant and equipment and equity investments with the remainder comprised of intangibles, both are subject to amortization over their estimated average lives.
| | | | | |
| 102 | OXY 20202022 FORM 10-K | 111 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
| | |
| NOTE 14 - STOCKHOLDERS’ EQUITY |
The following table presents the effects of Occidental's share repurchases as part of the $3.0 billion stock repurchase plan announced in February 2022, along with other transactions in Occidental's stock:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Exercise of Warrants and Options | (a) | Other | (b) | Treasury Stock Purchases | (c) | Common Stock Outstanding | (d) |
| December 31, 2021 | | | | | | | | 934,074,700 | | |
| First Quarter 2022 | | 1,082,282 | | | 2,764,746 | | | (730,746) | | | 937,190,982 | | |
| Second Quarter 2022 | | 3,409,920 | | | 42,342 | | | (11,679,732) | | | 928,963,512 | | |
| Third Quarter 2022 | | 7,667,545 | | | 18,280 | | | (28,571,576) | | | 908,077,761 | | |
| Fourth Quarter 2022 | | 86,309 | | | 18,108 | | | (8,323,234) | | | 899,858,944 | | |
| Total 2022 | | 12,246,056 | | | 2,843,476 | | | (49,305,288) | | | 899,858,944 | | |
(a) Approximately $280 million of cash was received as a result of the exercise of common stock warrants and options.
(b) Consisted of issuances for the 2015 long-term incentive plan, the OPC savings plan, dividend reinvestment plan and Anadarko restricted stock awards.
(c) Included purchases of 1,640,719 shares from the trustee of Occidental's defined contribution savings plan that are not part of publicly announced plans or programs.
(d) As of December 31, 2022, Occidental had 104 million outstanding warrants with a strike of $22 per share and 83.9 million of warrants with a strike of $59.62 per share.
TREASURY STOCK
Under the share repurchase program announced and completed in 2022, Occidental purchased 47.7 million shares for $3.0 billion. Additionally, Occidental purchased shares from the trustee of its defined contribution savings plan in 2022, 2021 and 2020. As of December 31, 2022, 2021 and 2020, treasury stock shares numbered 198.7 million, 149.3 million and 149.1 million, respectively.
PREFERRED STOCK
In connection with the Anadarko Acquisition, Occidental issued 100,000 shares of series A preferred stock, having a face value of $100,000 per share and a liquidation preference of $105,000 per share plus unpaid accrued dividends. The agreement includes a mandatory redemption provision that obligates Occidental to redeem the preferred at 110% of the par value on a dollar-for-dollar basis for every dollar distributed to common shareholders above $4.00 per share, on a trailing 12-month basis. Occidental cannot voluntarily redeem the preferred shares before August 2029. After August 2029, Occidental can voluntarily redeem the preferred shares at a 5% premium at par. Dividends on the preferred stock will accrue on the face value at a rate per annum of 8%, but will be paid only when, as and if declared by Occidental’s Board of Directors. At any time, when such dividends have not been paid in full, the unpaid amounts will accrue dividends, compounded quarterly, at a rate per annum of 9%. Following the payment in full of any accrued but unpaid dividends, the dividend rate will remain at 9% per annum. If preferred dividends are not paid in full, Occidental is prohibited from paying dividends on common stock. Occidental paid $200 million in preferred stock dividends in each quarter of 2022.
As of December 31, 2022, 2021 and 2020, Occidental had 100,000 shares of preferred stock issued and outstanding.
BERKSHIRE WARRANT
In connection with the preferred stock issuance, Occidental also issued the Berkshire Warrant. The Berkshire Warrant is exercisable at the holder’s option, in whole or in part, until the first anniversary of the date on which no shares of preferred stock remain outstanding, at which time the Berkshire Warrant expires. The holder of the Berkshire Warrant and the preferred stock may redeem the preferred stock as payment for the exercise price of the Warrant in lieu of cash payment upon exercise. As of December 31, 2022, the Berkshire warrant would result in the issuance of 83.9 million shares of Occidental common stock, if exercised in full for its current strike price of $59.624 per share of Occidental common stock.
COMMON STOCK WARRANTS
On June 26, 2020, the Board of Directors declared Common Stock Warrants, at a rate of 0.125 warrants per share of Occidental common stock. Occidental issued approximately 116 million Common Stock Warrants on August 3, 2020 to holders of record of outstanding shares of Occidental’s common stock as of the close of business on July 6, 2020, and pursuant to Occidental’s outstanding equity-based incentive awards in connection with anti-dilution adjustments resulting from such distribution. The Common Stock Warrants have an exercise price of $22.00 per share and will expire on August 3, 2027. The Common Stock Warrants are listed on the NYSE and trade under the symbol "OXY WS".
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
The Common Stock Warrants were measured at fair value on the declaration date using the Black-Scholes option model and were classified as equity in "Additional paid-in capital". The following level 2 inputs were used in the Black-Scholes option model: the expected life of the Common Stock Warrants, a volatility factor and the exercise price. The expected life is based on the estimated term of the Common Stock Warrants, the volatility factor is based on historical volatilities of Occidental common stock and the exercise of $22.00 per share of Occidental common stock.
EARNINGS PER SHARE
Occidental’s instruments containing rights to nonforfeitable dividends granted in stock-based awards are considered participating securities prior to vesting and, therefore, have been deducted from earnings in computing basic and diluted EPS under the two-class method.
Basic EPS was computed by dividing net income attributable to common stock, net of income allocated to participating securities, by the weighted-average number of common shares outstanding during each period, including vested but unissued shares and share units. The computation of diluted EPS reflects the additional dilutive effect of stock options, warrants and unvested stock awards.
The following table presents the summarized financial informationcalculation of its equity-method investments combined for the years endedbasic and as of December 31:
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
Summarized Results of Operations (a) | | | | | | |
| Revenues and other income | | $ | 5,455 | | | $ | 26,520 | | | $ | 28,091 | |
| Costs and expenses | | 5,455 | | | 24,084 | | | 25,029 | |
| Net income | | $ | 0 | | | $ | 2,436 | | | $ | 3,062 | |
| | | | | | |
| Summarized Balance Sheet | | | | | | |
| Current assets | | $ | 1,419 | | | $ | 1,130 | | | $ | 5,587 | |
| Non-current assets | | $ | 18,693 | | | $ | 21,158 | | | $ | 25,871 | |
| Current liabilities | | $ | 1,549 | | | $ | 785 | | | $ | 4,879 | |
| Long-term debt | | $ | 7,860 | | | $ | 8,673 | | | $ | 12,505 | |
| Other non-current liabilities | | $ | 866 | | | $ | 859 | | | $ | 95 | |
| Stockholders’ equity | | $ | 9,837 | | | $ | 11,971 | | | $ | 13,979 | |
(a)The 2019 Summarized Results of Operations include results of Plains for the period beginning January 1, 2019 through the date Occidental’s interest was sold in September 2019. Plains accounted for $24.7 billion of equity-method investment revenues and other income in 2019.
RELATED-PARTY TRANSACTIONS
From time to time, Occidental purchases oil, NGL, power, steam and chemicals from and sells oil, NGL, natural gas, chemicals and power to certain of its equity investees and other related parties. During 2020, 2019 and 2018, Occidental entered into the following related-party transactions and had the following amounts due from or to its related partiesdiluted EPS for the years ended December 31:
| | | | | | | | | | | | | | | | | | | | |
| millions | | 2020 | | 2019 | | 2018 |
Sales (a,c) | | $ | 301 | | | $ | 691 | | | $ | 805 | |
Purchases (b,c) | | $ | 1,112 | | | $ | 463 | | | $ | 502 | |
Services (d) | | $ | 1,032 | | | $ | 28 | | | $ | 52 | |
| Advances and amounts due from related parties | | $ | 54 | | | $ | 133 | | | $ | 63 | |
| Amounts due to related parties | | $ | 273 | | | $ | 463 | | | $ | 46 | |
| | | | | | | | | | | | | | | | | | | | |
| millions except per share amounts | | 2022 | | 2021 | | 2020 |
| Income (loss) from continuing operations | | $ | 13,304 | | | $ | 2,790 | | | $ | (13,533) | |
| Loss from discontinued operations | | — | | | (468) | | | (1,298) | |
| Net income (loss) | | $ | 13,304 | | | $ | 2,322 | | | $ | (14,831) | |
| | | | | | |
| Less: Preferred stock dividends | | (800) | | | (800) | | | (844) | |
| Net income (loss) attributable to common stock | | $ | 12,504 | | | $ | 1,522 | | | $ | (15,675) | |
| Less: Net income allocated to participating securities | | (83) | | | (10) | | | — | |
| Net income (loss), net of participating securities | | $ | 12,421 | | | $ | 1,512 | | | $ | (15,675) | |
| Weighted-average number of basic shares | | 926.2 | | | 935.0 | | | 918.7 | |
| Basic earnings (loss) per common share | | $ | 13.41 | | | $ | 1.62 | | | $ | (17.06) | |
| Net income (loss) attributable to common stock | | $ | 12,504 | | | $ | 1,522 | | | $ | (15,675) | |
| Less: Net income allocated to participating securities | | (77) | | | (10) | | | — | |
| Net income (loss), net of participating securities | | $ | 12,427 | | | $ | 1,512 | | | $ | (15,675) | |
| Weighted-average number of basic shares | | 926.2 | | | 935.0 | | | 918.7 | |
| Dilutive securities | | 75.8 | | | 23.8 | | | — | |
| Total diluted weighted-average common shares | | 1,002.0 | | | 958.8 | | | 918.7 | |
| Diluted earnings (loss) per common share | | $ | 12.40 | | | $ | 1.58 | | | $ | (17.06) | |
As of December 31, 2022, no potentially dilutive shares of Occidental common stock were excluded from the diluted shares. As of December 31, 2021, warrants and options covering 87 million shares of Occidental common stock were excluded from the diluted shares as their effect would have been anti-dilutive.
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
Accumulated OCI (loss) consisted of the following after-tax amounts as of December 31:
| | | | | | | | | | | | | | |
| millions | | 2022 | | 2021 |
| Foreign currency translation adjustments | | $ | (5) | | | $ | (8) | |
| Derivatives | | (25) | | | (104) | |
Pension and postretirement adjustments (a) | | 225 | | | (96) | |
| Total | | $ | 195 | | | $ | (208) | |
(a)In 2020, sales of Occidental-produced NGL and marketing fees to WES accounted for 70% of these totals. In 2019 and 2018, sales of Occidental-produced oil and NGL to Plains Pipeline affiliates accounted for 87% and 89% of these totals, respectively. In September 2019, Occidental sold its equity investment in Plains. See Note 411 - DivestituresRetirement and Other TransactionsPostretirement Benefit Plans for additionalfurther information. (b)In 2020, purchases of gas and NGL marketed on behalf of WES accounted for 59% of related-party purchases. In 2020, 2019 and 2018, purchases of ethylene from the Ingleside ethylene cracker accounted for 41%, 98% and 98% of related-party purchases, respectively.
(c)Excluded sales to and purchases from WES in 2019 as it was a consolidated subsidiary from the date of the Acquisition through December 31, 2019.
(d)In 2020, services primarily relates to fees charged by WES to gather, process and treat Occidental produced oil, NGL and natural gas.
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
| | |
NOTE 1715 - FAIR VALUE MEASUREMENTSSTOCK-BASED INCENTIVE PLANS |
FAIR VALUES – RECURRING
In January 2012, Occidental entered into a long-term contractissues stock-based awards to purchase CO2. This contract contains a price adjustment clauseemployees in accordance with the terms of the Plan, as amended and restated. An aggregate of 133 million shares of Occidental common stock were authorized for issuance and approximately 16.1 million shares had been reserved for issuance for employee awards through December 31, 2022. As of December 31, 2022, approximately 57.0 million shares were available for grants of future awards. The plan requires each share covered by an award (other than options) to be counted as if three shares were issued in determining the number of shares that is linkedare available for future awards. Accordingly, the number of shares available for future awards may be less than 57.0 million depending on the type of award granted, and shares available for future awards may increase by the number of shares that are forfeited, canceled, or correspond to changes in NYMEX oil prices. Occidental determined that the portion of this contract linked to NYMEX oil prices is not clearlyany stock-based awards settled in cash, including awards that were issued under a previous plan that remain outstanding. Current outstanding awards include RSUs, stock options, CROCEI awards and closelyTSRI awards.
During 2022, non-employee directors were granted awards for 33,575 shares of common stock. Compensation expense for these awards was measured using the closing quoted market price of Occidental’s common stock on the grant date and was fully recognized at that time.
Occidental incurred expenses of $258 million, $287 million and $202 million related to stock-based incentive plans in the host contract,years ended December 31, 2022, 2021, and Occidental therefore bifurcated2020, respectively. The income tax benefit associated with this embedded pricing feature from its host contractexpense was $54 million, $60 million and $42 million in the years ended December 31, 2022, 2021, and 2020, respectively.
As of December 31, 2022, unrecognized compensation expense for all unvested stock-based incentive awards was $236 million. This expense is expected to be recognized over a weighted-average period of 1.8 years. Occidental accounts for it atforfeitures as they occur.
RESTRICTED STOCK UNITS
Certain employees are awarded the right to receive RSUs, some of which have performance criteria, and are in the form of, or equivalent in value to, actual shares of Occidental common stock. Depending on their terms, RSUs may be settled in stock or may be cash settled liabilities. These awards vest from one to three years following the grant date. For certain RSUs, dividend equivalents are paid during the vesting period.
CASH-SETTLED RSU LIABILITY AWARDS
The weighted-average, grant-date fair values of cash-settled RSUs granted in 2022, 2021 and 2020 were $47.41, $25.83 and $40.86 per share, respectively. Cash-settled RSUs resulted in payments of $203 million, $4 million and $3 million, during the years ended December 31, 2022, 2021 and 2020, respectively.
STOCK-SETTLED RSU EQUITY AWARDS
The weighted-average, grant-date fair values of the stock-settled RSUs granted in 2022, 2021, and 2020 were $45.14, $25.45 and $41.60, respectively. The fair value of RSUs settled in shares during the consolidated financial statements.years ended December 31, 2022, 2021 and 2020 was $160 million, $70 million and $62 million, respectively.
A summary of changes in Occidental’s unvested cash- and stock-settled RSUs during the year ended December 31, 2022, is presented below:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Cash-Settled | | Stock-Settled |
| thousands, except fair values | | RSUs | | Weighted-Average
Grant-Date
Fair Value | | RSUs | | Weighted-Average
Grant-Date
Fair Value |
| Unvested as of January 1 | | 5,375 | | | | $ | 41.44 | | | 8,589 | | | | $ | 33.10 | |
| Granted | | 150 | | | | $ | 47.41 | | | 4,362 | | | | $ | 45.14 | |
| Vested | | (5,188) | | | | $ | 41.86 | | | (3,654) | | | | $ | 38.04 | |
| Forfeitures | | (39) | | | | $ | 35.80 | | | (403) | | | | $ | 39.09 | |
| Unvested as of December 31 | | 298 | | | | $ | 37.96 | | | 8,894 | | | | $ | 36.70 | |
TOTAL SHAREHOLDER RETURN INCENTIVE AWARDS
Certain executives are awarded TSRIs that vest at the end of a three-year period following the grant date. Payout is based upon Occidental’s absolute total shareholder return and performance relative to its peers. TSRIs have payouts that range from 0% to 200% of the target award and settle in stock once certified. Dividend equivalents for TSRIs are accumulated and paid upon certification of the award. The fair value of TSRIs settled in shares during the years ended December 31, 2022, 2021 and 2020 was zero, $4 million and $9 million, respectively.
| | | | | |
112 OXY 2022 FORM 10-K | 105 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
The fair values of TSRIs are initially determined on the grant date using a Monte Carlo simulation model based on Occidental’s assumptions, noted in the following table, and the volatility from corresponding peer group companies. The expected life is based on the Term. The risk-free interest rate is the implied yield available on zero coupon Treasury notes at the time of grant with a remaining term equal to the Term. The dividend yield is the expected annual dividend yield over the Term, expressed as a percentage of the stock price on the grant date. Estimates of fair value may not accurately predict the value ultimately realized by the employees who receive the awards, and the ultimate value may not be indicative of the reasonableness of the original estimates of fair value made by Occidental.
The grant-date assumptions used in the Monte Carlo simulation models for the estimated payout level of TSRIs were as follows:
| | | | | | | | | | | | | | | | | | | | |
| | | TSRIs |
| | 2022 | | 2021 | | 2020 |
| Assumptions used: | | | | | | |
| Risk-free interest rate | | 1.7% | | 0.2% | | 1.4% |
| Volatility factor | | 80% | | 75% | | 26% |
| Expected life (years) | | 2.89 | | 2.88 | | 3.00 |
| Grant-date fair value of underlying Occidental common stock | | $ | 42.98 | | $ | 25.39 | | $ | 41.60 |
A summary of changes in Occidental’s unvested TSRIs during the year ended December 31, 2022 is presented below:
| | | | | | | | | | | | | | | | | |
| | | TSRIs |
| thousands, except fair values | | Awards | | Weighted-Average
Grant-Date Fair Value
of Occidental Stock |
| Unvested as of January 1 | | 1,769 | | | | $ | 43.12 | |
| Granted | | 403 | | | | $ | 42.98 | |
Vested (a) | | (520) | | | | $ | 67.19 | |
| Forfeitures | | (9) | | | | $ | 35.43 | |
| Unvested as of December 31 | | 1,643 | | | | $ | 35.51 | |
(a)Presented at the target payouts. No payouts occurred in 2022.
