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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 20-F

(Mark One)

 

REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934

OR

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2021

OR

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

  

For the transition period from              to             

OR

 

SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

  

Date of event requiring this shell company report

Commission file number: 1-10888

TotalEnergies SE

(Exact Name of Registrant as Specified in Its Charter)

N/A

(Translation of Registrant's name into English)

Republic of France

(Jurisdiction of Incorporation or Organization)

2, place Jean Millier

La Défv

fense 6

92400 Courbevoie

France

(Address of Principal Executive Offices)

Jean-Pierre Sbraire

Chief Financial Officer

TotalEnergies SE

2, place Jean Millier

La Défense 6

92400 Courbevoie

France

Tel: +33 (0)1 47 44 45 46

Fax: +33 (0)1 47 44 49 44

(Name, Telephone, Email and/or Facsimile Number and Address of Company Contact Person)

Securities registered or to be registered pursuant to Section 12(b) of the Act.

Title of each class

Trading symbol(s)

Name of each exchange on which registered

Shares

New York Stock Exchange*

American Depositary Shares

TTE

New York Stock Exchange

*

Not for trading, but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

Securities registered or to be registered pursuant to Section 12(g) of the Act.

None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act.

None

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report.

2,640,429,329 Shares, par value €2.50 each, as of December 31, 2021

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes      No  

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.    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 or an emerging growth company. See definition of “large accelerated filer”, “accelerated filer”, and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer 

 

Accelerated filer  

 

Non-accelerated filer  

Emerging growth company  

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, 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.

***    The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.

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 which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP  

  

International Financial Reporting Standards as issued by the International
Accounting Standards Board  

  

Other  

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow.    Item 17      Item 18  

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes      No  

TABLE OF CONTENTS

BASIS OF PRESENTATION

i

 

STATEMENTS REGARDING COMPETITIVE POSITION

i

 

ADDITIONAL INFORMATION

i

 

CERTAIN TERMS, ABBREVIATIONS AND CONVERSION TABLE

i

 

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

i

ITEM 1.

IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS

1

 

 

ITEM 2.

OFFER STATISTICS AND EXPECTED TIMETABLE

1

 

 

ITEM 3.

KEY INFORMATION

1

 

 

ITEM 4.

INFORMATION ON THE COMPANY

1

 

 

ITEM 4A.

UNRESOLVED STAFF COMMENTS

2

 

 

ITEM 5.

OPERATING AND FINANCIAL REVIEW AND PROSPECTS

2

 

 

ITEM 6.

DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES

20

 

 

ITEM 7.

MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS

20

 

 

ITEM 8.

FINANCIAL INFORMATION

21

 

 

ITEM 9.

THE OFFER AND LISTING

21

 

 

ITEM 10.

ADDITIONAL INFORMATION

22

 

 

ITEM 11.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

26

 

 

ITEM 12.

DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES

27

 

 

ITEM 13.

DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES

27

 

 

ITEM 14.

MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS

27

 

 

ITEM 15.

CONTROLS AND PROCEDURES

27

 

 

ITEM 16A.

AUDIT COMMITTEE FINANCIAL EXPERT

28

 

 

ITEM 16B.

CODE OF ETHICS

28

 

 

ITEM 16C.

PRINCIPAL ACCOUNTANT FEES AND SERVICES

28

 

 

ITEM 16D.

EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES

28

 

 

ITEM 16E.

PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS

29

 

 

ITEM 16F.

CHANGE IN REGISTRANT'S CERTIFYING ACCOUNTANT

29

 

 

ITEM 16G.

CORPORATE GOVERNANCE

29

 

 

ITEM 16H.

MINE SAFETY DISCLOSURE

32

 

 

ITEM 17.

FINANCIAL STATEMENTS

32

 

 

ITEM 18.

FINANCIAL STATEMENTS

32

 

 

ITEM 19.