STOCK OPTIONS
Certain employees are granted options that vest over three years, expire on the tenth anniversary of the grant date, and settle in stock. Exercise prices of the options were equal to the quoted market value of Occidental’s stock on the grant date. The inputs to this and results of this model are presented below:
| | | | | | | | | | | | | | | | | | | | |
| | | Options |
| | 2022 | | 2021 | | 2020 |
| Assumptions used: | | | | | | |
| Risk-free interest rate | | 1.87% | | 0.7% | | 1.4% |
| Volatility factor | | 58% | | 55% | | 25% |
| Expected life (years) | | 6.02 | | 6.00 | | 6.00 |
| Dividend yield | | 0.09% | | 0.16% | | 7.60% |
| Exercise price | | $ | 42.98 | | $ | 25.39 | | $ | 41.60 |
| Grant-date fair value of underlying Occidental common stock | | $ | 23.39 | | $ | 12.72 | | $ | 3.19 |
| | | | | |
| 106 | OXY 20202022 FORM 10-K |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
The following tables provide fair value measurement information for assetsA summary of Occidental’s outstanding stock options as of December 31, 2022 and liabilities that are measured on a recurring basis:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | Fair Value Measurements Using | | Netting and Collateral | | Total Fair Value |
| Embedded derivatives | | Level 1 | | Level 2 | | Level 3 | | |
| December 31, 2020 | | | | | | | | | | |
| Accrued liabilities | | $ | 0 | | | $ | 64 | | | $ | 0 | | | $ | 0 | | | $ | 64 | |
| | | | | | | | | | |
| December 31, 2019 | | | | | | | | | | |
| Accrued liabilities | | $ | 0 | | | $ | 40 | | | $ | 0 | | | $ | 0 | | | $ | 40 | |
| Deferred credits and other liabilities - other | | $ | 0 | | | $ | 49 | | | $ | 0 | | | $ | 0 | | | $ | 49 | |
FAIR VALUES – NONRECURRING
The table below summarizes the significant impairments and other charges incurred to measure assets to their fair value on a nonrecurring basis throughoutchanges during the year ended December 31, 2020:2022 is presented below:
| | | | | | | | |
millions | | Total Fair Value |
Asset impairments and other charges | | |
Goodwill | | $ | 1,153 | |
Oil and gas properties - proved | | $ | 2,436 | |
Oil and gas properties - unproved | | $ | 4,591 | |
Oil and gas properties - discontinued operations | | $ | 2,191 | |
WES equity investment | | $ | 2,673 | |
| | | | | | | | | | | | | | | | | | | | |
| | | Vested | | Unvested |
| thousands, except fair values | | Options | Weighted Average Strike Price | | Options | Weighted Average Strike Price |
| January 1 | | 2,236 | | $ | 49.13 | | | 1,430 | | $ | 35.52 | |
| Granted | | — | | $ | — | | | 286 | | $ | 42.98 | |
| Vested | | 641 | | $ | 36.68 | | | (641) | | $ | 36.68 | |
| Forfeited | | (551) | | $ | 76.96 | | | — | | $ | — | |
| Exercised | | (673) | | $ | 39.78 | | | — | | $ | — | |
| December 31 | | 1,653 | | $ | 38.83 | | | 1,075 | | $ | 36.82 | |
GOODWILL
The intrinsic value of options exercised in 2022 was $17 million. No options were exercised during the years ended December 31, 2021 and 2020. As of December 31, 2019, Occidental had $1.2 billion of goodwill related to its ownership in WES, which was included in long-term receivables and other assets, net. Significant declines in the market value of WES’ publicly traded units resulted in management’s determination that, more likely than not, the fair value of the reporting unit was significantly less than its carrying value and2022, the remaining $1.2 billion in goodwilllife of fully vested options was fully impaired in the first quarter of 2020. The market value of WES’ publicly traded units is considered a Level 1 input.5.9 years.
OIL AND GAS PROPERTIESCASH RETURN ON CAPITAL EMPLOYED INCENTIVE AWARDS
InCertain executives are awarded CROCEI awards that vest at the second quarter 2020, asend of a resultthree-year period if performance targets based on CROCE are met. These awards are settled in stock upon certification of the expected prolonged period of lower commodity prices brought on by the COVID-19 pandemic’s impact on oil demand, Occidental tested substantially all of its oil and gas assets for impairment. Occidental recognized total pre-tax impairmentsperformance target, with payouts that range from 0% to its oil and gas proved and unproved properties of $8.6 billion, of which $6.4 billion is included in oil and gas segment results and $2.2 billion ($1.4 billion net of tax) related to Ghana is included in discontinued operations.
In the second quarter 2020, Occidental recorded proved property pre-tax impairments of $1.2 billion primarily related to certain assets for its domestic onshore and Gulf of Mexico assets and $0.9 billion to adjust the Algeria oil and gas proved properties to their fair value. The fair value200% of the proved properties was measured based ontarget award. Dividend equivalents are accumulated and paid upon certification of the income approach.
Unproved property pre-tax impairmentsaward. A summary of $4.3 billion were primarily related to domestic onshore unproved acreage. The fair value of this acreage was measured based on a market approach using an implied acreage valuation derived from domestic onshore market participants excludingchanges in Occidental’s unvested CROCEI during the fair value assigned to proved properties.
Income approaches are considered Level 3 fair value estimates and include significant assumptions of future production and timing of production, commodity price assumptions and operating and capital cost estimates, discounted using a 10 percent weighted average cost of capital. Taxes were based on current statutory rates. Future production and timing of productionyear ended December 31, 2022 is based on internal reserves estimates and internal economic models for a specific oil and gas asset. Internal reserve estimates consist of proved reserves and unproved reserves, the latter adjusted for uncertainty based on reserve category. Price assumptions were based on a combination of market information and published industry resources adjusted for historical differentials. Price assumptions ranged from approximately $40 per barrel of oil in 2020 increasing to approximately $70 per barrel of oil in 2034, with an unweighted arithmetic average price of $59.17 and $62.42 for WTI and Brent indexed assets for the 15 year period, respectively. Natural gas prices ranged from approximately $2.00 per Mcf in 2020 to approximately $3.60 per Mcf in 2034, with an unweighted arithmetic average price of $3.13 for NYMEX based assets for the 15 year period. Both oil and natural gas commodity prices were held flat after 2034 and were adjusted for location and quality differentials. Operating and capital cost estimates were based on current observable costs and were
| | | | | | | | | | | | | | | | | |
| | | CROCEI |
| thousands, except fair values | | Awards | | Weighted-Average
Grant-Date
Fair Value of Occidental Stock |
| Unvested as of January 1 | | 418 | | | | $ | 33.03 | |
| Granted | | 156 | | | | $ | 42.98 | |
| | | | | |
| | | | | |
| Unvested as of December 31 | | 574 | | | | $ | 35.73 | |
| | | | | |
OXY 20202022 FORM 10-K | 113107 |
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES | |
further escalated 1 percent in every period where commodity prices exceeded $50 per barrel and 2 percent in every period where commodity prices exceeded $60 per barrel. The weighted average cost of capital is calculated based on industry peers and best approximates the cost of capital an external market participant would expect to obtain.
In the first quarter 2020, Occidental's oil and gas segment recognized pre-tax impairment and related charges of $581 million primarily related to both proved and unproved oil and gas properties and a lower of cost or net realizable value adjustment for crude inventory. Occidental recorded proved property impairments of $293 million related to certain international assets and the Gulf of Mexico. Occidental recorded unproved property impairments, of approximately $241 million, primarily related to domestic onshore undeveloped leases and offshore Gulf of Mexico where Occidental no longer intends to pursue exploration, appraisal or development activities primarily due to the reduction in near-term capital plans.
If there is a further worsening of the macroeconomic conditions and if such worsened conditions are expected to be prolonged, Occidental’s oil and gas properties may be subject to further testing for impairment, which could result in additional non-cash asset impairments. Such impairments could be material to our financial statements.
WES EQUITY INVESTMENT
At the end of the third quarter 2020, Occidental recorded an other-than-temporary impairment of $2.7 billion, as the fair value of Occidental’s investment in WES has remained significantly lower than its book value for the majority of the nine months ended September 30, 2020. Occidental concluded that the difference between the fair value and book value of WES was not temporary, primarily given both the magnitude and the duration that the fair value was below its book value. This other-than-temporary impairment was calculated based on the closing market price of WES as of September 30, 2020. The market value of WES’ publicly traded common units is considered a Level 1 input.
2019
During 2019, Occidental measured assets and liabilities at acquisition-date fair value on a nonrecurring basis related to the Acquisition. See Note 3 - The Acquisition for more detail.In 2019, Occidental recorded a $1 billion charge as a result of recording Occidental’s equity investment in WES at fair value upon loss of control, see Note 1 - Summary of Significant Accounting Policies. Additionally, Occidental’s oil and gas segment recognized pre-tax impairment and related charges of $285 million related to domestic undeveloped leases that were set to expire in the near-term, where Occidental had no plans to pursue exploration activities, and $39 million related to Occidental’s mutually agreed early termination of its Qatar ISSD contract.
2018
During 2018, Occidental recognized pre-tax impairment and related charges of $416 million primarily related to Qatar ISND and ISSD proved properties and inventory. The fair value of the proved properties was measured based on the income approach, which incorporated a number of assumptions involving expectations of future cash flows.
FINANCIAL INSTRUMENTS FAIR VALUE
The carrying amounts of cash, cash equivalents, restricted cash, restricted cash equivalents and other on-balance sheet financial instruments, other than fixed-rate debt, approximate fair value. See Note 7 - Long-term Debt for the fair value of Long-term debt.
| | |
NOTE 1816 - INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS |
Occidental conducts its operations through 3three segments: (1) oil and gas; (2) chemical; and (3) midstream and marketing. The factors used to identify these segments are based on the nature of the operations that are undertaken in each segment. Income taxes, interest income, interest expense, environmental remediation expenses, Anadarko Acquisition-related costs and unallocated corporate expenses are included under Corporatecorporate and Eliminations.eliminations. Intersegment sales eliminate upon consolidation and are generally made at prices approximating those that the selling entity would be able to obtain in third-party transactions. Identifiable assets are those assets used in the operations of the segments. Corporate assets consist of cash and restricted cash, certain corporate receivables and PP&E. The chief operating decision maker analyzes each segment’s operating results to make decisions about resources to be allocated to the segment and to assess its performance as well as Occidental’s overall performance.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
| | millions | | millions | Oil and gas | | Chemical | | Midstream and marketing | | Corporate
and
eliminations | | Total |
| Year ended December 31, 2022 | | Year ended December 31, 2022 | | | | | |
| Net sales | | Net sales | $ | 27,165 | | | $ | 6,757 | | | $ | 4,136 | | | $ | (1,424) | | | $ | 36,634 | |
| Income (loss) from continuing operations before income taxes | | Income (loss) from continuing operations before income taxes | $ | 12,803 | | (a) | $ | 2,508 | | | $ | 273 | | (b) | $ | (1,467) | | (c) | $ | 14,117 | |
| Income tax expense | | Income tax expense | — | | | — | | | — | | | (813) | | (d) | (813) | |
| Income (loss) from continuing operations | | Income (loss) from continuing operations | $ | 12,803 | | | $ | 2,508 | | | $ | 273 | | | $ | (2,280) | | | $ | 13,304 | |
| Investments in unconsolidated entities | | Investments in unconsolidated entities | $ | 142 | | | $ | 578 | | | $ | 2,456 | | | $ | — | | | $ | 3,176 | |
Property, plant and equipment additions (e) | | Property, plant and equipment additions (e) | $ | 3,898 | | | $ | 331 | | | $ | 270 | | | $ | 67 | | | $ | 4,566 | |
| Depreciation, depletion and amortization | | Depreciation, depletion and amortization | $ | 6,179 | | | $ | 370 | | | $ | 328 | | | $ | 49 | | | $ | 6,926 | |
| Total assets | | Total assets | $ | 54,058 | | | $ | 4,558 | | | $ | 12,076 | | | $ | 1,917 | | | $ | 72,609 | |
| | Oil and gas | | Chemical | | Midstream and marketing | | Corporate
and
eliminations | | Total | |
| Year ended December 31, 2020 | | | | | | |
| Year ended December 31, 2021 | | Year ended December 31, 2021 | | | | | | | |
| Net sales | Net sales | $ | 13,066 | | | $ | 3,733 | | | $ | 1,768 | | | $ | (758) | | | $ | 17,809 | | Net sales | $ | 18,941 | | | $ | 5,246 | | | $ | 2,863 | | | $ | (1,094) | | | $ | 25,956 | |
| Income (loss) from continuing operations before income taxes | Income (loss) from continuing operations before income taxes | $ | (9,632) | | (a) | $ | 664 | | | $ | (4,175) | | (b) | $ | (2,562) | | (c) | $ | (15,705) | | Income (loss) from continuing operations before income taxes | $ | 4,145 | | (a) | $ | 1,544 | | | $ | 257 | | (b) | $ | (2,241) | | (c) | $ | 3,705 | |
| Income tax benefit | Income tax benefit | 0 | | | 0 | | | 0 | | | 2,172 | | (d) | 2,172 | | Income tax benefit | — | | | — | | | — | | | (915) | | (d) | (915) | |
| Income (loss) from continuing operations | Income (loss) from continuing operations | $ | (9,632) | | | $ | 664 | | | $ | (4,175) | | | $ | (390) | | | $ | (13,533) | | Income (loss) from continuing operations | $ | 4,145 | | | $ | 1,544 | | | $ | 257 | | | $ | (3,156) | | | $ | 2,790 | |
| Investments in unconsolidated entities | Investments in unconsolidated entities | $ | 168 | | | $ | 645 | | | $ | 2,437 | | | $ | 0 | | | $ | 3,250 | | Investments in unconsolidated entities | $ | 154 | | | $ | 608 | | | $ | 2,176 | | | $ | — | | | $ | 2,938 | |
Property, plant and equipment additions (e) | Property, plant and equipment additions (e) | $ | 2,279 | | | $ | 261 | | | $ | 50 | | | $ | 29 | | | $ | 2,619 | | Property, plant and equipment additions (e) | $ | 2,458 | | | $ | 316 | | | $ | 107 | | | $ | 50 | | | $ | 2,931 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | $ | 7,414 | | | $ | 356 | | | $ | 312 | | | $ | 15 | | | $ | 8,097 | | Depreciation, depletion and amortization | $ | 7,741 | | | $ | 343 | | | $ | 325 | | | $ | 38 | | | $ | 8,447 | |
| Total assets | Total assets | $ | 62,931 | | | $ | 4,326 | | | $ | 9,856 | | | $ | 2,951 | | | $ | 80,064 | | Total assets | $ | 56,132 | | | $ | 4,671 | | | $ | 11,132 | | | $ | 3,101 | | | $ | 75,036 | |
| | Year ended December 31, 2019 | | | | | | | | |
| Year ended December 31, 2020 | | Year ended December 31, 2020 | | | | | | | |
| Net sales | Net sales | $ | 13,941 | | | $ | 4,102 | | | $ | 4,132 | | | $ | (1,264) | | | $ | 20,911 | | Net sales | $ | 13,066 | | | $ | 3,733 | | | $ | 1,768 | | | $ | (758) | | | $ | 17,809 | |
| Income (loss) from continuing operations before income taxes | Income (loss) from continuing operations before income taxes | $ | 2,520 | | (a) | $ | 799 | | | $ | 241 | | (b) | $ | (3,206) | | (c) | $ | 354 | | Income (loss) from continuing operations before income taxes | $ | (9,632) | | (a) | $ | 664 | | | $ | (4,175) | | (b) | $ | (2,562) | | (c) | $ | (15,705) | |
| Income tax expense | Income tax expense | 0 | | | 0 | | | 0 | | | (861) | | (d) | (861) | | Income tax expense | — | | | — | | | — | | | 2,172 | | (d) | 2,172 | |
| Income (loss) from continuing operations | Income (loss) from continuing operations | $ | 2,520 | | | $ | 799 | | | $ | 241 | | | $ | (4,067) | | | $ | (507) | | Income (loss) from continuing operations | $ | (9,632) | | | $ | 664 | | | $ | (4,175) | | | $ | (390) | | | $ | (13,533) | |
| Investments in unconsolidated entities | Investments in unconsolidated entities | $ | 181 | | | $ | 689 | | | $ | 5,519 | | | $ | 0 | | | $ | 6,389 | | Investments in unconsolidated entities | $ | 168 | | | $ | 645 | | | $ | 2,437 | | | $ | — | | | $ | 3,250 | |
Property, plant and equipment additions (e) | Property, plant and equipment additions (e) | $ | 5,571 | | | $ | 272 | | | $ | 475 | | | $ | 135 | | | $ | 6,453 | | Property, plant and equipment additions (e) | $ | 2,279 | | | $ | 261 | | | $ | 50 | | | $ | 29 | | | $ | 2,619 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | $ | 5,153 | | | $ | 368 | | | $ | 563 | | | $ | 56 | | | $ | 6,140 | | Depreciation, depletion and amortization | $ | 7,414 | | | $ | 356 | | | $ | 312 | | | $ | 15 | | | $ | 8,097 | |
| Total assets | Total assets | $ | 80,093 | | | $ | 4,361 | | | $ | 14,915 | | | $ | 7,821 | | | $ | 107,190 | | Total assets | $ | 62,931 | | | $ | 4,326 | | | $ | 9,856 | | | $ | 2,951 | | | $ | 80,064 | |
| | Year ended December 31, 2018 | | | | | | | | |
| Net sales | $ | 10,441 | | | $ | 4,657 | | | $ | 3,656 | | | $ | (930) | | | $ | 17,824 | | |
Income (loss) from continuing operations before income taxes | $ | 2,442 | | (a) | $ | 1,159 | | | $ | 2,802 | | (b) | $ | (795) | |
| $ | 5,608 | | |
| Income tax expense | 0 | | | 0 | | | 0 | | | (1,477) | | (d) | (1,477) | | |
| Income (loss) from continuing operations | $ | 2,442 | | | $ | 1,159 | | | $ | 2,802 | | | $ | (2,272) | | | $ | 4,131 | | |
| Investments in unconsolidated entities | $ | 0 | | | $ | 733 | | | $ | 947 | | | $ | 0 | | | $ | 1,680 | | |
Property, plant and equipment additions (e) | $ | 4,443 | | | $ | 277 | | | $ | 221 | | | $ | 79 | | | $ | 5,020 | | |
| Depreciation, depletion and amortization | $ | 3,254 | | | $ | 354 | | | $ | 331 | | | $ | 38 | | | $ | 3,977 | | |
| Total assets | $ | 24,874 | | | $ | 4,359 | | | $ | 9,392 | | | $ | 3,534 | | | $ | 42,159 | | |
(a)The 2022 amount included $148 million of gains, primarily related to the sale of certain non-strategic assets in the Permian Basin. The 2022 amount included $55 million related to post-closing consideration earned from 2020 asset sales as a result of certain production and pricing targets being met as well as the closing of the sale of certain assets that were negotiated with the 2020 Colombia divestiture. The 2021 amount included $282 million of asset impairments and $280 million of net oil, gas and CO2 derivative losses. The 2020 amount included $7.1 billion related to asset impairments and net asset sale losses of $1.6 billion, partially offset by a $1.1 billion gain on the oil and gas collars and calls. The 2019 amount includedcalls and a net gainloss on the sale of $475 million related to Occidental’s joint venture with Ecopetrol in the Midland Basin and saleColombia assets of real estate assets, a $285 million impairment charge associated with domestic undeveloped leases that were set to expire in the near-term, where Occidental had no plans to pursue exploration activities, and a $39 million charge related to Occidental’s mutually agreed early termination of its Qatar ISSD contract. The 2018 amount included $416 million for the impairment of proved oil properties and inventory in Qatar ISND and ISSD due to the decline in oil prices.$353 million.
(b)The 2022 amount included $259 million of net derivative mark-to-market losses, $62 million relating to a gain on the sale of 10 million limited partner units in WES and a $36 million gain on the sale of a joint venture. The 2021 amount included $252 million in derivative mark-to-market losses and $124 million of gains on sales, primarily from the sale of 11.5 million limited partner units in WES. The 2020 amount included $2.7 billion of other-than-temporary impairment of WES equity
| | | | | | | | |
| | FINANCIAL STATEMENTS FOOTNOTES |
investment and $1.4 billion of impairments related to the write-off of goodwill and a $236 million loss from an equity investment related to WES' write-off of its goodwill.
(c)The 20192022 amount included a $1tax benefit of $2.7 billion chargein connection with Occidental’s legal entity reorganization, which is further discussed in the Income Taxes section of the Management’s Discussion and Analysis of Financial Condition and Results of Operations section under Part II, Item 7, of this Form 10-K and Note 10 - Income Taxes in the Notes to Consolidated Financial Statements in Part II Item 8 of this Form 10-K, as a resultwell as $317 million of recording Occidental’s investment in WES at fair value as of December 31, 2019 upon the loss of control, a $114 million gainnet gains on the sale of an equity investment in Plains and a $30 million mark-to-market gain on an interest rate swap for WES.swaps, $149 million of net gains on early debt extinguishment and $89 million of Anadarko acquisition-related costs. The 20182021 amount included pre-tax asset sale$153 million of Anadarko acquisition-related costs, $122 million net derivative mark-to-market gains on interest rate swaps and $118 million of $907 million on the sale of non-core domestic midstream assets. (c)early debt extinguishment expenses. The 2020 amount included $339 million in expenses related to Anadarko Acquisition-related costs and a $428 million loss on interest rate swaps. The 2019 amount included corporate transactions related to the Acquisition including charges of $1.0 billion related to employee severance and related costs, $401 million related to crucial seismic data and$213 million for bank, legal and consulting fees. There were no significant corporate transactions and events affecting 2018 results. The tax effect of these pre-tax adjustments was a $1.9 billion benefit in 2020, a $245 million benefit in 2019, and $198 million expense in 2018.
(d)Included all foreign and domestic income taxes from continuing operations.
(e)Included capital expenditures and capitalized interest, but excluded acquisition and disposition of assets.
| | | | | | | | |
| FINANCIAL STATEMENTS
FOOTNOTES
| |
GEOGRAPHIC AREAS
| | millions | millions | | Property, plant and equipment, net | millions | | Property, plant and equipment, net |
| For the years ended December 31, | For the years ended December 31, | | 2020 | | 2019 | | 2018 | For the years ended December 31, | | 2022 | | 2021 | | 2020 |
| United States | United States | | $ | 59,016 | | | $ | 72,808 | | | $ | 23,594 | | United States | | $ | 51,706 | | | $ | 53,197 | | | $ | 59,016 | |
| International | International | | International | |
| United Arab Emirates | | 3,737 | | | 3,886 | | | 4,051 | | |
| UAE | | UAE | | 3,663 | | | 3,645 | | | 3,737 | |
| Oman | Oman | | 1,901 | | | 2,115 | | | 2,048 | | Oman | | 2,159 | | | 2,055 | | | 1,901 | |
| Algeria | Algeria | | 664 | | | 1,761 | | | 0 | | Algeria | | 350 | | | 496 | | | 664 | |
| Colombia | | 0 | | | 1,010 | | | 927 | | |
| | Qatar | Qatar | | 510 | | | 563 | | | 741 | | Qatar | | 428 | | | 468 | | | 510 | |
| Other International | Other International | | 61 | | | 87 | | | 76 | | Other International | | 78 | | | 69 | | | 61 | |
| Total International | Total International | | 6,873 | | | 9,422 | | | 7,843 | | Total International | | 6,678 | | | 6,733 | | | 6,873 | |
| Total | Total | | $ | 65,889 | | | $ | 82,230 | | | $ | 31,437 | | Total | | $ | 58,384 | | | $ | 59,930 | | | $ | 65,889 | |
| | | | | |
116 | OXY 20202022 FORM 10-K | 109 |
| | | | | |
| Supplemental Quarterly Information
(Unaudited)
|
| | | | | |
Quarterly Financial Data | Occidental Petroleum Corporation
and Subsidiaries |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions except per-share amounts | | First Quarter | | Second Quarter | | Third Quarter | | Fourth Quarter |
| 2020 | | | | | | | | |
| Segment net sales | | | | | | | | |
| Oil and gas | | $ | 5,060 | | | $ | 2,040 | | | $ | 2,989 | | | $ | 2,977 | |
| Chemical | | 962 | | | 846 | | | 937 | | | 988 | |
| Midstream and marketing | | 790 | | | 204 | | | 364 | | | 410 | |
| Eliminations | | (199) | | | (162) | | | (182) | | | (215) | |
| Net sales | | $ | 6,613 | | | $ | 2,928 | | | $ | 4,108 | | | $ | 4,160 | |
| Gross profit | | $ | 1,440 | | | $ | (1,048) | | | $ | 63 | | | $ | 167 | |
| Segment earnings | | | | | | | | |
| Oil and gas | | $ | 236 | | | $ | (7,734) | | | $ | (1,072) | | | $ | (1,062) | |
| Chemical | | 186 | | | 108 | | | 178 | | | 192 | |
| Midstream and marketing | | (1,287) | | | (7) | | | (2,791) | | | (90) | |
| Total segment earnings | | $ | (865) | | | $ | (7,633) | | | $ | (3,685) | | | $ | (960) | |
| Unallocated corporate items | | | | | | | | |
| Interest expense, net | | (352) | | | (310) | | | (353) | | | (409) | |
| Income tax benefit | | 25 | | | 1,468 | | | 403 | | | 276 | |
| Other | | (821) | | | (241) | | | (20) | | | (56) | |
| Loss from continuing operations | | $ | (2,013) | | | $ | (6,716) | | | $ | (3,655) | | | $ | (1,149) | |
| Discontinued operations, net of taxes | | — | | | (1,415) | | | 80 | | | 37 | |
| Net Loss | | $ | (2,013) | | | $ | (8,131) | | | $ | (3,575) | | | $ | (1,112) | |
| | | | | | | | |
| Less: Preferred stock dividend | | (219) | | | (222) | | | (203) | | | (200) | |
| Net loss attributable to common stockholders | | $ | (2,232) | | | $ | (8,353) | | | $ | (3,778) | | | $ | (1,312) | |
| Basic loss per common share | | $ | (2.49) | | | $ | (9.12) | | | $ | (4.07) | | | $ | (1.41) | |
| Diluted loss per common share | | $ | (2.49) | | | $ | (9.12) | | | $ | (4.07) | | | $ | (1.41) | |
| Dividends per common share | | $ | 0.79 | | | $ | 0.01 | | | $ | 0.01 | | | $ | 0.01 | |
| | | | | | | | |
| 2019 | | | | | | | | |
| Segment net sales | | | | | | | | |
| Oil and gas | | $ | 2,351 | | | $ | 2,718 | | | $ | 3,993 | | | $ | 4,879 | |
| Chemical | | 1,059 | | | 998 | | | 1,071 | | | 974 | |
Midstream and marketing (a) | | 816 | | | 909 | | | 1,163 | | | 1,244 | |
| Eliminations | | (222) | | | (205) | | | (368) | | | (469) | |
| Net sales | | $ | 4,004 | | | $ | 4,420 | | | $ | 5,859 | | | $ | 6,628 | |
| Gross profit | | $ | 1,210 | | | $ | 1,449 | | | $ | 1,471 | | | $ | 1,414 | |
| Segment earnings | | | | | | | | |
| Oil and gas | | $ | 484 | | | $ | 726 | | | $ | 268 | | | $ | 1,042 | |
| Chemical | | 265 | | | 208 | | | 207 | | | 119 | |
Midstream and marketing (a) | | 279 | | | 331 | | | 400 | | | (769) | |
| Total segment earnings | | $ | 1,028 | | | $ | 1,265 | | | $ | 875 | | | $ | 392 | |
| Unallocated corporate items | | | | | | | | |
| Interest expense, net | | (83) | | | (143) | | | (360) | | | (416) | |
| Income tax expense | | (225) | | | (306) | | | (163) | | | (167) | |
| Other | | (89) | | | (181) | | | (1,089) | | | (845) | |
| Income (loss) from continuing operations | | $ | 631 | | | $ | 635 | | | $ | (737) | | | $ | (1,036) | |
| Discontinued operations, net of taxes | | — | | | — | | | (15) | | | — | |
| Net Income (loss) | | $ | 631 | | | $ | 635 | | | $ | (752) | | | $ | (1,036) | |
| Less: Net income attributable to noncontrolling interests | | — | | | — | | | (42) | | | (103) | |
| Less: Preferred stock dividend | | — | | | — | | | (118) | | | (200) | |
| Net income (loss) attributable to common stockholders | | $ | 631 | | | $ | 635 | | | $ | (912) | | | $ | (1,339) | |
| Basic earnings (loss) per common share | | $ | 0.84 | | | $ | 0.84 | | | $ | (1.08) | | | $ | (1.50) | |
| Diluted earnings (loss) per common share | | $ | 0.84 | | | $ | 0.84 | | | $ | (1.08) | | | $ | (1.50) | |
| Dividends per common share | | $ | 0.78 | | | $ | 0.78 | | | $ | 0.79 | | | $ | 0.79 | |
(a)Midstream and marketing segment net sales and earnings include the results of WES from the Acquisition date to the loss of control date.
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
Supplemental Oil and Gas Information
OIL AND GAS RESERVES
The following tables set forth Occidental’s net interests in quantities of proved developed and undeveloped reserves of oil, (including condensate), NGL and natural gas and changes in such quantities. Proved oil, NGL and natural gas reserves were estimated using the unweighted arithmetic average of the first-day-of-the-month price for each month within the year, unless prices were defined by contractual arrangements. Oil, NGL and natural gas prices used for this purpose were based on posted benchmark prices and adjusted for price differentials including gravity, quality and transportation costs. The following table shows the pricing used in the reserve analysis for the periods presented:
| | | | | | | | | | | | | | | | | | | | |
| | 2020 | | 2019 | | 2018 |
| Average WTI Oil ($/Bbl) | | $ | 39.57 | | | $ | 55.69 | | | $ | 65.56 | |
| Average Brent Oil ($/Bbl) | | $ | 43.41 | | | $ | 63.03 | | | $ | 72.20 | |
| Average Henry Hub Natural Gas ($/MMbtu) | | $ | 1.98 | | | $ | 2.58 | | | $ | 3.10 | |
Average Mt. Belvieu NGL ($/Bbl) (a) | | $ | 18.74 | | | N/A | | N/A |
(a) Mt. Belvieu pricing was added as an NGL benchmark beginning in 2020. Prior to 2020, WTI Oil was used as a benchmark for NGL. | | | | | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 | | 2020 |
| Average WTI Oil ($/Bbl) | | $ | 93.67 | | | $ | 66.56 | | | $ | 39.57 | |
| Average Brent Oil ($/Bbl) | | $ | 97.77 | | | $ | 69.24 | | | $ | 43.41 | |
| Average Henry Hub Natural Gas ($/MMbtu) | | $ | 6.36 | | | $ | 3.60 | | | $ | 1.98 | |
| Average Mt. Belvieu NGL ($/Bbl) | | $ | 47.81 | | | $ | 44.22 | | | $ | 18.74 | |
Reserves are stated net of applicable royalties. Estimated reserves include Occidental’s economic interests under production-sharing contracts (PSCs)PSCs and other similar economic arrangements. In addition, discussions of oil and gas production or volumes, in general, refer to sales volumes unless the context requires or it is indicated otherwise.
Prices for oil, NGL and natural gas fluctuate widely. Historically, the markets for oil, NGL and natural gas and refined products have been volatile and may continue to be volatile in the future. Prolonged or further declines in oil, NGL and natural gas prices would continue to reduce Occidental’s operating results and cash flows and could impact its future rate of growth and further impact the recoverability of the carrying value of its assets.
| | | | | |
118110 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
OIL RESERVES (a)
| | millions of barrels (MMbbl) | | United States | | Latin America | | Middle East / Africa (b) | | Total | |
| MMbbl | | MMbbl | | United States | | | International | | Total |
| PROVED DEVELOPED AND UNDEVELOPED RESERVES | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | |
| Balance at December 31, 2017 | | 1,107 | | | 82 | | | 326 | | | 1,515 | | |
| Balance as of December 31, 2019 | | Balance as of December 31, 2019 | | 1,570 | | | | 469 | | | 2,039 | |
| Revisions of previous estimates | Revisions of previous estimates | | 15 | | | (2) | | | (7) | | | 6 | | Revisions of previous estimates | | (283) | | | | (1) | | | (284) | |
| Improved recovery | Improved recovery | | 135 | | | 23 | | | 31 | | | 189 | | Improved recovery | | 82 | | | | 18 | | | 100 | |
| Extensions and discoveries | Extensions and discoveries | | — | | | 4 | | | 2 | | | 6 | | Extensions and discoveries | | 9 | | | | 5 | | | 14 | |
| Purchases of proved reserves | Purchases of proved reserves | | 32 | | | — | | | — | | | 32 | | Purchases of proved reserves | | 2 | | | | — | | | 2 | |
| Sales of proved reserves | Sales of proved reserves | | (12) | | | — | | | — | | | (12) | | Sales of proved reserves | | (31) | | | | (101) | | | (132) | |
| Production | Production | | (91) | | | (11) | | | (51) | | | (153) | | Production | | (205) | | | | (59) | | | (264) | |
| Balance at December 31, 2018 | | 1,186 | | | 96 | | | 301 | | | 1,583 | | |
| Balance as of December 31, 2020 | | Balance as of December 31, 2020 | | 1,144 | | | | 331 | | | 1,475 | |
| Revisions of previous estimates | Revisions of previous estimates | | (154) | | | 3 | | | 8 | | | (143) | | Revisions of previous estimates | | 382 | | | | 4 | | | 386 | |
| Improved recovery | Improved recovery | | 128 | | | 12 | | | 25 | | | 165 | | Improved recovery | | 6 | | | | 13 | | | 19 | |
| Extensions and discoveries | Extensions and discoveries | | 37 | | | 2 | | | 2 | | | 41 | | Extensions and discoveries | | 88 | | | | 1 | | | 89 | |
| Purchases of proved reserves | Purchases of proved reserves | | 545 | | | — | | | 84 | | | 629 | | Purchases of proved reserves | | 33 | | | | — | | | 33 | |
| Sales of proved reserves | Sales of proved reserves | | (17) | | | — | | | — | | | (17) | | Sales of proved reserves | | (5) | | | | — | | | (5) | |
| Production | Production | | (155) | | | (12) | | | (52) | | | (219) | | Production | | (182) | | | | (44) | | | (226) | |
| Balance at December 31, 2019 | | 1,570 | | | 101 | | | 368 | | | 2,039 | | |
| Balance as of December 31, 2021 | | Balance as of December 31, 2021 | | 1,466 | | | | 305 | | | 1,771 | |
Revisions of previous estimates (c)(b) | Revisions of previous estimates (c)(b) | | (283) | | | 12 | | | (13) | | | (284) | | Revisions of previous estimates (c)(b) | | 215 | | | | (5) | | | 210 | |
| Improved recovery | Improved recovery | | 82 | | | — | | | 18 | | | 100 | | Improved recovery | | 57 | | | | 9 | | | 66 | |
| Extensions and discoveries | Extensions and discoveries | | 9 | | | — | | | 5 | | | 14 | | Extensions and discoveries | | 89 | | | | 6 | | | 95 | |
| Purchases of proved reserves | Purchases of proved reserves | | 2 | | | — | | | — | | | 2 | | Purchases of proved reserves | | 7 | | | | — | | | 7 | |
| Sales of proved reserves | Sales of proved reserves | | (31) | | | (101) | | | — | | | (132) | | Sales of proved reserves | | (10) | | | | — | | | (10) | |
| Production | Production | | (205) | | | (12) | | | (47) | | | (264) | | Production | | (185) | | | | (41) | | | (226) | |
| Balance at December 31, 2020 | | 1,144 | | | — | | | 331 | | | 1,475 | | |
| Balance as of December 31, 2022 | | Balance as of December 31, 2022 | | 1,639 | | | | 274 | | | 1,913 | |
| | PROVED DEVELOPED RESERVES | PROVED DEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED RESERVES | | | | | |
| December 31, 2017 | | 772 | | | 77 | | | 279 | | | 1,128 | | |
| December 31, 2018 | | 843 | | | 77 | | | 240 | | | 1,160 | | |
| December 31, 2019 | | 1,206 | | | 76 | | | 295 | | | 1,577 | | |
December 31, 2020 (d) | | 917 | | | — | | | 251 | | | 1,168 | | |
PROVED UNDEVELOPED RESERVES | | |
| December 31, 2017 | | 335 | | | 5 | | | 47 | | | 387 | | |
| December 31, 2018 | | 343 | | | 19 | | | 61 | | | 423 | | |
| December 31, 2019 | December 31, 2019 | | 364 | | | 25 | | | 73 | | | 462 | | December 31, 2019 | | 1,206 | | | | 371 | | | 1,577 | |
| December 31, 2020 | December 31, 2020 | | 227 | | | — | | | 80 | | | 307 | | December 31, 2020 | | 917 | | | | 251 | | | 1,168 | |
| December 31, 2021 | | December 31, 2021 | | 1,140 | | | | 226 | | | 1,366 | |
| December 31, 2022 | | December 31, 2022 | | 1,208 | | | | 200 | | | 1,408 | |
PROVED UNDEVELOPED RESERVES | | PROVED UNDEVELOPED RESERVES | | | |
| December 31, 2019 | | December 31, 2019 | | 364 | | | | 98 | | | 462 | |
| December 31, 2020 | | December 31, 2020 | | 227 | | | | 80 | | | 307 | |
| December 31, 2021 | | December 31, 2021 | | 326 | | | | 79 | | | 405 | |
| December 31, 2022 | | December 31, 2022 | | 431 | | | | 74 | | | 505 | |
|
(a)Excluded reserve amounts related to thediscontinued operations and held for sale assets. Reserves related to the Algeria assets have been reclassifiedin 2020 and included in prior and the current periods.2019. Proved reserves for held for sale assets as of December 31, 2021 were immaterial.
(b)Over half of the proved reserve amounts relate to PSCs.
(c)Revisions of previous estimates in 2020 reflected negative2022 included the effects of new infill drilling, price revisions and other updates, including changes in reservoir performance, economic conditions, and development plans. Positive revisions of 185 MMboe,164 MMbbl were related to additions associated with infill development projects, primarily in the Permian Basin (180 MMboe)(122 MMbbl) and the DJ Basin (20 MMboe), partially offset by(33 MMbbl). Another 72 MMbbl of positive price revisions of 28 MMboe on PSCs. Another 127 MMboe in negative revisions were related to changes in development plans primarily in the Permian Basin which were(83 MMbbl) and the Gulf of Mexico (6 MMbbl), partially offset by 23 MMboe innegative price revisions of 22 MMbbl related to PSCs. Further positive revisions related toof 34 MMbbl were associated with updates based on reservoir performance.