EXHIBITS

33

BASIS OF PRESENTATION

References in this annual report on Form 20-F (this “Annual Report”) to pages and sections of the “Universal Registration Document 2021”  are references only to those pages and sections of TotalEnergies’ Universal Registration Document for the year ended December 31, 2021 attached in Exhibit 15.1 to this Form 20-F and forming a part hereof. Other than as expressly provided herein, the Universal Registration Document 2021 is not incorporated herein by reference.

TotalEnergies' Consolidated Financial Statements on pages F-9 to F-13 are prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and IFRS as adopted by the European Union (EU) as of December 31, 2021.

In addition, this Annual Report and the Universal Registration Document 2021 contain certain measures that are not defined by generally accepted accounting principles (GAAP) such as IFRS. Our management uses these financial measures, along with the most directly comparable GAAP financial measures, in evaluating our operating performance. We believe that presentation of this information, along with comparable GAAP measures, is useful to investors because it allows investors to understand the primary method used by management to evaluate performance on a meaningful basis. Non-GAAP financial measures should not be considered in isolation from, or as a substitute for, financial information presented in compliance with GAAP. Non-GAAP financial measures as reported by us may not be comparable with similarly titled amounts reported by other companies.

STATEMENTS REGARDING COMPETITIVE POSITION

Unless otherwise indicated, statements made in “Item 4. Information on the Company” referring to TotalEnergies' competitive position are based on TotalEnergies' estimates, and in some cases rely on a range of sources, including investment analysts’ reports, independent market studies and TotalEnergies' internal assessments of market share based on publicly available information about the financial results and performance of market participants.

ADDITIONAL INFORMATION

This Annual Report reports information primarily regarding TotalEnergies' business, operations and financial information relating to the fiscal year ended December 31, 2021. For more recent updates regarding TotalEnergies, you may inspect any reports, statements or other information TotalEnergies files with the United States Securities and Exchange Commission (“SEC”). All of its SEC filings made after December 31, 2001 are available to the public at the SEC website at http://www.sec.gov and from certain commercial document retrieval services. See also “Item 10. - 10.8 Documents on display”.

No material on the TotalEnergies website forms any part of this Annual Report. References in this Annual Report to documents on the TotalEnergies website are included as an aid to the location of such documents and such documents are not incorporated by reference. References to websites and the Sustainability & Climate - Progress Report 2022 contained in this Annual Report (including all exhibits hereto) are provided for reference only; the information contained on the referenced websites or in the Sustainability & Climate - Progress Report 2022 is not incorporated by reference in this Annual Report.

CERTAIN TERMS, ABBREVIATIONS AND CONVERSION TABLE

For the meanings of certain terms used in this document, as well as certain abbreviations and a conversion table, refer to the “Glossary” starting on page 641 of the Universal Registration Document 2021, incorporated herein by reference. The terms “TotalEnergies", "TotalEnergies company" and “Company” as used in this document refer to TotalEnergies SE collectively with all of its direct and indirect consolidated companies located in or outside of France. The term “Corporation” as used in this document exclusively refers to TotalEnergies SE, which is the parent company.

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

TotalEnergies has made certain forward-looking statements (within the meaning of the Private Securities Litigation Reform Act of 1995) in this document and in the documents referred to in, or incorporated by reference into, this Annual Report. This document may contain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, notably with respect to the financial condition, results of operations, business activities and industrial strategy of TotalEnergies. This document may also contain statements regarding the perspectives, objectives, areas of improvement and goals of TotalEnergies, including with respect to climate change and carbon neutrality (net zero emissions). An ambition expresses an outcome desired by TotalEnergies, it being specified that the means to be deployed do not depend solely on TotalEnergies. These forward-looking statements may generally be identified by the use of the future or conditional tense or forward-looking words such as “envisions”, “intends”, “anticipates”, “believes”, “considers”, “plans”, “expects”, “thinks”, “targets”, “aims” or similar terminology. Such forward-looking statements included in this document are based on economic data, estimates and assumptions prepared in a given economic, competitive and regulatory environment and considered to be reasonable by TotalEnergies as of the date of this document.