(d)Approximately 11% of the proved developed reserves at December 31, 2020, are nonproducing, primarilyperformance (30MMbbl) and changes in development plans (4 MMbbl). The positive revisions were offset by negative revisions associated with the Permian Basinvarious other cost and Oman.interest related revisions (60 MMbbl).
| | | | | |
OXY 20202022 FORM 10-K | 119111 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
NGL RESERVES (a)
| | millions of barrels (MMbbl) | | United States | | Latin America | | Middle East / Africa | | Total | |
| MMbbl | | MMbbl | | United States | | | International | | Total |
| PROVED DEVELOPED AND UNDEVELOPED RESERVES | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | |
| Balance at December 31, 2017 | | 247 | | | — | | | 198 | | | 445 | | |
| Balance as of December 31, 2019 | | Balance as of December 31, 2019 | | 540 | | | | 208 | | | 748 | |
| Revisions of previous estimates | Revisions of previous estimates | | 7 | | | — | | | 15 | | | 22 | | Revisions of previous estimates | | (90) | | | | 10 | | | (80) | |
| Improved recovery | Improved recovery | | 47 | | | — | | | — | | | 47 | | Improved recovery | | 32 | | | | 10 | | | 42 | |
| Extensions and discoveries | Extensions and discoveries | | — | | | — | | | — | | | — | | Extensions and discoveries | | 2 | | | | — | | | 2 | |
| Purchases of proved reserves | Purchases of proved reserves | | 11 | | | — | | | — | | | 11 | | Purchases of proved reserves | | 1 | | | | — | | | 1 | |
| Sales of proved reserves | Sales of proved reserves | | (3) | | | — | | | — | | | (3) | | Sales of proved reserves | | (20) | | | | — | | | (20) | |
| Production | Production | | (25) | | | — | | | (11) | | | (36) | | Production | | (81) | | | | (13) | | | (94) | |
| Balance at December 31, 2018 | | 284 | | | — | | | 202 | | | 486 | | |
| Balance as of December 31, 2020 | | Balance as of December 31, 2020 | | 384 | | | | 215 | | | 599 | |
| Revisions of previous estimates | Revisions of previous estimates | | (21) | | | — | | | 9 | | | (12) | | Revisions of previous estimates | | 227 | | | | (1) | | | 226 | |
| Improved recovery | Improved recovery | | 58 | | | — | | | — | | | 58 | | Improved recovery | | — | | | | — | | | — | |
| Extensions and discoveries | Extensions and discoveries | | 11 | | | — | | | — | | | 11 | | Extensions and discoveries | | 27 | | | | — | | | 27 | |
| Purchases of proved reserves | Purchases of proved reserves | | 267 | | | — | | | 10 | | | 277 | | Purchases of proved reserves | | 7 | | | | — | | | 7 | |
| Sales of proved reserves | Sales of proved reserves | | (7) | | | — | | | — | | | (7) | | Sales of proved reserves | | (2) | | | | — | | | (2) | |
| Production | Production | | (52) | | | — | | | (13) | | | (65) | | Production | | (79) | | | | (12) | | | (91) | |
| Balance at December 31, 2019 | | 540 | | | — | | | 208 | | | 748 | | |
| Balance as of December 31, 2021 | | Balance as of December 31, 2021 | | 564 | | | | 202 | | | 766 | |
Revisions of previous estimates (b) | Revisions of previous estimates (b) | | (90) | | | — | | | 10 | | | (80) | | Revisions of previous estimates (b) | | 126 | | | | 2 | | | 128 | |
| Improved recovery | Improved recovery | | 32 | | | — | | | 10 | | | 42 | | Improved recovery | | 13 | | | | — | | | 13 | |
| Extensions and discoveries | Extensions and discoveries | | 2 | | | — | | | — | | | 2 | | Extensions and discoveries | | 36 | | | | — | | | 36 | |
| Purchases of proved reserves | Purchases of proved reserves | | 1 | | | — | | | — | | | 1 | | Purchases of proved reserves | | 2 | | | | — | | | 2 | |
| Sales of proved reserves | Sales of proved reserves | | (20) | | | — | | | — | | | (20) | | Sales of proved reserves | | (4) | | | | — | | | (4) | |
| Production | Production | | (81) | | | — | | | (13) | | | (94) | | Production | | (83) | | | | (12) | | | (95) | |
| Balance at December 31, 2020 | | 384 | | | — | | | 215 | | | 599 | | |
| Balance as of December 31, 2022 | | Balance as of December 31, 2022 | | 654 | | | | 192 | | | 846 | |
| | PROVED DEVELOPED RESERVES | PROVED DEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED RESERVES | | | |
| December 31, 2017 | | 161 | | | — | | | 153 | | | 314 | | |
| December 31, 2018 | | 196 | | | — | | | 145 | | | 341 | | |
| December 31, 2019 | | 406 | | | — | | | 147 | | | 553 | | |
December 31, 2020 (c) | | 314 | | | — | | | 138 | | | 452 | | |
| PROVED UNDEVELOPED RESERVES | | |
| December 31, 2017 | | 86 | | | — | | | 45 | | | 131 | | |
| December 31, 2018 | | 88 | | | — | | | 57 | | | 145 | | |
| December 31, 2019 | December 31, 2019 | | 134 | | | — | | | 61 | | | 195 | | December 31, 2019 | | 406 | | | | 147 | | | 553 | |
| December 31, 2020 | December 31, 2020 | | 70 | | | — | | | 77 | | | 147 | | December 31, 2020 | | 314 | | | | 138 | | | 452 | |
| December 31, 2021 | | December 31, 2021 | | 433 | | | | 125 | | | 558 | |
| December 31, 2022 | | December 31, 2022 | | 444 | | | | 120 | | | 564 | |
PROVED UNDEVELOPED RESERVES | | PROVED UNDEVELOPED RESERVES | | | |
| December 31, 2019 | | December 31, 2019 | | 134 | | | | 61 | | | 195 | |
| December 31, 2020 | | December 31, 2020 | | 70 | | | | 77 | | | 147 | |
| December 31, 2021 | | December 31, 2021 | | 131 | | | | 77 | | | 208 | |
| December 31, 2022 | | December 31, 2022 | | 210 | | | | 72 | | | 282 | |
(a)Excluded reserve amounts related to thediscontinued operations and held for sale assets. Reserves related to the Algeria assets have been reclassifiedin 2020 and included in prior and the current periods.2019. Proved reserves for held for sale assets as of December 31, 2021 were immaterial.
(b)Revisions of previous estimates in 2020 reflected negative2022 included the effects of new infill drilling, price revisions and other updates, including changes in reservoir performance, economic conditions and development plans. Positive revisions of 77 MMboe,80 MMbbl were related to additions associated with infill development projects, primarily in the Permian Basin (56 MMboe)MMbbl) and the DJ Basin (21 MMboe)(24 MMbbl). Another 36 MMboe in negative30 MMbbl of positive price revisions were related to changes in development plans primarily in the Permian Basin, which were offset by 36 MMboe inBasin. Further positive revisions related toof 36 MMbbl were primarily associated with updates based on reservoir performance.
(c)Approximately 5% of the proved developed reserves at December 31, 2020, are nonproducing, primarily The positive revisions were offset by negative revisions associated with the Permian Basin.various other cost and interest related revisions (18 MMbbl).
| | | | | |
120112 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
NATURAL GAS RESERVES (a)
| | billions of cubic feet (Bcf) | | United States | | Latin America | | Middle East / Africa (b) | | Total | |
| Bcf | | Bcf | | United States | | | International | | Total |
| PROVED DEVELOPED AND UNDEVELOPED RESERVES | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | |
| Balance at December 31, 2017 | | 1,205 | | | 12 | | | 2,614 | | | 3,831 | | |
| Balance as of December 31, 2019 | | Balance as of December 31, 2019 | | 4,128 | | | | 2,572 | | | 6,700 | |
| Revisions of previous estimates | Revisions of previous estimates | | (25) | | | — | | | 191 | | | 166 | | Revisions of previous estimates | | (823) | | | | 102 | | | (721) | |
| Improved recovery | Improved recovery | | 329 | | | 1 | | | 17 | | | 347 | | Improved recovery | | 183 | | | | 103 | | | 286 | |
| Extensions and discoveries | Extensions and discoveries | | — | | | — | | | 4 | | | 4 | | Extensions and discoveries | | 38 | | | | — | | | 38 | |
| Purchases of proved reserves | Purchases of proved reserves | | 69 | | | — | | | — | | | 69 | | Purchases of proved reserves | | 4 | | | | — | | | 4 | |
| Sales of proved reserves | Sales of proved reserves | | (14) | | | — | | | — | | | (14) | | Sales of proved reserves | | (523) | | | | (9) | | | (532) | |
| Production | Production | | (119) | | | (2) | | | (187) | | | (308) | | Production | | (561) | | | | (195) | | | (756) | |
| Balance at December 31, 2018 | | 1,445 | | | 11 | | | 2,639 | | | 4,095 | | |
| Balance as of December 31, 2020 | | Balance as of December 31, 2020 | | 2,446 | | | | 2,573 | | | 5,019 | |
| Revisions of previous estimates | Revisions of previous estimates | | (409) | | | (1) | | | 90 | | | (320) | | Revisions of previous estimates | | 1,274 | | | | 27 | | | 1,301 | |
| Improved recovery | Improved recovery | | 393 | | | 2 | | | 30 | | | 425 | | Improved recovery | | 3 | | | | 3 | | | 6 | |
| Extensions and discoveries | Extensions and discoveries | | 59 | | | 2 | | | 3 | | | 64 | | Extensions and discoveries | | 176 | | | | — | | | 176 | |
| Purchases of proved reserves | Purchases of proved reserves | | 2,996 | | | — | | | — | | | 2,996 | | Purchases of proved reserves | | 22 | | | | — | | | 22 | |
| Sales of proved reserves | Sales of proved reserves | | (30) | | | — | | | — | | | (30) | | Sales of proved reserves | | (25) | | | | — | | | (25) | |
| Production | Production | | (326) | | | (2) | | | (202) | | | (530) | | Production | | (477) | | | | (172) | | | (649) | |
| Balance at December 31, 2019 | | 4,128 | | | 12 | | | 2,560 | | | 6,700 | | |
| Balance as of December 31, 2021 | | Balance as of December 31, 2021 | | 3,419 | | | | 2,431 | | | 5,850 | |
Revisions of previous estimates (c)(b) | Revisions of previous estimates (c)(b) | | (823) | | | (1) | | | 103 | | | (721) | | Revisions of previous estimates (c)(b) | | 841 | | | | (30) | | | 811 | |
| Improved recovery | Improved recovery | | 183 | | | — | | | 103 | | | 286 | | Improved recovery | | 51 | | | | 17 | | | 68 | |
| Extensions and discoveries | Extensions and discoveries | | 38 | | | — | | | — | | | 38 | | Extensions and discoveries | | 244 | | | | 23 | | | 267 | |
| Purchases of proved reserves | Purchases of proved reserves | | 4 | | | — | | | — | | | 4 | | Purchases of proved reserves | | 8 | | | | — | | | 8 | |
| Sales of proved reserves | Sales of proved reserves | | (523) | | | (9) | | | — | | | (532) | | Sales of proved reserves | | (45) | | | | — | | | (45) | |
| Production | Production | | (561) | | | (2) | | | (193) | | | (756) | | Production | | (445) | | | | (164) | | | (609) | |
| Balance at December 31, 2020 | | 2,446 | | | — | | | 2,573 | | | 5,019 | | |
| Balance as of December 31, 2022 | | Balance as of December 31, 2022 | | 4,073 | | | | 2,277 | | | 6,350 | |
| | | | | | | | | | |
| PROVED DEVELOPED RESERVES | PROVED DEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED RESERVES | | | |
| December 31, 2017 | | 782 | | | 11 | | | 2,131 | | | 2,924 | | |
| December 31, 2018 | | 978 | | | 11 | | | 2,015 | | | 3,004 | | |
| December 31, 2019 | | 3,198 | | | 11 | | | 1,996 | | | 5,205 | | |
December 31, 2020 (d) | | 2,028 | | | — | | | 1,846 | | | 3,874 | | |
| PROVED UNDEVELOPED RESERVES | | |
| December 31, 2017 | | 423 | | | 1 | | | 483 | | | 907 | | |
| December 31, 2018 | | 467 | | | — | | | 624 | | | 1,091 | | |
| December 31, 2019 | December 31, 2019 | | 930 | | | 1 | | | 564 | | | 1,495 | | December 31, 2019 | | 3,198 | | | | 2,007 | | | 5,205 | |
| December 31, 2020 | December 31, 2020 | | 418 | | | — | | | 727 | | | 1,145 | | December 31, 2020 | | 2,028 | | | | 1,846 | | | 3,874 | |
| December 31, 2021 | | December 31, 2021 | | 2,632 | | | | 1,705 | | | 4,337 | |
| December 31, 2022 | | December 31, 2022 | | 2,761 | | | | 1,597 | | | 4,358 | |
PROVED UNDEVELOPED RESERVES | | PROVED UNDEVELOPED RESERVES | | | |
| December 31, 2019 | | December 31, 2019 | | 930 | | | | 565 | | | 1,495 | |
| December 31, 2020 | | December 31, 2020 | | 418 | | | | 727 | | | 1,145 | |
| December 31, 2021 | | December 31, 2021 | | 787 | | | | 726 | | | 1,513 | |
| December 31, 2022 | | December 31, 2022 | | 1,312 | | | | 680 | | | 1,992 | |
(a)Excluded reserve amounts related to thediscontinued operations and held for sale assets. Reserves related to the Algeria assets have been reclassifiedin 2020 and included in prior and the current periods.2019. Proved reserves for held for sale assets as of December 31, 2021 were immaterial.
(b)Approximately a quarter of Middle East proved reserves relate to PSCs.
(c)Revisions of previous estimates in 2020 reflected negative2022 included the effects of new infill drilling, price revisions and other updates, including changes in reservoir performance, economic conditions and development plans. Positive revisions of 483545 Bcf were related to additions associated with infill development projects, primarily in the Permian Basin (281(322 Bcf) and the DJ Basin (210(221 Bcf). Another 200 Bcf of positive price revisions were primarily in the Permian Basin (205 Bcf) and the DJ Basin (11 Bcf), partially offset by positivenegative price revisions of 3731 Bcf on PSCs. Another 209 Bcf in negative revisions were related to PSCs. Further positive revisions of 193 Bcf were associated with updates based on reservoir performance (163 Bcf), interest related revisions (21 Bcf) and changes in development plans primarily in the Permian Basin and 7 Bcf in(9 Bcf). The positive revisions were offset by negative revisions related to updates based on reservoir performance.
(d)Approximately 2% of the proved developed reserves at December 31, 2020, are nonproducing, primarily associated with the Permian Basin, DJ Basin and Oman.various other cost related revisions (127 Bcf).
| | | | | |
OXY 20202022 FORM 10-K | 121113 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
TOTAL RESERVES (a) | millions of Boe (MMboe) (b) | | United States | | Latin America | | Middle East / Africa | | Total (c) | |
MMboe (b) | | MMboe (b) | | United States | | | International | | Total |
| PROVED DEVELOPED AND UNDEVELOPED RESERVES | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | | PROVED DEVELOPED AND UNDEVELOPED RESERVES | | | | | |
| Balance at December 31, 2017 | | 1,555 | | | 84 | | | 959 | | | 2,598 | | |
| Balance as of December 31, 2019 | | Balance as of December 31, 2019 | | 2,798 | | | | 1,106 | | | 3,904 | |
| Revisions of previous estimates | Revisions of previous estimates | | 18 | | | (2) | | | 40 | | | 56 | | Revisions of previous estimates | | (510) | | | | 26 | | | (484) | |
| Improved recovery | Improved recovery | | 237 | | | 23 | | | 34 | | | 294 | | Improved recovery | | 145 | | | | 45 | | | 190 | |
| Extensions and discoveries | Extensions and discoveries | | — | | | 4 | | | 3 | | | 7 | | Extensions and discoveries | | 17 | | | | 5 | | | 22 | |
| Purchases of proved reserves | Purchases of proved reserves | | 54 | | | — | | | — | | | 54 | | Purchases of proved reserves | | 4 | | | | — | | | 4 | |
| Sales of proved reserves | Sales of proved reserves | | (17) | | | — | | | — | | | (17) | | Sales of proved reserves | | (138) | | | | (103) | | | (241) | |
| Production | Production | | (136) | | | (11) | | | (93) | | | (240) | | Production | | (380) | | | | (104) | | | (484) | |
| Balance at December 31, 2018 | | 1,711 | | | 98 | | | 943 | | | 2,752 | | |
| Balance as of December 31, 2020 | | Balance as of December 31, 2020 | | 1,936 | | | | 975 | | | 2,911 | |
| Revisions of previous estimates | Revisions of previous estimates | | (243) | | | 3 | | | 32 | | | (208) | | Revisions of previous estimates | | 821 | | | | 8 | | | 829 | |
| Improved recovery | Improved recovery | | 251 | | | 12 | | | 30 | | | 293 | | Improved recovery | | 7 | | | | 13 | | | 20 | |
| Extensions and discoveries | Extensions and discoveries | | 58 | | | 2 | | | 3 | | | 63 | | Extensions and discoveries | | 144 | | | | 1 | | | 145 | |
| Purchases of proved reserves | Purchases of proved reserves | | 1,311 | | | — | | | 94 | | | 1,405 | | Purchases of proved reserves | | 44 | | | | — | | | 44 | |
| Sales of proved reserves | Sales of proved reserves | | (29) | | | — | | | — | | | (29) | | Sales of proved reserves | | (11) | | | | — | | | (11) | |
| Production | Production | | (261) | | | (12) | | | (99) | | | (372) | | Production | | (341) | | | | (85) | | | (426) | |
| Balance at December 31, 2019 | | 2,798 | | | 103 | | | 1,003 | | | 3,904 | | |
| Balance as of December 31, 2021 | | Balance as of December 31, 2021 | | 2,600 | | | | 912 | | | 3,512 | |
Revisions of previous estimates (d)(c) | Revisions of previous estimates (d)(c) | | (510) | | | 12 | | | 14 | | | (484) | | Revisions of previous estimates (d)(c) | | 481 | | | | (7) | | | 474 | |
| Improved recovery | Improved recovery | | 145 | | | — | | | 45 | | | 190 | | Improved recovery | | 78 | | | | 11 | | | 89 | |
| Extensions and discoveries | Extensions and discoveries | | 17 | | | — | | | 5 | | | 22 | | Extensions and discoveries | | 166 | | | | 10 | | | 176 | |
| Purchases of proved reserves | Purchases of proved reserves | | 4 | | | — | | | — | | | 4 | | Purchases of proved reserves | | 10 | | | | — | | | 10 | |
| Sales of proved reserves | Sales of proved reserves | | (138) | | | (103) | | | — | | | (241) | | Sales of proved reserves | | (21) | | | | — | | | (21) | |
| Production | Production | | (380) | | | (12) | | | (92) | | | (484) | | Production | | (342) | | | | (81) | | | (423) | |
| Balance at December 31, 2020 | | 1,936 | | | — | | | 975 | | | 2,911 | | |
| Balance as of December 31, 2022 | | Balance as of December 31, 2022 | | 2,972 | | | | 845 | | | 3,817 | |
| | PROVED DEVELOPED RESERVES | PROVED DEVELOPED RESERVES | | | | | | | | PROVED DEVELOPED RESERVES | | | |
| December 31, 2017 | | 1,063 | | | 79 | | | 786 | | | 1,928 | | |
| December 31, 2018 | | 1,202 | | | 79 | | | 721 | | | 2,002 | | |
| December 31, 2019 | | 2,145 | | | 78 | | | 775 | | | 2,998 | | |
December 31, 2020 (e) | | 1,569 | | | — | | | 697 | | | 2,266 | | |
| PROVED UNDEVELOPED RESERVES | | |
| December 31, 2017 | | 492 | | | 5 | | | 173 | | | 670 | | |
| December 31, 2018 | | 509 | | | 19 | | | 222 | | | 750 | | |
| December 31, 2019 | December 31, 2019 | | 653 | | | 25 | | | 228 | | | 906 | | December 31, 2019 | | 2,145 | | | | 853 | | | 2,998 | |
| December 31, 2020 | December 31, 2020 | | 367 | | | — | | | 278 | | | 645 | | December 31, 2020 | | 1,569 | | | | 697 | | | 2,266 | |
| December 31, 2021 | | December 31, 2021 | | 2,012 | | | | 635 | | | 2,647 | |
| December 31, 2022 | | December 31, 2022 | | 2,112 | | | | 586 | | | 2,698 | |
PROVED UNDEVELOPED RESERVES | | PROVED UNDEVELOPED RESERVES | | | |
| December 31, 2019 | | December 31, 2019 | | 653 | | | | 253 | | | 906 | |
| December 31, 2020 | | December 31, 2020 | | 367 | | | | 278 | | | 645 | |
| December 31, 2021 | | December 31, 2021 | | 588 | | | | 277 | | | 865 | |
| December 31, 2022 | | December 31, 2022 | | 860 | | | | 259 | | | 1,119 | |
(a)Excluded reserve amounts related to thediscontinued operations and held for sale assets. Reserves related to the Algeria assets have been reclassifiedin 2020 and included in prior and the current periods.2019. Proved reserves for held for sale assets as of December 31, 2021 were immaterial.