These forward-looking statements are not historical data and should not be interpreted as assurances that the perspectives, objectives or goals announced will be achieved. They may prove to be inaccurate in the future, and may evolve or be modified with a significant difference between the actual results and those initially estimated, due to the uncertainties notably related to the economic, financial, competitive and regulatory environment, or due to the occurrence of risk factors, such as, notably, the price fluctuations in crude oil and natural gas, the evolution of the demand and price of petroleum products, the changes in production results and reserves estimates, the ability to achieve cost reductions and operating efficiencies without unduly disrupting business operations, changes in laws and regulations including those related to the environment and climate, currency fluctuations, as well as economic and political developments, changes in market conditions, loss of market share and changes in consumer preferences, or pandemics such as the COVID-19 pandemic. Additionally, certain financial information is based on estimates particularly in the assessment of the recoverable value of assets and potential impairments of assets relating thereto.

Except for its ongoing obligations to disclose material information as required by applicable securities laws, TotalEnergies does not have any intention or obligation to update forward-looking statements after the distribution of this document, even if new information, future events or other circumstances have made them incorrect or misleading.

For additional factors, you should read the information set forth under “Item 3. -3.1 Risk Factors”, “Item 4. Information on the Company”, “Item 5. Operating and Financial Review and Prospects” and “Item 11. Quantitative and Qualitative Disclosures about Market Risk”.

Form 20-F 2021   TotalEnergies

   i

ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS

Not applicable.

ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE

Not applicable.

ITEM 3. KEY INFORMATION

3.1    Risk factors

TotalEnergies conducts its business in a constantly changing environment and is exposed to risks that, if they were to occur, could have a material adverse effect on its business, financial condition, reputation, outlook, or the price of financial instruments issued by TotalEnergies SE. Point 3.1 of chapter 3 of the Universal Registration Document 2021 (starting on page 120), incorporated herein by reference, presents the significant risk factors specific to TotalEnergies, to which it believes it is exposed as of the filing date of this Annual Report. However, TotalEnergies may be exposed to other non-specific risks, or of which it may not be aware, or the potential consequences of which may be underestimated, or the materialization of which is not considered, at that date, likely to have a material adverse impact on TotalEnergies, its business, financial condition, reputation or outlook. In particular, TotalEnergies could be exposed to systemic risks, such as unexpected major disruptions (health, such as the COVID-19 pandemic, security, monetary or cyber), leading to large-scale disturbances with global human and economic repercussions.

For additional information on the risks to which TotalEnergies believes it is exposed as of the filing date of this Annual Report, along with its approaches to managing certain of these risks, please refer to “Item 5. Operating and financial review and prospects” and “Item 11. Quantitative and qualitative disclosures about market risk”, as well as points 3.2, 3.3 and 3.6 of chapter 3 (starting on pages 129, 134 and 143, respectively) of the Universal Registration Document 2021, incorporated herein by reference.

ITEM 4. INFORMATION ON THE COMPANY

The following information providing an integrated overview of TotalEnergies from the Universal Registration Document 2021 is incorporated herein by reference:

-

presentation of TotalEnergies and its governance (points 1.1.1 and 1.9 of chapter 1, starting on pages 4 and 40 respectively);

-

its collective ambition and strategy (points 1.2 and 1.3 of chapter 1, starting on page 12);

-

history, employees, integrated business model, industrial assets and geographic presence (points 1.1.2, 1.1.3, and 1.8.1-1.8.4 of chapter 1, starting on pages 8, 10 and 36 respectively);

-

an overview of its climate ambition, sustainability-linked commitments, investment policy, R&D and dialogue with stakeholders (points 1.4, 1.5, 1.6, 1.7 and 1.8.5 of chapter 1, starting on pages 18, 27, 30, 33 and 39 respectively); and

-

organizational structure (point 1.9.3 of chapter 1, starting on page 43).