(b)Natural gas volumes have been converted to Boe based on an energy content of six Mcf of gas to one barrel of oil.Conversion to Boe does not necessarily result in price equivalency.
(c)Included proved reserves related to PSCs and other similar economic arrangements of 0.3 billion Boe at December 31, 2020, and 0.5 billion Boe at December 31, 2019, 2018 and 2017.
(d)Revisions of previous estimates in 2020 reflected negative2022 included the effects of new infill drilling, price revisions and other updates, including changes in reservoir performance, economic conditions and development plans. Positive revisions of 342335 MMboe were related to additions associated with infill development projects, primarily in the Permian Basin (283(232 MMboe) and the DJ Basin (74(94 MMboe). Another 136 MMboe of positive price revisions were primarily in the Permian Basin (147 MMboe), the Gulf of Mexico (8 MMBoe) and the DJ Basin (4 MMboe), partially offset by positivenegative price revisions of 3629 MMboe on international production sharing contracts. Another 197 MMboe in negative revisions were related to PSCs. Further positive revisions of 98 MMboe were associated with updates based on reservoir performance (93 MMboe) and changes in development plans primarily in the Permian Basin, which(5 MMboe). The positive revisions were offset by 57 MMboe in positivenegative revisions related to updates based on reservoir performance.
(e)Approximately 7% of the proved developed reserves at December 31, 2020, are nonproducing, primarily associated with the Permian Basin, Omanvarious other cost and Gulf of Mexico.interest related revisions (95 MMboe).
| | | | | |
122114 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
CAPITALIZED COSTS
Capitalized costs relating to oil and gas producing activities and related accumulated DD&A were as follows:
| | millions | millions | | United
States | | Latin
America | | Middle East / Africa | | Total | millions | | United States | | | International | | Total |
| December 31, 2020 | | | | | | | |
| December 31, 2022 | | December 31, 2022 | | | | | | |
| Proved properties | Proved properties | | $ | 63,988 | | | $ | 116 | | | $ | 14,432 | | | $ | 78,536 | | Proved properties | | $ | 71,314 | | | | $ | 15,733 | | | $ | 87,047 | |
| Unproved properties | Unproved properties | | 23,713 | | | 27 | | | 178 | | | 23,918 | | Unproved properties | | 17,251 | | | | 189 | | | 17,440 | |
Total capitalized costs (a) | Total capitalized costs (a) | | 87,701 | | | 143 | | | 14,610 | | | 102,454 | | Total capitalized costs (a) | | 88,565 | | | | 15,922 | | | 104,487 | |
| Proved properties depreciation, depletion and amortization | Proved properties depreciation, depletion and amortization | | (27,914) | | | (116) | | | (11,024) | | | (39,054) | | Proved properties depreciation, depletion and amortization | | (36,727) | | | | (12,373) | | | (49,100) | |
| Unproved properties valuation | Unproved properties valuation | | (5,285) | | | (27) | | | — | | | (5,312) | | Unproved properties valuation | | (4,781) | | | | (27) | | | (4,808) | |
| Total Accumulated depreciation, depletion and amortization | Total Accumulated depreciation, depletion and amortization | | (33,199) | | | (143) | | | (11,024) | | | (44,366) | | Total Accumulated depreciation, depletion and amortization | | (41,508) | | | | (12,400) | | | (53,908) | |
| Net capitalized costs | Net capitalized costs | | $ | 54,502 | | | $ | — | | | $ | 3,586 | | | $ | 58,088 | | Net capitalized costs | | $ | 47,057 | | | | $ | 3,522 | | | $ | 50,579 | |
| | December 31, 2019 | | | | | | | |
| December 31, 2021 | | December 31, 2021 | | | | | | |
| Proved properties | | Proved properties | | $ | 66,443 | | | | $ | 15,232 | | | $ | 81,675 | |
| Unproved properties | | Unproved properties | | 19,423 | | | | 153 | | | 19,576 | |
Total capitalized costs (a) | | Total capitalized costs (a) | | 85,866 | | | | 15,385 | | | 101,251 | |
| Proved properties depreciation, depletion and amortization | | Proved properties depreciation, depletion and amortization | | (32,355) | | | | (11,821) | | | (44,176) | |
| Unproved properties valuation | | Unproved properties valuation | | (4,789) | | | | (27) | | | (4,816) | |
| Total Accumulated depreciation, depletion and amortization | | Total Accumulated depreciation, depletion and amortization | | (37,144) | | | | (11,848) | | | (48,992) | |
| Net capitalized costs | | Net capitalized costs | | $ | 48,722 | | | | $ | 3,537 | | | $ | 52,259 | |
| | December 31, 2020 | | December 31, 2020 | | | | | | |
| Proved properties | Proved properties | | $ | 59,658 | | | $ | 3,667 | | | $ | 13,707 | | | $ | 77,032 | | Proved properties | | $ | 63,988 | | | | $ | 14,548 | | | $ | 78,536 | |
| Unproved properties | Unproved properties | | 30,301 | | | 36 | | | 432 | | | 30,769 | | Unproved properties | | 23,713 | | | | 205 | | | 23,918 | |
Total capitalized costs (a,b) | Total capitalized costs (a,b) | | 89,959 | | | 3,703 | | | 14,139 | | | 107,801 | | Total capitalized costs (a,b) | | 87,701 | | | | 14,753 | | | 102,454 | |
| Proved properties depreciation, depletion and amortization | Proved properties depreciation, depletion and amortization | | (20,961) | | | (2,643) | | | (9,012) | | | (32,616) | | Proved properties depreciation, depletion and amortization | | (27,914) | | | | (11,140) | | | (39,054) | |
| Unproved properties valuation | Unproved properties valuation | | (1,025) | | | (27) | | | (170) | | | (1,222) | | Unproved properties valuation | | (5,285) | | | | (27) | | | (5,312) | |
| Total Accumulated depreciation, depletion and amortization | Total Accumulated depreciation, depletion and amortization | | (21,986) | | | (2,670) | | | (9,182) | | | (33,838) | | Total Accumulated depreciation, depletion and amortization | | (33,199) | | | | (11,167) | | | (44,366) | |
| Net capitalized costs | Net capitalized costs | | $ | 67,973 | | | $ | 1,033 | | | $ | 4,957 | | | $ | 73,963 | | Net capitalized costs | | $ | 54,502 | | | | $ | 3,586 | | | $ | 58,088 | |
| | December 31, 2018 | | | | | | | |
| Proved properties | | $ | 35,717 | | | $ | 3,436 | | | $ | 17,302 | | | $ | 56,455 | | |
| Unproved properties | | 1,900 | | | 43 | | | 401 | | | 2,344 | | |
Total capitalized costs (a) | | 37,617 | | | 3,479 | | | 17,703 | | | 58,799 | | |
| Proved properties depreciation, depletion and amortization | | (17,188) | | | (2,514) | | | (14,286) | | | (33,988) | | |
| Unproved properties valuation | | (1,200) | | | (27) | | | (85) | | | (1,312) | | |
| Total Accumulated depreciation, depletion and amortization | | (18,388) | | | (2,541) | | | (14,371) | | | (35,300) | | |
| Net capitalized costs | | $ | 19,229 | | | $ | 938 | | | $ | 3,332 | | | $ | 23,499 | | |
(a)Included acquisition costs, development costs, capitalized interest and asset retirement obligations. AROs.
(b)Excluded capitalized costs related to Ghana, which iswas presented as held for sale. Capitalized costs related to the Algeria assets have been reclassified and included in prior and the current periods.
(b)$50.3 billionsale as of capitalized costs are associated with the Acquisition.December 31, 2020.
| | | | | |
OXY 20202022 FORM 10-K | 123115 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
COSTS INCURRED
Costs incurred in oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, were as follows:
| | millions | millions | | United
States | | Latin
America | | Middle East / Africa | | Total | millions | | United States | | | International | | Total |
December 31, 2020 (a) | | | | | | | |
| December 31, 2022 | | December 31, 2022 | | | | | |
Property acquisition costs (a) | | Property acquisition costs (a) | | | | | |
| Proved properties | | Proved properties | | $ | 496 | | | | $ | 3 | | | $ | 499 | |
| Unproved properties | | Unproved properties | | 488 | | | | — | | | 488 | |
| Exploration costs | | Exploration costs | | 279 | | | | 175 | | | 454 | |
| Development costs | | Development costs | | 3,083 | | | | 423 | | | 3,506 | |
| Costs incurred | | Costs incurred | | $ | 4,346 | | | | $ | 601 | | | $ | 4,947 | |
December 31, 2021 (b) | | December 31, 2021 (b) | | | |
| Property acquisition costs | Property acquisition costs | | | | | | | Property acquisition costs | | | |
| Proved properties | Proved properties | | $ | 7 | | | $ | 2 | | | $ | 33 | | | $ | 42 | | Proved properties | | $ | 378 | | | | $ | 1 | | | $ | 379 | |
| Unproved properties | Unproved properties | | 41 | | | 19 | | | 5 | | | 65 | | Unproved properties | | 51 | | | | — | | | 51 | |
| Exploration costs | Exploration costs | | 117 | | | 11 | | | 84 | | | 212 | | Exploration costs | | 147 | | | | 143 | | | 290 | |
| Development costs | Development costs | | 1,376 | | | 65 | | | 401 | | | 1,842 | | Development costs | | 1,749 | | | | 366 | | | 2,115 | |
| Costs incurred | Costs incurred | | $ | 1,541 | | | $ | 97 | | | $ | 523 | | | $ | 2,161 | | Costs incurred | | $ | 2,325 | | | | $ | 510 | | | $ | 2,835 | |
December 31, 2019 (b) | | | | | | | |
December 31, 2020 (b) | | December 31, 2020 (b) | | | |
| Property acquisition costs | Property acquisition costs | | | | | | | Property acquisition costs | | | |
| Proved properties | Proved properties | | $ | 19,567 | | | $ | 6 | | | $ | 1,909 | | | $ | 21,482 | | Proved properties | | $ | 7 | | | | $ | 35 | | | $ | 42 | |
| Unproved properties | Unproved properties | | 29,042 | | | 1 | | | 11 | | | 29,054 | | Unproved properties | | 41 | | | | 24 | | | 65 | |
| Exploration costs | Exploration costs | | 307 | | | 58 | | | 142 | | | 507 | | Exploration costs | | 117 | | | | 95 | | | 212 | |
| Development costs | Development costs | | 4,449 | | | 196 | | | 575 | | | 5,220 | | Development costs | | 1,376 | | | | 466 | | | 1,842 | |
| Costs incurred | Costs incurred | | $ | 53,365 | | | $ | 261 | | | $ | 2,637 | | | $ | 56,263 | | Costs incurred | | $ | 1,541 | | | | $ | 620 | | | $ | 2,161 | |
| December 31, 2018 | | | | | | | |
| Property acquisition costs | | | | | | | |
| Proved properties | | $ | 428 | | | $ | — | | | $ | — | | | $ | 428 | | |
| Unproved properties | | 46 | | | 4 | | | 2 | | | 52 | | |
| Exploration costs | | 196 | | | 42 | | | 44 | | | 282 | | |
| Development costs | | 3,387 | | | 203 | | | 698 | | | 4,288 | | |
| Costs incurred | | $ | 4,057 | | | $ | 249 | | | $ | 744 | | | $ | 5,050 | | |
(a)ExcludedIncluded $340 million in property acquisition costs incurred related to Ghana, which is presented as held for sale.non-monetary exchange transactions.
(b)Excluded costs incurred related to the Mozambique (sold 2019), South Africa (sold 2020) and Ghana assets (held for sale). Costs incurred related to the Algeria assets have been reclassified and included to reflect the Algeria operations as continued operations.(sold 2021) assets.
| | | | | |
124116 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
RESULTS OF OPERATIONS
Occidental’s oil and gas producing activities for continuing operations, which exclude items such as asset divestitures, corporate overhead, interest and royalties, were as follows:
| | millions | millions | | United
States | | Latin
America | | Middle East / Africa | | Total | millions | | United States | | | International (a) | | Total |
| FOR THE YEAR ENDED DECEMBER 31, 2020 | | | | | | | |
Revenues (a) | | $ | 9,058 | | | $ | 467 | | | $ | 2,480 | | | $ | 12,005 | | |
| FOR THE YEAR ENDED DECEMBER 31, 2022 | | FOR THE YEAR ENDED DECEMBER 31, 2022 | | | | | |
Revenues (b) | | Revenues (b) | | $ | 22,487 | | | | $ | 4,671 | | | $ | 27,158 | |
| Lease operating costs | | Lease operating costs | | 3,050 | | | | 978 | | | 4,028 | |
| Transportation costs | | Transportation costs | | 1,324 | | | | 69 | | | 1,393 | |
| Other operating expenses | | Other operating expenses | | 981 | | | | 235 | | | 1,216 | |
| Depreciation, depletion and amortization | | Depreciation, depletion and amortization | | 5,608 | | | | 571 | | | 6,179 | |
| Taxes other than on income | | Taxes other than on income | | 1,236 | | | | 299 | | | 1,535 | |
| Exploration expenses | | Exploration expenses | | 113 | | | | 103 | | | 216 | |
| | Pretax income (loss) | | Pretax income (loss) | | 10,175 | | | | 2,416 | | | 12,591 | |
Income tax expense (benefit) (c) | | Income tax expense (benefit) (c) | | 2,213 | | | | 964 | | | 3,177 | |
| Results of operations | | Results of operations | | $ | 7,962 | | | | $ | 1,452 | | | $ | 9,414 | |
| FOR THE YEAR ENDED DECEMBER 31, 2021 | | FOR THE YEAR ENDED DECEMBER 31, 2021 | | | |
Revenues (b) | | Revenues (b) | | $ | 15,817 | | | | $ | 3,462 | | | $ | 19,279 | |
| Lease operating costs | Lease operating costs | | 2,169 | | | 133 | | | 788 | | | 3,090 | | Lease operating costs | | 2,341 | | | | 883 | | | 3,224 | |
| Transportation costs | Transportation costs | | 1,425 | | | 9 | | | 63 | | | 1,497 | | Transportation costs | | 1,306 | | | | 65 | | | 1,371 | |
| Other operating expenses | Other operating expenses | | 960 | | | 42 | | | 179 | | | 1,181 | | Other operating expenses | | 896 | | | | 176 | | | 1,072 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | | 6,611 | | | 125 | | | 678 | | | 7,414 | | Depreciation, depletion and amortization | | 7,053 | | | | 687 | | | 7,740 | |
| Taxes other than on income | Taxes other than on income | | 503 | | | 6 | | | 105 | | | 614 | | Taxes other than on income | | 785 | | | | 209 | | | 994 | |
| Exploration expenses | Exploration expenses | | 68 | | | 10 | | | 54 | | | 132 | | Exploration expenses | | 158 | | | | 94 | | | 252 | |
Oil and gas mark-to-market - Collars and CO2 | Oil and gas mark-to-market - Collars and CO2 | | (1,089) | | | — | | | — | | | (1,089) | | Oil and gas mark-to-market - Collars and CO2 | | 280 | | | | — | | | 280 | |
| Pretax income (loss) before impairments and other charges | Pretax income (loss) before impairments and other charges | | (1,589) | | | 142 | | | 613 | | | (834) | | Pretax income (loss) before impairments and other charges | | 2,998 | | | | 1,348 | | | 4,346 | |
| Asset impairments and other charges | Asset impairments and other charges | | 5,973 | | | 21 | | | 1,187 | | | 7,181 | | Asset impairments and other charges | | 282 | | | | — | | | 282 | |
| Pretax income (loss) | Pretax income (loss) | | (7,562) | | | 121 | | | (574) | | | (8,015) | | Pretax income (loss) | | 2,716 | | | | 1,348 | | | 4,064 | |
Income tax expense (benefit) (b) | | (1,663) | | | 65 | | | 363 | | | (1,235) | | |
Results of operations (c) | | $ | (5,899) | | | $ | 56 | | | $ | (937) | | | $ | (6,780) | | |
| FOR THE YEAR ENDED DECEMBER 31, 2019 | | | | | | | |
Revenues (a) | | $ | 9,497 | | | $ | 703 | | | $ | 3,853 | | | $ | 14,053 | | |
Income tax expense (benefit) (c) | | Income tax expense (benefit) (c) | | 508 | | | | 656 | | | 1,164 | |
| Results of operations | | Results of operations | | $ | 2,208 | | | | $ | 692 | | | $ | 2,900 | |
| FOR THE YEAR ENDED DECEMBER 31, 2020 | | FOR THE YEAR ENDED DECEMBER 31, 2020 | | | |
Revenues (b) | | Revenues (b) | | $ | 9,058 | | | | $ | 2,947 | | | $ | 12,005 | |
| Lease operating costs | Lease operating costs | | 2,271 | | | 163 | | | 940 | | | 3,374 | | Lease operating costs | | 2,169 | | | | 921 | | | 3,090 | |
| Transportation costs | Transportation costs | | 647 | | | 5 | | | 92 | | | 744 | | Transportation costs | | 1,425 | | | | 72 | | | 1,497 | |
| Other operating expenses | Other operating expenses | | 1,125 | | | 51 | | | 207 | | | 1,383 | | Other operating expenses | | 960 | | | | 221 | | | 1,181 | |
| Depreciation, depletion and amortization | Depreciation, depletion and amortization | | 4,113 | | | 135 | | | 905 | | | 5,153 | | Depreciation, depletion and amortization | | 6,611 | | | | 803 | | | 7,414 | |
| Taxes other than on income | Taxes other than on income | | 651 | | | 8 | | | 133 | | | 792 | | Taxes other than on income | | 503 | | | | 111 | | | 614 | |
| Exploration expenses | Exploration expenses | | 99 | | | 45 | | | 103 | | | 247 | | Exploration expenses | | 68 | | | | 64 | | | 132 | |
Oil and gas mark-to-market - Collars and CO2 | Oil and gas mark-to-market - Collars and CO2 | | 15 | | | — | | | — | | | 15 | | Oil and gas mark-to-market - Collars and CO2 | | (1,089) | | | | — | | | (1,089) | |
| Pretax income before impairments and other charges | | 576 | | | 296 | | | 1,473 | | | 2,345 | | |
| Pretax income (loss) before impairments and other charges | | Pretax income (loss) before impairments and other charges | | (1,589) | | | | 755 | | | (834) | |
| Asset impairments and other charges | Asset impairments and other charges | | 288 | | | — | | | 39 | | | 327 | | Asset impairments and other charges | | 5,973 | | | | 1,208 | | | 7,181 | |
| Pretax income | | 288 | | | 296 | | | 1,434 | | | 2,018 | | |
Income tax expense (b) | | 74 | | | 135 | | | 802 | | | 1,011 | | |
Results of operations (d) | | $ | 214 | | | $ | 161 | | | $ | 632 | | | $ | 1,007 | | |
| FOR THE YEAR ENDED DECEMBER 31, 2018 | | | | | | | |
Revenues (a) | | $ | 5,747 | | | $ | 731 | | | $ | 3,963 | | | $ | 10,441 | | |
| Lease operating costs | | 1,675 | | | 151 | | | 939 | | | 2,765 | | |
| Transportation costs | | 11 | | | 3 | | | 98 | | | 112 | | |
| Other operating expenses | | 676 | | | 49 | | | 186 | | | 911 | | |
| Depreciation, depletion and amortization | | 2,321 | | | 102 | | | 831 | | | 3,254 | | |
| Taxes other than on income | | 407 | | | 6 | | | — | | | 413 | | |
| Exploration expenses | | 64 | | | 19 | | | 27 | | | 110 | | |
Oil and gas mark-to-market - CO2 | | (4) | | | — | | | — | | | (4) | | |
| Pretax income before impairments and other charges | | 597 | | | 401 | | | 1,882 | | | 2,880 | | |
| Asset impairments and other charges | | 32 | | | — | | | 416 | | | 448 | | |
| Pretax income | | 565 | | | 401 | | | 1,466 | | | 2,432 | | |
Income tax expense (benefit) (b) | | (131) | | | 174 | | | 925 | | | 968 | | |
| Pretax income (loss) | | Pretax income (loss) | | (7,562) | | | | (453) | | | (8,015) | |
Income tax expense (benefit) (c) | | Income tax expense (benefit) (c) | | (1,663) | | | | 428 | | | (1,235) | |
| Results of operations | Results of operations | | $ | 696 | | | $ | 227 | | | $ | 541 | | | $ | 1,464 | | Results of operations | | $ | (5,899) | | | | $ | (881) | | | $ | (6,780) | |
(a)Revenues are net of royalty payments.
(b)U.S. federal income taxes reflect certain expenses related to oil and gas activities allocated for U.S. income tax purposes. These amounts are computed using the statutory rate in effect during the period.
(c)The 2020 results of operations excluded Ghana, which is presented as discontinued operations.
(d)The 2019 resultsResults of operations excluded discontinued operations related to the Mozambique, South Africa (sold 2020) and Ghana (sold 2021) assets. Results of operations related to the Algeria assets have been reclassified and are included to reflect the Algeria operations as continuing operations.
| | | | | |
| Supplemental Oil and Gas Information
(Unaudited)
|
RESULTS PER UNIT OF PRODUCTION FOR CONTINUING OPERATIONS
| | | | | | | | | | | | | | | | | | | | | | | | | | |
$/Boe (a) | | United
States | | Latin
America | | Middle East / Africa | | Total |
| FOR THE YEAR ENDED DECEMBER 31, 2020 | | | | | | | | |
Revenues (b) | | $ | 23.86 | | | $ | 38.59 | | | $ | 26.79 | | | $ | 24.79 | |
| Lease operating costs | | 5.71 | | | 10.96 | | | 8.51 | | | 6.38 | |
| Transportation costs | | 3.75 | | | 0.73 | | | 0.68 | | | 3.09 | |
| Other operating expenses | | 2.53 | | | 3.48 | | | 1.93 | | | 2.44 | |
| Depreciation, depletion and amortization | | 17.41 | | | 10.33 | | | 7.32 | | | 15.31 | |
| Taxes other than on income | | 1.32 | | | 0.48 | | | 1.14 | | | 1.27 | |
| Exploration expenses | | 0.18 | | | 0.84 | | | 0.58 | | | 0.27 | |
Oil and gas mark-to-market - Collars and CO2 | | (2.87) | | | — | | | — | | | (2.25) | |
| Pretax income (loss) before impairments and other charges | | (4.17) | | | 11.77 | | | 6.63 | | | (1.72) | |
| Asset impairments and other charges | | 15.73 | | | 1.75 | | | 12.81 | | | 14.83 | |
| Pretax income (loss) | | (19.90) | | | 10.02 | | | (6.18) | | | (16.55) | |
Income tax expense (benefit) (c) | | (4.38) | | | 5.40 | | | 3.92 | | | (2.55) | |
Results of operations (d) | | $ | (15.52) | | | $ | 4.62 | | | $ | (10.10) | | | $ | (14.00) | |
| FOR THE YEAR ENDED DECEMBER 31, 2019 | | | | | | | | |
Revenues (b) | | $ | 36.43 | | | $ | 56.70 | | | $ | 38.97 | | | $ | 37.78 | |
| Lease operating costs | | 8.71 | | | 13.18 | | | 9.51 | | | 9.07 | |
| Transportation costs | | 2.48 | | | 0.34 | | | 0.93 | | | 2.00 | |
| Other operating expenses | | 4.32 | | | 4.15 | | | 2.10 | | | 3.72 | |
| Depreciation, depletion and amortization | | 15.78 | | | 10.85 | | | 9.15 | | | 13.85 | |
| Taxes other than on income | | 2.50 | | | 0.63 | | | 1.35 | | | 2.13 | |
| Exploration expenses | | 0.38 | | | 3.66 | | | 1.01 | | | 0.66 | |
Oil and gas mark-to-market - CO2 | | 0.06 | | | — | | | — | | | 0.04 | |
| Pretax income before impairments and other charges | | 2.20 | | | 23.89 | | | 14.92 | | | 6.31 | |
| Asset impairments and other charges | | 1.11 | | | — | | | 0.43 | | | 0.88 | |
| Pretax income | | 1.09 | | | 23.89 | | | 14.49 | | | 5.43 | |
Income tax expense (c) | | 0.29 | | | 10.90 | | | 8.10 | | | 2.72 | |
Results of operations (e) | | $ | 0.80 | | | $ | 12.99 | | | $ | 6.39 | | | $ | 2.71 | |
| FOR THE YEAR ENDED DECEMBER 31, 2018 | | | | | | | | |
Revenues (b) | | $ | 42.30 | | | $ | 63.37 | | | $ | 42.78 | | | $ | 43.50 | |
| Lease operating costs | | 12.33 | | | 13.08 | | | 10.14 | | | 11.52 | |
| Transportation costs | | 0.08 | | | 0.24 | | | 1.06 | | | 0.47 | |
| Other operating expenses | | 4.98 | | | 4.24 | | | 2.01 | | | 3.79 | |
| Depreciation, depletion and amortization | | 17.08 | | | 8.88 | | | 8.96 | | | 13.56 | |
| Taxes other than on income | | 3.00 | | | 0.52 | | | — | | | 1.72 | |
| Exploration expenses | | 0.47 | | | 1.65 | | | 0.29 | | | 0.46 | |
Oil and gas mark-to-market - CO2 | | (0.03) | | | — | | | — | | | (0.01) | |
| Pretax income before impairments and other charges | | 4.39 | | | 34.76 | | | 20.32 | | | 11.99 | |
| Asset impairments and other charges | | 0.24 | | | — | | | 4.49 | | | 1.87 | |
| Pretax income | | 4.15 | | | 34.76 | | | 15.83 | | | 10.12 | |
Income tax expense (benefit) (c) | | (0.96) | | | 15.08 | | | 9.99 | | | 4.03 | |
| Results of operations | | $ | 5.11 | | | $ | 19.68 | | | $ | 5.84 | | | $ | 6.09 | |
(a)Natural gas volumes have been converted to Boe based on energy content of six Mcf of gas to one barrel of oil.
(b)Revenues are net of royalty payments.
(c)U.S. federal income taxes reflect certain expenses related to oil and gas activities allocated for U.S. income tax purposes. These amounts are computed using the statutory rate in effect during the period.
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
RESULTS PER UNIT OF PRODUCTION FOR CONTINUING OPERATIONS
| | | | | | | | | | | | | | | | | | | | | | | | |
$/Boe (a) | | United States | | | | | | International (b) | | Total |
| FOR THE YEAR ENDED DECEMBER 31, 2022 | | | | | | | | | | |
Revenues (c) | | $ | 65.77 | | | | | | | $ | 57.67 | | | $ | 64.22 | |
| Lease operating costs | | 8.92 | | | | | | | 12.07 | | | 9.52 | |
| Transportation costs | | 3.87 | | | | | | | 0.85 | | | 3.29 | |
| Other operating expenses | | 2.87 | | | | | | | 2.90 | | | 2.88 | |
| Depreciation, depletion and amortization | | 16.40 | | | | | | | 7.05 | | | 14.61 | |
| Taxes other than on income | | 3.61 | | | | | | | 3.69 | | | 3.63 | |
| Exploration expenses | | 0.33 | | | | | | | 1.27 | | | 0.51 | |
| | | | | | | | | | |
| | | | | | | | | | |
| Pretax income (loss) | | 29.77 | | | | | | | 29.84 | | | 29.78 | |
Income tax expense (d) | | 6.47 | | | | | | | 11.90 | | | 7.51 | |
| Results of operations | | $ | 23.30 | | | | | | | $ | 17.94 | | | $ | 22.27 | |
| FOR THE YEAR ENDED DECEMBER 31, 2021 | | | | | | | | | | |
Revenues (c) | | $ | 46.42 | | | | | | | $ | 40.82 | | | $ | 45.31 | |
| Lease operating costs | | 6.87 | | | | | | | 10.41 | | | 7.58 | |
| Transportation costs | | 3.83 | | | | | | | 0.76 | | | 3.22 | |
| Other operating expenses | | 2.63 | | | | | | | 2.08 | | | 2.52 | |
| Depreciation, depletion and amortization | | 20.70 | | | | | | | 8.10 | | | 18.19 | |
| Taxes other than on income | | 2.30 | | | | | | | 2.47 | | | 2.34 | |
| Exploration expenses | | 0.46 | | | | | | | 1.10 | | | 0.59 | |
Oil and gas mark-to-market - Collars and CO2 | | 0.82 | | | | | | | — | | | 0.66 | |
| Pretax income (loss) before impairments and other charges | | 8.81 | | | | | | | 15.90 | | | 10.21 | |
| Asset impairments and other charges | | 0.83 | | | | | | | — | | | 0.66 | |
| Pretax income (loss) | | 7.98 | | | | | | | 15.90 | | | 9.55 | |
Income tax expense (d) | | 1.49 | | | | | | | 7.73 | | | 2.73 | |
| Results of operations | | $ | 6.49 | | | | | | | $ | 8.17 | | | $ | 6.82 | |
| FOR THE YEAR ENDED DECEMBER 31, 2020 | | | | | | | | | | |
Revenues (c) | | $ | 23.86 | | | | | | | $ | 28.15 | | | $ | 24.79 | |
| Lease operating costs | | 5.71 | | | | | | | 8.80 | | | 6.38 | |
| Transportation costs | | 3.75 | | | | | | | 0.69 | | | 3.09 | |
| Other operating expenses | | 2.53 | | | | | | | 2.11 | | | 2.44 | |
| Depreciation, depletion and amortization | | 17.41 | | | | | | | 7.67 | | | 15.31 | |
| Taxes other than on income | | 1.32 | | | | | | | 1.06 | | | 1.27 | |
| Exploration expenses | | 0.18 | | | | | | | 0.61 | | | 0.27 | |
Oil and gas mark-to-market - CO2 | | (2.87) | | | | | | | — | | | (2.25) | |
| Pretax income (loss) before impairments and other charges | | (4.17) | | | | | | | 7.21 | | | (1.72) | |
| Asset impairments and other charges | | 15.73 | | | | | | | 11.54 | | | 14.83 | |
| Pretax income (loss) | | (19.90) | | | | | | | (4.33) | | | (16.55) | |
Income tax expense (benefit) (d) | | (4.38) | | | | | | | 4.09 | | | (2.55) | |
| Results of operations | | $ | (15.52) | | | | | | | $ | (8.42) | | | $ | (14.00) | |
(d)(a)The 2020 resultsNatural gas volumes have been converted to Boe based on energy content of operations excluded Ghana, which is presented in discontinued operations.six Mcf of gas to one barrel of oil.
(e)(b)The 2019 resultsResults of operations excluded discontinued operations related to the Mozambique, South Africa (sold 2020) and Ghana (sold 2021) assets. Results
(c)Revenues are net of operationsroyalty payments.
(d)U.S. federal income taxes reflect certain expenses related to oil and gas activities allocated for U.S. income tax purposes. These amounts are computed using the Algeria assets have been reclassified and are included to reflectstatutory rate in effect during the Algeria operations as continuing operations.period.
| | | | | |
126118 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
STANDARDIZED MEASURE, INCLUDING YEAR-TO-YEAR CHANGES THEREIN, OF DISCOUNTED FUTURE NET CASH FLOWS
For purposes of the following disclosures, future cash flows were computed by applying to Occidental’s proved oil and gas reserves the unweighted arithmetic average of the first-day-of-the-month price for each month within the years ended December 31, 2020, 20192022, 2021 and 2018,2020, respectively, unless prices were defined by contractual arrangements, and exclude escalations based upon future conditions. The realized prices used to calculate future cash flows vary by producing area and market conditions. Future operating and capital costs were forecast using the current cost environment applied to expectations of future operating and development activities to develop and produce proved reserves at year end.
Future income tax expenses were computed by applying, generally, year-end statutory tax rates (adjusted for permanent differences, tax credits, allowances and foreign income repatriation considerations) to the estimated net future pre-tax cash flows. The discount was computed by application of a 10% discount factor. The calculations assumed the continuation of existing economic, operating and contractual conditions atas of December 31, 2020, 20192022, 2021 and 2018.2020. Such assumptions, which are required by regulation, have not always proven accurate in the past. Other valid assumptions would give rise to substantially different results.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | United
States | | Latin
America | | Middle East / Africa | | Total |
| AT DECEMBER 31, 2020 | | | | | | | | |
| Future cash inflows | | $ | 49,050 | | | $ | — | | | $ | 21,270 | | | $ | 70,320 | |
| Future costs | | | | | | | | |
| Production costs and other operating | | (29,147) | | | — | | | (8,304) | | | (37,451) | |
Development costs (a) | | (9,103) | | | (6) | | | (2,404) | | | (11,513) | |
| Future income tax expense | | (19) | | | — | | | (2,088) | | | (2,107) | |
| Future net cash flows | | 10,781 | | | (6) | | | 8,474 | | | 19,249 | |
| 10% discount factor | | (3,827) | | | — | | | (4,071) | | | (7,898) | |
Standardized measure of discounted future net cash flows (b) | | $ | 6,954 | | | $ | (6) | | | $ | 4,403 | | | $ | 11,351 | |
| AT DECEMBER 31, 2019 | | | | | | | | |
| Future cash inflows | | $ | 97,293 | | | $ | 5,803 | | | $ | 33,258 | | | $ | 136,354 | |
| Future costs | | | | | | | | |
| Production costs and other operating | | (47,685) | | | (2,824) | | | (11,318) | | | (61,827) | |
Development costs (a) | | (13,137) | | | (553) | | | (2,719) | | | (16,409) | |
| Future income tax expense | | (4,097) | | | (687) | | | (3,842) | | | (8,626) | |
| Future net cash flows | | 32,374 | | | 1,739 | | | 15,379 | | | 49,492 | |
| 10% discount factor | | (12,427) | | | (701) | | | (7,135) | | | (20,263) | |
Standardized measure of discounted future net cash flows (c) | | $ | 19,947 | | | $ | 1,038 | | | $ | 8,244 | | | $ | 29,229 | |
| AT DECEMBER 31, 2018 | | | | | | | | |
| Future cash inflows | | $ | 75,313 | | | $ | 6,104 | | | $ | 31,158 | | | $ | 112,575 | |
| Future costs | | | | | | | | |
| Production costs and other operating | | (33,373) | | | (2,673) | | | (9,609) | | | (45,655) | |
Development costs (a) | | (9,450) | | | (377) | | | (2,136) | | | (11,963) | |
| Future income tax expense | | (4,150) | | | (959) | | | (3,524) | | | (8,633) | |
| Future net cash flows | | 28,340 | | | 2,095 | | | 15,889 | | | 46,324 | |
| 10% discount factor | | (14,288) | | | (846) | | | (7,729) | | | (22,863) | |
| Standardized measure of discounted future net cash flows | | $ | 14,052 | | | $ | 1,249 | | | $ | 8,160 | | | $ | 23,461 | |
| | | | | | | | | | | | | | | | | | | | | | | | |
| millions | | United States | | | | | | International (a) | | Total |
| Balance as of December 31, 2022 | | | | | | | | | | |
| Future cash inflows | | $ | 186,942 | | | | | | | $ | 34,514 | | | $ | 221,456 | |
| Future costs | | | | | | | | | | |
| Production costs and other operating | | (68,068) | | | | | | | (9,468) | | | (77,536) | |
Development costs (b) | | (14,845) | | | | | | | (2,498) | | | (17,343) | |
| Future income tax expense | | (18,633) | | | | | | | (4,984) | | | (23,617) | |
| Future net cash flows | | 85,396 | | | | | | | 17,564 | | | 102,960 | |
| 10% discount factor | | (37,340) | | | | | | | (7,468) | | | (44,808) | |
| Standardized measure of discounted future net cash flows | | $ | 48,056 | | | | | | | $ | 10,096 | | | $ | 58,152 | |
| Balance as of December 31, 2021 | | | | | | | | | | |
| Future cash inflows | | $ | 116,014 | | | | | | | $ | 28,865 | | | $ | 144,879 | |
| Future costs | | | | | | | | | | |
| Production costs and other operating | | (47,803) | | | | | | | (9,284) | | | (57,087) | |
Development costs (b) | | (12,186) | | | | | | | (3,004) | | | (15,190) | |
| Future income tax expense | | (9,875) | | | | | | | (3,544) | | | (13,419) | |
| Future net cash flows | | 46,150 | | | | | | | 13,033 | | | 59,183 | |
| 10% discount factor | | (19,538) | | | | | | | (5,821) | | | (25,359) | |
| Standardized measure of discounted future net cash flows | | $ | 26,612 | | | | | | | $ | 7,212 | | | $ | 33,824 | |
| Balance as of December 31, 2020 | | | | | | | | | | |
| Future cash inflows | | $ | 49,050 | | | | | | | $ | 21,270 | | | $ | 70,320 | |
| Future costs | | | | | | | | | | |
| Production costs and other operating | | (29,147) | | | | | | | (8,304) | | | (37,451) | |
Development costs (b) | | (9,103) | | | | | | | (2,410) | | | (11,513) | |
| Future income tax expense | | (19) | | | | | | | (2,088) | | | (2,107) | |
| Future net cash flows | | 10,781 | | | | | | | 8,468 | | | 19,249 | |
| 10% discount factor | | (3,827) | | | | | | | (4,071) | | | (7,898) | |
| Standardized measure of discounted future net cash flows | | $ | 6,954 | | | | | | | $ | 4,397 | | | $ | 11,351 | |
(a)Included asset retirement costs.Excluded discontinued operations related to Ghana (sold 2021).
(b)2020 excluded discounted future net cash flows of $0.1 billion related to Ghana, which is presented as held for sale.Included ARO costs.