The following information providing an overview of TotalEnergies' businesses and activities from the Universal Registration Document 2021 is incorporated herein by reference:

-

information concerning TotalEnergies' principal capital expenditures and divestitures (point 1.6 of chapter 1, starting on page 30). See also “Item 5. Operating and financial review and prospects”;

-

business overview for fiscal year 2021 (points 2.1 to 2.5 of chapter 2, starting on page 64); and

-

geographical breakdown of TotalEnergies’ sales, property, plants and equipment, intangible assets and capital expenditures over the past three years (Note 4 to the Consolidated Financial Statements, on page F-30).

The following other information from the Universal Registration Document 2021 is incorporated herein by reference:

-

countries under economic sanctions (point 3.2 of chapter 3, starting on page 129);

-

insurance and risk management (point 3.4 of chapter 3, starting on page 141);

-

non-financial performance and additional reporting information (points 5.1 to 5.11 of chapter 5 and chapter 11, starting on page 272 and 603 respectively); and

-

investor relations (point 6.6 of chapter 6, starting on page 382).

Form 20-F 2021   TotalEnergies

   1

ITEM 4A. UNRESOLVED STAFF COMMENTS

None.

ITEM 5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS

This section is an analysis of the financial performance and of significant trends that may affect TotalEnergies’ future performance and it should be read in conjunction with the Consolidated Financial Statements and the Notes thereto starting on page F-9. The Consolidated Financial Statements and the Notes thereto are prepared in accordance with IFRS as issued by the IASB and IFRS as adopted by the EU.

This section contains forward-looking statements that are subject to risks and uncertainties. For a list of important factors that could cause actual results to differ materially from those expressed in the forward-looking statements, see “Cautionary Statement Concerning Forward-Looking Statements” starting on page ii.

For information on the Russian-Ukrainian conflict and the situation of the Company at March 24, 2022, refer to Item 5. – 5.6 starting on page 17.

5.1    Overview

TotalEnergies’ results are affected by a variety of factors, including changes in crude oil and natural gas prices and refining and marketing margins, all generally expressed in dollars, as well as changes in exchange rates, particularly the value of the euro compared to the dollar. Higher crude oil and natural gas prices generally have a positive effect on the income of TotalEnergies because the Exploration & Production segment’s oil and gas business and the Integrated Gas, Renewables & Power segment’s LNG and downstream gas business are positively impacted by the resulting increase in revenues. Lower crude oil and natural gas prices generally have a corresponding negative effect. The effect of changes in crude oil prices on the activities of TotalEnergies' Refining & Chemicals and Marketing & Services segments (Downstream) depends upon the speed at which the prices of refined petroleum products adjust to reflect such changes. TotalEnergies' results are also significantly affected by the costs of its activities, in particular those related to exploration and production, and by the outcome of its strategic decisions with respect to cost reduction efforts. In addition, TotalEnergies' results are affected by general economic and political conditions and changes in governmental laws and regulations, as well as by the impact of decisions by OPEC+ on production levels. For more information, refer to “Item 3. - 3.1 Risk factors”.

In 2021, TotalEnergies generated cash flow (DACF)1 of $30.7 billion, up $13 billion compared to 2020, and adjusted EBITDA2 of $42.3 billion. TotalEnergies reported adjusted net income3 of $18.1 billion, representing a return on equity of 16.9% and a return on capital employed (ROACE) of nearly 14% for 2021, which demonstrates the quality of its portfolio and operations. IFRS net income was $16 billion (€13.6 billion).

The integrated Gas, Renewables & Power (iGRP) segment reported an adjusted net operating income4 and cash flow (DACF)5 of $6.2 billion and $6.1 billion, respectively. These historic results build on the globally integrated LNG portfolio, leveraging rising oil and gas prices and outperformance in the gas and LNG trading business. The profitable growth strategy in Renewables & Electricity continues with more than 10 GW of gross installed capacity and more than 6 million electricity customers at year-end 2021. At the start of 2022, TotalEnergies secured an additional 2 GW of offshore wind projects with the award of a concession in Scotland, as part of the Scotwind tender.