(c)2019 excluded discounted future net cash flows of $0.8 billion related to Occidental’s Mozambique (sold 2019), South Africa (sold 2020) and Ghana (held for sale) assets. Discounted future net cash flows for Algeria of $1.2 billion have been reclassified and included.
| | | | | |
OXY 20202022 FORM 10-K | 127119 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS FROM PROVED RESERVE QUANTITIES(a)
| | millions | millions | | 2020 | | 2019 (a) | | 2018 | millions | | 2022 | | 2021 | | 2020 |
| Balance at January 1 | | $ | 29,229 | | | $ | 23,461 | | | $ | 16,220 | | |
| Balance as of January 1 | | Balance as of January 1 | | $ | 33,824 | | | $ | 11,351 | | | $ | 29,229 | |
| Sales and transfers of oil and gas produced, net of production costs and other operating expenses | Sales and transfers of oil and gas produced, net of production costs and other operating expenses | | (6,483) | | | (9,207) | | | (7,828) | | Sales and transfers of oil and gas produced, net of production costs and other operating expenses | | (20,547) | | | (13,983) | | | (6,483) | |
| Net change in prices received per barrel, net of production costs and other operating expenses | Net change in prices received per barrel, net of production costs and other operating expenses | | (19,738) | | | (6,506) | | | 9,482 | | Net change in prices received per barrel, net of production costs and other operating expenses | | 29,798 | | | 32,464 | | | (19,738) | |
| Extensions, discoveries and improved recovery, net of future production and development costs | Extensions, discoveries and improved recovery, net of future production and development costs | | 1,007 | | | 2,607 | | | 3,378 | | Extensions, discoveries and improved recovery, net of future production and development costs | | 5,390 | | | 2,412 | | | 1,007 | |
| Change in estimated future development costs | Change in estimated future development costs | | 1,686 | | | (1,666) | | | (3,463) | | Change in estimated future development costs | | (1,562) | | | (376) | | | 1,686 | |
| Revisions of quantity estimates | Revisions of quantity estimates | | (1,989) | | | (2,172) | | | 664 | | Revisions of quantity estimates | | 10,481 | | | 10,296 | | | (1,989) | |
| Previously estimated development costs incurred during the period | Previously estimated development costs incurred during the period | | 1,680 | | | 3,304 | | | 1,943 | | Previously estimated development costs incurred during the period | | 1,813 | | | 1,277 | | | 1,680 | |
| Accretion of discount | Accretion of discount | | 2,541 | | | 2,381 | | | 1,551 | | Accretion of discount | | 3,492 | | | 1,009 | | | 2,541 | |
| Net change in income taxes | Net change in income taxes | | 3,212 | | | 3,285 | | | (1,182) | | Net change in income taxes | | (5,961) | | | (6,249) | | | 3,212 | |
| Purchases and sales of reserves in place, net | Purchases and sales of reserves in place, net | | (651) | | | 11,229 | | | 347 | | Purchases and sales of reserves in place, net | | (158) | | | 377 | | | (651) | |
| Changes in production rates and other | Changes in production rates and other | | 857 | | | 2,513 | | | 2,349 | | Changes in production rates and other | | 1,582 | | | (4,754) | | | 857 | |
| Net change | Net change | | (17,878) | | | 5,768 | | | 7,241 | | Net change | | 24,328 | | | 22,473 | | | (17,878) | |
| Balance at December 31 | | $ | 11,351 | | | $ | 29,229 | | | $ | 23,461 | | |
| Balance as of December 31 | | Balance as of December 31 | | $ | 58,152 | | | $ | 33,824 | | | $ | 11,351 | |
(a)2019 values have been adjusted to reclassify and reflect the Algeria operations as continuing Excluded results from discontinued operations.
AVERAGE SALES PRICE
The following table sets forth, for each year in the three-year period ended December 31, 2020, Occidental’s approximate average sales prices in continuing operations:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | United
States | | Latin
America | | Middle East / Africa | | Total |
| 2020 | | | | | | | | |
| Oil ($/Bbl) | | $ | 36.39 | | | $ | 38.80 | | | $ | 41.52 | | | $ | 37.41 | |
| NGL ($/Bbl) | | $ | 11.98 | | | $ | — | | | $ | 16.22 | | | $ | 12.58 | |
| Gas ($/Mcf) | | $ | 1.18 | | | $ | 5.41 | | | $ | 1.62 | | | $ | 1.31 | |
| 2019 | | | | | | | | |
| Oil ($/Bbl) | | $ | 54.31 | | | $ | 57.26 | | | $ | 62.03 | | | $ | 56.32 | |
| NGL ($/Bbl) | | $ | 16.03 | | | $ | — | | | $ | 21.85 | | | $ | 17.20 | |
| Gas ($/Mcf) | | $ | 1.31 | | | $ | 7.01 | | | $ | 1.59 | | | $ | 1.45 | |
| 2018 | | | | | | | | |
| Oil ($/Bbl) | | $ | 56.30 | | | $ | 64.32 | | | $ | 67.69 | | | $ | 60.64 | |
| NGL ($/Bbl) | | $ | 27.64 | | | $ | — | | | $ | 23.20 | | | $ | 26.25 | |
| Gas ($/Mcf) | | $ | 1.59 | | | $ | 6.43 | | | $ | 1.58 | | | $ | 1.62 | |
| | | | | |
128120 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
NET PRODUCTIVE AND DRY— EXPLORATORY AND DEVELOPMENT WELLS COMPLETED
The following table sets forth, for each year in the three-year period ended December 31, 2020,2022, Occidental’s net productive and dry exploratory and development wells completed:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | United
States | | Latin
America | | Middle East / Africa (a) | | Total |
| 2020 | | | | | | | | |
| Oil | | | | | | | | |
| Exploratory | | 7 | | | — | | | 2 | | | 9 | |
| Development | | 240 | | | — | | | 81 | | | 321 | |
| Gas | | | | | | | | |
| | | | | | | | |
| Exploratory | | — | | | 1 | | | 1 | | | 2 | |
| Development | | 6 | | | — | | | 1 | | | 7 | |
| Dry | | | | | | | | |
| Exploratory | | — | | | — | | | 1 | | | 1 | |
| Development | | — | | | — | | | — | | | — | |
| | | | | | | | |
| 2019 | | | | | | | | |
| Oil | | | | | | | | |
| Exploratory | | 22 | | | — | | | 7 | | | 29 | |
| Development | | 422 | | | 68 | | | 129 | | | 619 | |
| Gas | | | | | | | | |
| Exploratory | | — | | | 2 | | | 5 | | | 7 | |
| Development | | 2 | | | — | | | 2 | | | 4 | |
| Dry | | | | | | | | |
| Exploratory | | 1 | | | 3 | | | 6 | | | 10 | |
| Development | | — | | | 1 | | | — | | | 1 | |
| 2018 | | | | | | | | |
| Oil | | | | | | | | |
| Exploratory | | 11 | | | 2 | | | 5 | | | 18 | |
| Development | | 267 | | | 54 | | | 138 | | | 459 | |
| Gas | | | | | | | | |
| | | | | | | | |
| Development | | 3 | | | — | | | 1 | | | 4 | |
| Dry | | | | | | | | |
| Exploratory | | — | | | 2 | | | 3 | | | 5 | |
| | | | | | | | |
(a)Prior period wells completed for Algeria have been reclassified and included to reflect the Algeria operations as continuing operations. | | | | | | | | | | | | | | | | | | | | |
| | United States | | International | | Total |
| 2022 | | | | | | |
| Oil | | | | | | |
| Exploratory | | 9 | | | 10 | | | 19 | |
| Development | | 265 | | | 32 | | | 297 | |
| Gas | | | | | | |
| | | | | | |
| Exploratory | | — | | | — | | | — | |
| Development | | 3 | | | 2 | | | 5 | |
| Dry | | | | | | |
| Exploratory | | — | | | 5 | | | 5 | |
| Development | | 1 | | | — | | | 1 | |
| | | | | | |
| 2021 | | | | | | |
| Oil | | | | | | |
| Exploratory | | 6 | | | 4 | | | 10 | |
| Development | | 292 | | | 42 | | | 334 | |
| Gas | | | | | | |
| Exploratory | | — | | | 1 | | | 1 | |
| Development | | 4 | | | — | | | 4 | |
| Dry | | | | | | |
| Exploratory | | 4 | | | 2 | | | 6 | |
| Development | | 1 | | | — | | | 1 | |
| 2020 | | | | | | |
| Oil | | | | | | |
| Exploratory | | 7 | | | 2 | | | 9 | |
| Development | | 240 | | | 81 | | | 321 | |
| Gas | | | | | | |
| Exploratory | | — | | | 2 | | | 2 | |
| Development | | 6 | | | 1 | | | 7 | |
| Dry | | | | | | |
| Exploratory | | — | | | 1 | | | 1 | |
| Development | | — | | | — | | | — | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | |
OXY 20202022 FORM 10-K | 129121 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
PRODUCTIVE OIL AND GAS WELLS
The following table sets forth, as of December 31, 2020,2022, Occidental’s productive oil and gas wells (both producing and capable of production):
| Wells at December 31, 2020 (a) | | United
States | | Latin
America | | Middle East / Africa | | Total | |
| | | United States | | | International | | Total |
Oil | Oil | | Oil | | | |
Gross (b) | Gross (b) | | 20,189 | | | (1,271) | | | 1 | | | — | | | 2,817 | | | — | | | 23,007 | | | (1,271) | | Gross (b) | | 17,944 | | | (1,009) | | | | 2,894 | | | — | | | 20,838 | | | (1,009) | |
Net (c) | Net (c) | | 16,549 | | | (1,169) | | | 1 | | | — | | | 1,238 | | | (35) | | | 17,788 | | | (1,204) | | Net (c) | | 15,437 | | | (861) | | | | 1,392 | | | — | | | 16,829 | | | (861) | |
Gas | Gas | | Gas | | | | | |
Gross (b) | Gross (b) | | 4,441 | | | (2,166) | | | 36 | | | — | | | 127 | | | (2) | | | 4,604 | | | (2,168) | | Gross (b) | | 2,656 | | | (1,453) | | | | 162 | | | (2) | | | 2,818 | | | (1,455) | |
Net (c) | Net (c) | | 3,198 | | | (1,982) | | | 34 | | | — | | | 60 | | | (4) | | | 3,292 | | | (1,986) | | Net (c) | | 2,229 | | | (1,165) | | | | 96 | | | (2) | | | 2,325 | | | (1,167) | |
(a)The numbers in parentheses indicate the number of wells with multiple completions.
(b)The total number of wells in which interests are owned.
(c)The sum of fractional interests.
PARTICIPATION IN WELLS BEING DRILLED OR PENDING COMPLETION
The following table sets forth, as of December 31, 2020,2022, Occidental’s participation in exploratory and development wells being drilled:
| | | United
States | | Latin
America | | Middle East / Africa | | Total | | United States | | | International | | Total |
| Exploratory and development wells being drilled | Exploratory and development wells being drilled | | | | | | | | | Exploratory and development wells being drilled | | | | | | | |
| Gross | Gross | | 46 | | | — | | | 17 | | | 63 | | Gross | | 27 | | | | 16 | | | 43 | |
| Net | Net | | 33 | | | — | | | 11 | | | 44 | | Net | | 22 | | | | 12 | | | 34 | |
Exploratory and development wells pending completion (a) | Exploratory and development wells pending completion (a) | | | | | | | | | Exploratory and development wells pending completion (a) | | | | | | | |
| Gross | Gross | | 187 | | | — | | | 2 | | | 189 | | Gross | | 107 | | | | 1 | | | 108 | |
| Net | Net | | 150 | | | — | | | 1 | | | 151 | | Net | | 79 | | | | 1 | | | 80 | |
(a)Wells suspended or waiting on completion include exploration and development wells where drilling has occurred, but the wells are awaiting the completion of hydraulic fracturing or other completion activities or the resumption of drilling in the future. There were 5742 MMboe of PUDsPUD reserves primarily assigned to U.S. onshore development wells suspended or waiting on completion atas of December 31, 2020.2022. Occidental expects to convert all of these PUDsPUD reserves to developed status within five years of their initial disclosure.
AtAs of December 31, 2020,2022, Occidental was participating in 104135 and 3337 gross pressure-maintenance projects in the United States and Middle East/Africa,Internationally, respectively. In the United States, these projects primarily consisted of waterfloods with someand CO2 floods, and in the Middle East/East and North Africa, these projects consisted mostly of waterfloods.
| | | | | |
130122 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
OIL AND GAS ACREAGE
The following table sets forth, as of December 31, 2020,2022, Occidental’s holdings of developed and undeveloped oil and gas acreage:
| | thousands | thousands | | United
States | | Latin
America | | Middle East / Africa | | Total | thousands | | United States | | | International | | Total |
Developed (a) | Developed (a) | | | | | | | Developed (a) | | | | | | | |
Gross (b) | Gross (b) | | 6,449 | | | 67 | | | 1,068 | | | 7,584 | | Gross (b) | | 6,190 | | | | 1,130 | | | 7,320 | |
Net (c) | Net (c) | | 3,960 | | | 56 | | | 320 | | | 4,336 | | Net (c) | | 3,948 | | | | 393 | | | 4,341 | |
Undeveloped (d) | Undeveloped (d) | | | Undeveloped (d) | | | | |
Gross (b) | Gross (b) | | 1,451 | | | — | | | 7,972 | | | 9,423 | | Gross (b) | | 1,437 | | | | 8,422 | | | 9,859 | |
Net (c) | Net (c) | | 970 | | | — | | | 6,553 | | | 7,523 | | Net (c) | | 1,016 | | | | 6,677 | | | 7,693 | |
Fee Mineral Ownership (e) | Fee Mineral Ownership (e) | | Fee Mineral Ownership (e) | | | |
Gross (b) | Gross (b) | | 8,069 | | | — | | | — | | | 8,069 | | Gross (b) | | 8,040 | | | | — | | | 8,040 | |
Net (c) | Net (c) | | 4,559 | | | — | | | — | | | 4,559 | | Net (c) | | 4,567 | | | | — | | | 4,567 | |
(a)Acres spaced or assigned to productive wells.
(b)Total acres in which interests are held.
(c)Sum of the fractional interests owned based on working interests, or interests under PSCs and other economic arrangements.
(d)Acres on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and gas, regardless of whether the acreage contains proved reserves.
(e)Occidental’s fee mineral acreage is primarily undeveloped.
Occidental’s investment in developed and undeveloped acreage comprises numerous concessions, blocks and leases. Work programs are designed to ensure that the exploration potential of any property is fully evaluated before the contractual expiration date. In some instances, Occidental may elect to relinquish acreage in advance of the contractual expiration date if the evaluation process is complete and there is not a business basis for extension. In cases where additional time may be required to fully evaluate acreage, Occidental has generally been successful in obtaining extensions. Scheduled lease and concession expirations for undeveloped acreage over the next three years are not expected to have a material adverse impact on Occidental.
| | | | | |
OXY 20202022 FORM 10-K | 131123 |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
OIL, NGL AND NATURAL GAS SALES VOLUMES PER DAY
The following tables set forth the sales volumes from ongoing operations of oil, NGL and natural gas per day for each of the three years in the period ended December 31, 2020.2022. The differences between the sales and production volumes per day are negligible and are generally due to the timing of shipments at Occidental’s international locations where product is loaded onto tankers. Natural gas volumes have been converted to Boe based on energy content of six Mcf of gas to one barrel of oil.
| | Sales per Day from Ongoing Operations (Mboe/d) | Sales per Day from Ongoing Operations (Mboe/d) | | 2020 | | 2019 | | 2018 | Sales per Day from Ongoing Operations (Mboe/d) | | 2022 | | 2021 | | 2020 |
| United States | United States | | | | | | | United States | | | | | | |
| Permian Resources | | 435 | | | 355 | | | 214 | | |
| Permian EOR | | 140 | | | 154 | | | 154 | | |
| DJ Basin | | 293 | | | 120 | | | — | | |
| Permian | | Permian | | 513 | | | 487 | | | 575 | |
| Rockies & Other Domestic | | Rockies & Other Domestic | | 277 | | | 302 | | | 332 | |
| Gulf of Mexico | Gulf of Mexico | | 130 | | | 58 | | | — | | Gulf of Mexico | | 147 | | | 144 | | | 130 | |
| Other Domestic | | 39 | | | 27 | | | 4 | | |
| Total | Total | | 1,037 | | | 714 | | | 372 | | Total | | 937 | | | 933 | | | 1,037 | |
| Latin America | | 33 | | | 34 | | | 32 | | |
| Middle East / Africa | | |
Algeria (a) | | 45 | | | 24 | | | — | | |
| International | | International | |
| Algeria and Other International | | Algeria and Other International | | 48 | | | 43 | | | 46 | |
| Al Hosn Gas | Al Hosn Gas | | 78 | | | 82 | | | 73 | | Al Hosn Gas | | 73 | | | 76 | | | 78 | |
| Dolphin | Dolphin | | 45 | | | 42 | | | 40 | | Dolphin | | 37 | | | 40 | | | 45 | |
| Oman | Oman | | 85 | | | 89 | | | 86 | | Oman | | 64 | | | 74 | | | 85 | |
| Total | Total | | 253 | | | 237 | | | 199 | | Total | | 222 | | | 233 | | | 254 | |
| Total Sales from Ongoing Operations (Mboe/d) | Total Sales from Ongoing Operations (Mboe/d) | | 1,323 | | | 985 | | | 603 | | Total Sales from Ongoing Operations (Mboe/d) | | 1,159 | | | 1,166 | | | 1,291 | |
| Operations exited or exiting | Operations exited or exiting | | 28 | | | 44 | | | 55 | | Operations exited or exiting | | — | | | 18 | | | 60 | |
| Total Sales (Mboe/d) | Total Sales (Mboe/d) | | 1,351 | | | 1,029 | | | 658 | | Total Sales (Mboe/d) | | 1,159 | | | 1,184 | | | 1,351 | |
(a)
Prior period sales volumes for Algeria have been reclassified and included to reflect the Algeria operations as ongoing operations.