The Exploration & Production segment benefited from higher oil and gas prices with adjusted net operating income of $10.4 billion and was a strong contributor to the Company’s net cash flow with $12.2 billion. In line with its strategy to invest in low-cost and low-emission projects, TotalEnergies increased its presence in Brazil by entering the Atapu and Sépia giant fields, launched the Lake Albert Resource Development Project in Uganda, while divesting interests in mature assets.

1   DACF = debt adjusted cash flow, is defined as operating cash flow before working capital changes and without financial charges. Operating cash flow before working capital changes is defined as cash flow from operating activities before changes in working capital at replacement cost, excluding the mark-to-market effect of iGRP’s contracts and including capital gain from renewable projects sales (effective first quarter 2020). Operating cash flow before working capital changes provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the inventory effect and replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

2   Adjusted EBITDA (Earnings Before Interest, Tax, Depreciation and Amortization) corresponds to the adjusted earnings before depreciation, depletion and impairment of tangible and intangible assets and mineral interests, income tax expense and cost of net debt, i.e., all operating income and contribution of equity affiliates to net income. The reconciliation of adjusted EBITDA with the consolidated financial statements is set forth under “Reconciliation of net income (TotalEnergies share) to adjusted EBITDA” on page 5.

3   Adjusted net income refers to adjusted net operating income, adjusted for special items, inventory valuation effect and the effect of changes in fair value. See “- 5.3 Business segment reporting” below for further details.

4   Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

5   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charges of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases, excluding the impact of contracts recognized at fair value for the segment and including capital gains on the sale of renewable projects.

TotalEnergies   Form 20-F 2021

   2   

Downstream1 posted solid results with $3.5 billion in adjusted net operating income and cash flow (DACF)2 of $5.5 billion, or more than $3 billion in net cash flow. High margins in petrochemicals and the return to pre-crisis results in the Marketing & Services segment, despite sales volumes still impacted by the COVID-19 pandemic, offset European refining margins that remained low, due to the rise in energy costs.

The Company maintained capital discipline with net investments3 of $13.3 billion, of which 25% was in Renewables & Electricity. TotalEnergies reported net cash flow4 of $15.8 billion for the year, allowing it to continue to reduce its net debt with year-end gearing5 reduced to 15.3%, compared to 21.7% at year-end 2020, and buy back $1.5 billion of shares, in line with the previously announced objective.

In line with the policy announced in February 2021, the Board of Directors will propose at the Shareholders’ Meeting to be held on May 25, 2022, the distribution of a final 2021 dividend of €0.66 per share, equal to the three 2021 interim dividends already declared.

In addition, the Board of Directors defined a return-to-shareholder policy for 2022 combining, on the one hand, an increase in interim dividends of 5% given the structural growth in cash flow generated by the LNG and electricity business, and, on the other hand, buybacks to share the surplus cash flow from high hydrocarbon prices. These share buybacks are expected to be $2 billion for the first half of 2022.

In accordance with the resolution approved by shareholders in May 2021 on TotalEnergies’ ambitions for sustainable development and energy transition toward carbon neutrality, the Board of Directors will report on the progress made in implementing these ambitions at the Shareholders’ Meeting to be held on May 25, 2022. With this in mind, the Board of Directors adopted a ‘Sustainability & Climate - Progress Report 2022’, which will be submitted to a shareholder advisory vote at the Annual Shareholders’ Meeting on May 25, 2022. It was published and presented on March 24, 2022, during a Strategy, Sustainability & Climate investor meeting.

Outlook

The price of oil rose above $90/b for the first time since 2014 at the beginning of 2022. This increase in price is driven by the global demand recovery and OPEC+ discipline in a context of constrained supply, given the low level of investment in hydrocarbons since 2015. It is exacerbated in the short term by low oil inventories. Prices could therefore remain at high levels, depending on the mobilization of OPEC+ production and the growth of unconventional oil production in the United States.

After reaching all-time highs in the fourth quarter 2021, gas prices have remained very high in Europe and Asia since the beginning of 2022, driven by geopolitical uncertainties in Europe despite a mild winter season. In this context, futures markets anticipate gas prices that may remain above $20/Mbtu in 2022.