| | | | | |
132124 | OXY 20202022 FORM 10-K |
| | | | | |
| Supplemental Oil and Gas Information (Unaudited) |
| | Sales per Day by Products from Ongoing Operations (Mboe/d) | | 2020 | | 2019 | | 2018 | |
| Sales per Day by Products from Ongoing Operations | | Sales per Day by Products from Ongoing Operations | | 2022 | | 2021 | | 2020 |
| United States | United States | | | | | | | United States | | | | | | |
| Oil (Mbbl) | Oil (Mbbl) | | Oil (Mbbl) | |
| Permian Resources | | 237 | | | 207 | | | 132 | | |
| Permian EOR | | 106 | | | 117 | | | 117 | | |
| DJ Basin | | 96 | | | 46 | | | — | | |
| Permian | | Permian | | 303 | | | 286 | | | 343 | |
| Rockies & Other Domestic | | Rockies & Other Domestic | | 82 | | | 93 | | | 109 | |
| Gulf of Mexico | Gulf of Mexico | | 109 | | | 48 | | | — | | Gulf of Mexico | | 122 | | | 119 | | | 109 | |
| Other Domestic | | 13 | | | 7 | | | 1 | | |
| Total | Total | | 561 | | | 425 | | | 250 | | Total | | 507 | | | 498 | | | 561 | |
| NGL (Mbbl) | NGL (Mbbl) | | NGL (Mbbl) | |
| Permian Resources | | 101 | | | 74 | | | 38 | | |
| Permian EOR | | 28 | | | 30 | | | 29 | | |
| DJ Basin | | 79 | | | 28 | | | — | | |
| Permian | | Permian | | 119 | | | 110 | | | 129 | |
| Rockies & Other Domestic | | Rockies & Other Domestic | | 97 | | | 97 | | | 83 | |
| Gulf of Mexico | Gulf of Mexico | | 9 | | | 4 | | | — | | Gulf of Mexico | | 11 | | | 10 | | | 9 | |
| Other Domestic | | 4 | | | 4 | | | — | | |
| Total | Total | | 221 | | | 140 | | | 67 | | Total | | 227 | | | 217 | | | 221 | |
| Natural gas (MMcf) | Natural gas (MMcf) | | Natural gas (MMcf) | |
| Permian Resources | | 584 | | | 442 | | | 261 | | |
| Permian EOR | | 36 | | | 44 | | | 50 | | |
| DJ Basin | | 713 | | | 275 | | | — | | |
| Permian | | Permian | | 545 | | | 548 | | | 620 | |
| Rockies & Other Domestic | | Rockies & Other Domestic | | 590 | | | 676 | | | 838 | |
| Gulf of Mexico | Gulf of Mexico | | 71 | | | 34 | | | — | | Gulf of Mexico | | 81 | | | 84 | | | 71 | |
| Other Domestic | | 125 | | | 98 | | | 16 | | |
| Total | Total | | 1,529 | | | 893 | | | 327 | | Total | | 1,216 | | | 1,308 | | | 1,529 | |
| Latin America | | |
| International | | International | |
| Oil (Mbbl) | Oil (Mbbl) | | 32 | | | 33 | | | 31 | | Oil (Mbbl) | |
| Natural gas (MMcf) | | 6 | | | 7 | | | 6 | | |
| Middle East / Africa | | |
| Oil (Mbbl) | | |
| Algeria | | 42 | | | 22 | | | — | | |
| Algeria and Other International | | Algeria and Other International | | 42 | | | 39 | | | 42 | |
| Al Hosn Gas | Al Hosn Gas | | 14 | | | 14 | | | 13 | | Al Hosn Gas | | 12 | | | 13 | | | 14 | |
| Dolphin | Dolphin | | 7 | | | 7 | | | 7 | | Dolphin | | 6 | | | 7 | | | 7 | |
| Oman | Oman | | 65 | | | 66 | | | 63 | | Oman | | 53 | | | 61 | | | 65 | |
| Total | Total | | 128 | | | 109 | | | 83 | | Total | | 113 | | | 120 | | | 128 | |
| NGL (Mbbl) | NGL (Mbbl) | | NGL (Mbbl) | |
| Algeria | | 3 | | | 2 | | | — | | |
| Algeria and Other International | | Algeria and Other International | | 4 | | | 3 | | | 3 | |
| Al Hosn Gas | Al Hosn Gas | | 25 | | | 26 | | | 23 | | Al Hosn Gas | | 23 | | | 23 | | | 25 | |
| Dolphin | Dolphin | | 9 | | | 8 | | | 8 | | Dolphin | | 7 | | | 8 | | | 9 | |
| Total | Total | | 37 | | | 36 | | | 31 | | Total | | 34 | | | 34 | | | 37 | |
| Natural gas (MMcf) | Natural gas (MMcf) | | Natural gas (MMcf) | |
| Algeria and Other International | | Algeria and Other International | | 12 | | | 6 | | | 6 | |
| Al Hosn Gas | Al Hosn Gas | | 238 | | | 251 | | | 220 | | Al Hosn Gas | | 227 | | | 234 | | | 238 | |
| Dolphin | Dolphin | | 171 | | | 161 | | | 152 | | Dolphin | | 142 | | | 151 | | | 171 | |
| Oman | Oman | | 120 | | | 138 | | | 139 | | Oman | | 69 | | | 80 | | | 120 | |
| Total | Total | | 529 | | | 550 | | | 511 | | Total | | 450 | | | 471 | | | 535 | |
| Total Sales from Ongoing Operations (Mboe/d) | Total Sales from Ongoing Operations (Mboe/d) | | 1,323 | | | 985 | | | 603 | | Total Sales from Ongoing Operations (Mboe/d) | | 1,159 | | | 1,166 | | | 1,291 | |
| | | | | |
OXY 20202022 FORM 10-K | 133125 |
| | | | | |
| Schedule II – Valuation and Qualifying Accounts | Occidental Petroleum Corporation
and Subsidiaries |
| | | | | Additions | | | | | | | | | Additions | | | | | |
| millions | millions | | Balance at Beginning of Period | | Charged to
Costs and
Expenses | | Charged to
Other
Accounts | | Deductions (a) | | Balance at
End of
Period | | millions | | Balance at Beginning of Period | | Charged to
Costs and
Expenses | | Charged to
Other
Accounts | | Deductions (a) | | Balance at
End of
Period | |
| 2020 | | | | | | | | | | | |
| Allowance for doubtful accounts | | $ | 788 | | | $ | 37 | | | $ | (3) | | | $ | 0 | | | $ | 822 | | (b) | |
| Environmental, litigation and other reserves | | $ | 2,411 | | | $ | 115 | | | $ | 43 | | | $ | (140) | | | $ | 2,429 | | (c) | |
| | 2019 | | | |
| 2022 | | 2022 | | | | | | | | | | | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | $ | 668 | | | $ | 126 | | | $ | (6) | | | $ | 0 | | | $ | 788 | | (b) | Allowance for doubtful accounts | | $ | 867 | | | $ | 37 | | | $ | — | | | $ | — | | | $ | 904 | | (b) |
| Environmental, litigation, tax and other reserves | Environmental, litigation, tax and other reserves | | $ | 994 | | | $ | 182 | | | $ | 1,408 | | | $ | (173) | | | $ | 2,411 | | (c) | Environmental, litigation, tax and other reserves | | $ | 3,164 | | | $ | 714 | | | $ | 138 | | | $ | (304) | | | $ | 3,712 | | (c) |
| | 2018 | | | |
| 2021 | | 2021 | | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | | $ | 594 | | | $ | 77 | | | $ | (3) | | | $ | 0 | | | $ | 668 | | (b) | Allowance for doubtful accounts | | $ | 822 | | | $ | 56 | | | $ | (11) | | | $ | — | | | $ | 867 | | (b) |
| Environmental, litigation, tax and other reserves | Environmental, litigation, tax and other reserves | | $ | 935 | | | $ | 140 | | | $ | 85 | | | $ | (166) | | | $ | 994 | | (c) | Environmental, litigation, tax and other reserves | | $ | 2,429 | | | $ | 900 | | | $ | 94 | | | $ | (259) | | | $ | 3,164 | | (c) |
| | 2020 | | 2020 | | |
| Allowance for doubtful accounts | | Allowance for doubtful accounts | | $ | 788 | | | $ | 37 | | | $ | (3) | | | $ | — | | | $ | 822 | | (b) |
| Environmental, litigation, tax and other reserves | | Environmental, litigation, tax and other reserves | | $ | 2,411 | | | $ | 115 | | | $ | 43 | | | $ | (140) | | | $ | 2,429 | | (c) |
(a)Primarily represents payments.
(b)Of these amounts, $44 million, $46 million and $42 million $22 millionin 2022, 2021, and $24 million in 2020, 2019, and 2018, respectively, arewere classified as current.
(c)Of these amounts, $266 million, $790 million and $149 million $188 millionin 2022, 2021, and $146 million in 2020, 2019, and 2018, respectively, arewere classified as current.
Note: The amounts presented represent continuing operations.
| | | | | |
134126 | OXY 20202022 FORM 10-K |
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
Occidental had no changes in, and no disagreements with, Occidental’s accountants on accounting and financial disclosure.
ITEM 9A. CONTROLS AND PROCEDURES
| | |
| MANAGEMENT’S ANNUAL ASSESSMENT OF AND REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING |
The management of Occidental Petroleum Corporation and its subsidiaries (Occidental) is responsible for establishing and maintaining adequate internal control over financial reporting. Occidental’s system of internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statementsConsolidated Financial Statements for external purposes in accordance with generally accepted accounting principles.GAAP. Occidental’s internal control over financial reporting includes those policies and procedures that: (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and divestitures of Occidental’s assets; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principlesGAAP and that Occidental’s receipts and expenditures are being made only in accordance with authorizations of Occidental’s management and directors; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of Occidental’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management has assessed the effectiveness of Occidental’s internal control system as of December 31, 2020,2022, based on the criteria for effective internal control over financial reporting described in Internal Control - Integrated Framework issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this assessment, management believes that, as of December 31, 2020,2022, Occidental’s system of internal control over financial reporting is effective.
Occidental’s independent auditors, KPMG LLP, have issued an audit report on Occidental’s internal control over financial reporting.
| | |
| DISCLOSURE CONTROLS AND PROCEDURES |
Occidental’s President and Chief Executive Officer and its Senior Vice President and Chief Financial Officer supervised and participated in Occidental’s evaluation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based upon that evaluation, Occidental’s President and Chief Executive Officer and Senior Vice President and Chief Financial Officer concluded that Occidental’s disclosure controls and procedures were effective as of December 31, 2020.
There has been no change in Occidental’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the fourth quarter of 2020 that has materially affected, or is reasonably likely to materially affect, Occidental’s internal control over financial reporting. The Report of Independent Registered Public Accounting Firm on Internal Control over Financial Reporting is set forth in Item 8.2022.
ITEM 9B. OTHER INFORMATION
None.
ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
None.
| | | | | |
OXY 20202022 FORM 10-K | 135127 |
Part III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Occidental has adopted aOccidental’s Code of Business Conduct (Code). The Code applies to the President and Chief Executive Officer, Senior Vice President and Chief Financial Officer, Vice President, Chief Accounting Officer and Controller and persons performing similar functions (Key Personnel).functions. The Code of Business Conduct also applies to Occidental’s directors, employees and the employees of entities which it controls. The Code of Business Conduct is posted aton our website, www.oxy.com. Occidental will satisfy any disclosure requirement under Item 5.05 of Form 8-K regarding an amendment to, or waiver from, any provision of the Code with respect to its Key Personnel or directorsof Business Conduct by disclosing the nature of that amendment or waiver on its website within four business days following the date of the amendment or waiver.
The list of Occidental’s executive officers and related information under Information About Our Executive Officers set forth in Part I of this 10-K is incorporated by reference herein. The information required by this Item 10 is incorporated herein by reference from Occidental’s definitive Proxy Statement to be filed with the SEC pursuant to Regulation 14A within 120 days of December 31, 2020.2022.
ITEM 11. EXECUTIVE COMPENSATION
The information under the caption “Compensation Discussion and Analysis - Compensation Committee Report” shall not be deemed to be “soliciting material,” or to be “filed” with the SEC, or subject to Regulation 14A or 14C under the Exchange Act or to 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. The information required by this Item 11 is incorporated herein by reference from Occidental’s definitive Proxy Statement to be filed with the SEC pursuant to Regulation 14A within 120 days of December 31, 2020.2022.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
| | |
| SECURITIES AUTHORIZED FOR ISSUANCE UNDER EQUITY COMPENSATION PLANS |
All of Occidental’s stock-based compensation plans for its employees and non-employee directors have been approved by the stockholders. The aggregate number of shares of Occidental common stock authorized for issuance under such plans is approximately 133 million, of which approximately 11.616.1 million had been reserved for issuance through December 31, 2020.2022. The following is a summary of the securities available for issuance under such plans:
| | | | | | | | | | | | | | | | | | | | | | | |
| a) | Number of securities to be issued upon exercise of outstanding options, warrants and rights | | b) | Weighted-average exercise price of outstanding options, warrants and rights | | c) | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) |
12,543,99516,053,787(1)
| | 46.3438.04(2)
| | 88,324,98256,980,559 (3)
|
(1)IncludedIncludes shares reserved to be issued pursuant to restricted stock units, stock options (Options)RSUs, Options and performance-based awards. Shares for performance-based awards are included assuming maximum payout, but may be paid out at lesser amounts, or not at all, according to achievement of performance goals.
(2)Price applies only to the Options included in column (a). Exercise price is not applicable to the other awards included in column (a), nor warrants not issued under equity compensation plans.
(3)A plan provision requires each share covered by an award (other than stock appreciation rights (SARs) and Options) to be counted as if three shares were issued in determining the number of shares that are available for future awards. Accordingly, the number of shares available for future awards may be less than the amount shown depending on the type of award granted. Additionally, under the plan, the amount shown may increase, depending on the award type, by the number of shares currently unvested or forfeitable, or three times that number as applicable, that are forfeited or canceled, or correspond to the portion of any stock-based awards settled in cash.
The information required by this Item 12 is incorporated herein by reference from Occidental’s definitive Proxy Statement to be filed with the SEC pursuant to Regulation 14A within 120 days of December 31, 2020.2022.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
The information required by this Item 13 is incorporated herein by reference from Occidental’s definitive Proxy Statement to be filed with the SEC pursuant to Regulation 14A within 120 days of December 31, 2020.
2022. | | | | | |
136128 | OXY 20202022 FORM 10-K |
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Our independent registered public accounting firm is KPMG LLP, Houston, TX, Auditor Firm ID: 185.
The information about our principal accountant, KPMG LLP, Houston, Texas (185) required by this Item 14 is incorporated herein by reference from Occidental’s definitive Proxy Statement to be filed with the SEC pursuant to Regulation 14A within 120 days of December 31, 2020.2022.
Part IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
The agreements included as exhibits to this report are included to provide information about their terms and not to provide any other factual or disclosure information about Occidental or the other parties to the agreements. The agreements contain representations and warranties by each of the parties to the applicable agreement that were made solely for the benefit of the other agreement parties and:
■Should not be treated as categorical statements of fact, but rather as a way of allocating the risk among the parties if those statements prove to be inaccurate;
■Have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement, which disclosures are not necessarily reflected in the agreement;
■May apply standards of materiality in a way that is different from the way investors may view materiality; and
■Were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement and are subject to more recent developments.
(a) (1) and (2). Financial Statements and Financial Statement Schedule
Reference is made to Item 8 of the Table of Contents of this report,the Form 10-K, where these documents are listed.
(a) (3). Exhibits
| | | | | |
| 3.(i) | Restated Certificate of Incorporation of Occidental, dated November 12, 1999, and Certificates of Amendment thereto dated May 5, 2006, May 1, 2009, May 2, 2014 and June 3, 2020 (filed as Exhibit 4.1 to the Registration Statement on Form S-8 of Occidental filed on June 17, 2020, File No. 333-239236). |
| 3.(i)(a) | |
| 3.(ii) | |
| 3.(ii)(a) | |
| 3.(ii)(b) | |
| 4.1 | |
4.2 | |
4.34.2 | |
| 4.3 | |
| 4.4 | |
| 4.5 | |
| Other instruments defining the rights of holders of other long-term debt of Occidental and its subsidiaries are not being filed since the total amount of securities authorized under each of such instruments does not exceed 10% of the total assets of Occidental and its subsidiaries on a consolidated basis. Occidental agrees to furnish a copy of any such instrument to the Commission upon request. |
All of the Exhibitsexhibits numbered 10.1 to 10.3310.26 are management contracts and compensatory plans required to be identified specifically as responsive to Item 601(b)(10)(iii)(A) of Regulation S-K pursuant to Item 15(b) of Form 10-K. |
| | | | | |
| 10.5 | |
10.6 | |
10.7 | |
10.810.6 | Form of Indemnification Agreement between Occidental and each of its directors and certain executive officers (filed as Exhibit B to the Proxy Statement of Occidental for its May 21, 1987, Annual Meeting of Stockholders, File No. 1-9210). |
10.910.7 | |
10.1010.8 | |
10.11 | |
10.12 | |
10.13 | |
10.14 | |
10.1510.9 | |
10.1610.10 | |
10.17 | |
10.18 | |
10.19 | |
10.20 | |
10.21 | |
10.2210.11 | |
10.23 | |
10.2410.12 | |
10.2510.13 | |
10.2610.14 | |
10.2710.15 | |
10.2810.16 | |
10.2910.17 | |
10.3010.18 | |
| | | | | |
10.3110.19 | |
10.3210.20 | |
10.3310.21 | |
10.3410.22 | |
10.3510.23 | |
10.3610.24 | |
10.3710.25 | |
| | | | | |
| 10.26 | |
| 10.27 | |
| 10.28 | Second Amended and Restated Credit Agreement, dated as of December 10, 2021, by and among Occidental Petroleum Corporation, the banks party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent (filed as Exhibit 10.1 to the Current Report on Form 8-K of Occidental filed on December 13, 2021, File No. 1-9210). |
| 21 | |
| 23.1 | |
| 23.2 | |
| 31.1 | |
| 31.2 | |
| 32.1 | |
| 99.1 | |
| 101.INS | Inline XBRL Instance Document. |
| 101.SCH | Inline XBRL Taxonomy Extension Schema Document. |
| 101.CAL | Inline XBRL Taxonomy Extension Calculation Linkbase Document. |
| 101.LAB | Inline XBRL Taxonomy Extension Label Linkbase Document. |
| 101.PRE | Inline XBRL Taxonomy Extension Presentation Linkbase Document. |
| 101.DEF | Inline XBRL Taxonomy Extension Definition Linkbase Document. |
| 104 | Cover Page Interactive Data File - The cover page from Occidental Petroleum Corporation’s Annual Report on Form 10-K for the year ended December 31, 20202022 is formatted in Inline XBRL (included as Exhibit 101). |
| |
ITEM 16. FORM 10-K SUMMARY
Not applicable.None.
| | | | | |
OXY 20202022 FORM 10-K | 139131 |
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| | | | | | | | |
| | OCCIDENTAL PETROLEUM CORPORATION |
| | | |
| By: | /s/ Vicki Hollub |
| | | Vicki Hollub |
| | | President and Chief Executive Officer |
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
| | | | | | | | | | | | | | |
| | | Title | Date |
| | | | |
| /s/ Vicki Hollub | | President, Chief Executive Officer | February 26, 202127, 2023 |
| Vicki Hollub | | and Director |
| | | | |
| /s/ Robert L. Peterson | | Senior Vice President and | February 26, 202127, 2023 |
| Robert L. Peterson | | Chief Financial Officer |
| | | | |
| /s/ Christopher O. Champion | | Vice President, Chief Accounting Officer | February 26, 202127, 2023 |
| Christopher O. Champion | | and Controller |
| | | | |
| /s/ Stephen I. ChazenVicky A. Bailey | | Chairman of the Board of DirectorsDirector | February 26, 202127, 2023 |
| Stephen I. ChazenVicky A. Bailey | |
| | | | |
| /s/ Andrew F. Gould | | Director | February 26, 202127, 2023 |
| Andrew F. Gould | |
| | | | |
| /s/ Carlos M. Gutierrez | | Director | February 26, 202127, 2023 |
| Carlos M. Gutierrez | |
| | | | |
| /s/ Gaoxiang Hu | | Director | February 26, 2021 |
| Gaoxiang Hu | |
| | | | |
| /s/ William R. Klesse | | Director | February 26, 202127, 2023 |
| William R. Klesse | |
| | | | |
| /s/ Andrew N. Langham | | Director | February 26, 2021 |
| Andrew N. Langham | |
| | | | |
| /s/ Jack B. Moore | | Director | February 26, 202127, 2023 |
| Jack B. Moore | |
| | | | |
| /s/ Margarita Paláu-HernándezClaire O’Neill | | Director | February 26, 202127, 2023 |
| Margarita Paláu-HernándezClaire O’Neill | |
| | | | |
| /s/ Avedick B. Poladian | | Director | February 26, 202127, 2023 |
| Avedick B. Poladian | |
| | | | |
| /s/ Robert M. Shearer | | Director | February 26, 202127, 2023 |
| Robert M. Shearer | |
| | | | | |
140132 | OXY 20202022 FORM 10-K |