TotalEnergies anticipates 2022 hydrocarbon production growth of around 2%, driven by the start-ups of Mero 1 in Brazil and Ikike in Nigeria, the entry into the Atapu and Sépia PSCs in Brazil effective May 2022 but impacted by the sales of mature assets completed in 2021 as well as the exit from Myanmar effective July 2022.

Continuing the momentum that has been underway for several years, TotalEnergies is implementing its strategy of integrated growth in LNG, which is expected to generate structural cash flow growth in 2022. In addition, given the evolution of oil and gas prices in recent months and the lag effect on price formulas, TotalEnergies anticipates that its average LNG selling price should remain at a high level of at least $12/Mbtu in the first half of 2022.

In Renewables & Electricity, TotalEnergies plans to have more than 16 GW of renewable gross capacity in operation by year-end 2022. Electricity generation is expected to increase by more than 25% in 2022. To implement its profitable growth strategy in the electricity value chain, TotalEnergies expects to allocate, in 2022, $3.5 billion of net investments to Renewables & Electricity, or 25% of its net investments.

Downstream will continue to strengthen its industrial competitiveness and invest in petrochemicals and in new markets, such as biofuels and electric mobility.

Confident in its ability to transform itself into a sustainable multi-energy company and increase the return to shareholders, the Company confirms its cash flow allocation priorities: investing in profitable projects to implement its transformation strategy, linking dividend growth to structural cash flow growth, maintaining a strong balance sheet and a long-term debt rating with a minimum “A” level by anchoring gearing below 20%, and allocating a share of the surplus cash flow from high hydrocarbon prices to share buybacks.

In accordance with this policy, TotalEnergies expects net investments of $14-15 billion in 2022, of which 50% will be allocated to growth and 50% to maintaining the base of its activity.

1   Downstream refers to the Refining & Chemicals business segment and the Marketing & Services business segment.

2   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charge of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, except those related to leases.

3   Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

4   Refer to the reconciliation table for different cash flow figures set forth under “Cash Flow” on page 5.

5   Gearing = net debt / (net debt +shareholders equity TotalEnergies share + non-controlling interests); excludes leases receivables and leases debts. For additional information, refer to Note 15.1(E) to the Consolidated Financial Statements (starting on page F-71).

Form 20-F 2021   TotalEnergies

   3

5.2    TotalEnergies results 2019-2021

As of and for the year ended December 31 (in millions of dollars, except per share data)

2021

2020

2019

Sales

 

205,863

 

140,685

 

200,316

Adjusted EBITDA(a)(b)

42,302

21,112

35,163

Adjusted net operating income from business segments(b)

 

20,209

 

6,404

 

14,554

Integrated Gas, Renewables & Power

 

6,243

 

1,778

 

7,509

Exploration & Production

 

10,439

 

2,363

 

2,389

Refining & Chemicals

 

1,909

 

1,039

 

3,003

Marketing & Services

 

1,618

 

1,224

 

1,653

Net income (loss) from equity affiliates

 

3,438

 

452

 

3,406

Fully-diluted earnings per share ($)

 

5.92

 

(2.90)

 

4.17

Fully-diluted weighted-average shares (millions)(c)

 

2,647

 

2,621

 

2,618

Net income (TotalEnergies share)

 

16,032

 

(7,242)

 

11,267

Organic investments(d)

 

12,675

 

10,339

 

13,397

Net acquisitions(e)

 

632

 

2,650

 

4,052

Net investments(f)

 

13,307

 

12,989

 

17,449

Cash flow from operating activities(g)

 

30,410

 

14,803

 

24,685

Of which:

 

 

 

  

(increase)/decrease in working capital

 

(616)

 

1,869

 

(1,718)

financial charges

 

(1,520)

 

(1,938)

 

(2,069)

(a)

Adjusted results are defined as income using replacement cost, adjusted for special items, excluding the impact of changes in fair value. See “- 5.3 Business segment reporting” below for further details.

(b)

Adjusted EBITDA (Earnings Before Interest, Tax, Depreciation and Amortization) corresponds to the adjusted earnings before depreciation, depletion and impairment of tangible and intangible assets and mineral interests, income tax expense and cost of net debt, i.e., all operating income and contribution of equity affiliates to net income. The reconciliation of adjusted EBITDA with the consolidated financial statements is set forth under “Reconciliation of net income (TotalEnergies share) to adjusted EBITDA” on page 5.

(c)

In 2020, the effect generated by the grant of TotalEnergies performance shares and by the capital increase reserved for employees (19,007,836 shares) is anti-dilutive. In accordance with IAS 33, the weighted-average number of diluted shares is therefore equal to the weighted-average number of shares.

(d)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(e)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(f)

Net investments = organic investments + net acquisitions.

(g)

The reconciliation table for different cash flow figures is set forth under “Cash Flow” on page 5.

Market environment parameters

    

2021

    

2020

    

2019

Brent ($/b)

 

70.9

 

41.8

 

64.2

Henry Hub ($/Mbtu)(a)

 

3.7

 

2.1

 

2.5

NBP ($/Mbtu)(b)

 

16.4

 

3.3

 

4.9

JKM ($/Mbtu)(c)

 

18.5

 

4.4

 

5.5

Average price of liquids ($/b) (d)

 

65.0

 

37.0

 

59.8

Average price of gas ($/Mbtu) (d)

 

6.60

 

2.96

 

3.88

Average price of LNG ($/Mbtu) (e)

8.80

4.83

6.31

Variable cost margin – Refining Europe, VCM(f) ($/t)

 

10.5

 

11.5

 

34.9

(a)

Henry Hub (HH), a pipeline located in Erath, Louisiana, USA, serves as the official delivery point for New York Mercantile Exchange (NYMEX) futures contracts. It is widely used as a price reference for natural gas markets in North America. The hub is operated by Sabine Pipe Line LLC and is connected to four intrastate and nine interstate pipelines, including the Transcontinental, Acadian and Sabine pipelines.

(b)

NBP (National Balancing Point) is a virtual natural gas trading point in the United Kingdom for transferring rights in respect of physical gas and which is widely used as a price benchmark for the natural gas markets in Europe. NBP is operated by National Grid Gas plc, the operator of the UK transmission network.

(c)

JKM (Japan-Korea Marker) measures the prices of spot LNG trades in Asia. It is based on prices reported in spot market trades and/or bids and offers collected after the close of the Asian trading day at 16:30 Singapore time.

(d)

Consolidated subsidiaries.

(e)

Consolidated subsidiaries and equity affiliates.

(f)

This indicator represents TotalEnergies’ average margin on variable cost for refining in Europe (equal to the difference between TotalEnergies European refined product sales and crude oil purchases with associated variable costs divided by volumes refined in tons).

Hydrocarbon production*

    

2021

    

2020

    

2019

Hydrocarbon production (kboe/d)

2,819

2,871

3,014

Oil (including bitumen) (kb/d)

 

1,274

 

1,298

 

1,431

Gas (including condensates and associated NGL) (kboe/d)

 

1,545

 

1,573

 

1,583

Hydrocarbon production*

    

2021

    

2020

    

2019

Hydrocarbon production (kboe/d)

2,819

2,871

3,014

Liquids (kb/d)**

 

1,500

 

1,543

 

1,672

Gas (Mcf/d)***

 

7,203

 

7,246

7,309

*   TotalEnergies production = production of Exploration & Production segment (EP) + production of Integrated Gas, Renewables & Power segment (iGRP).

**  Including condensates and NGL associated with the production of gas.

*** 2019 data restated.

For a discussion of TotalEnergies’ proved reserves, refer to point 2.3.1 of chapter 2 of the Universal Registration Document 2021 (starting on page 88), incorporated herein by reference. See also point 9.1 of chapter 9 of the Universal Registration Document 2021 (starting on page 520), incorporated herein by reference, for additional information on proved reserves, including tables showing changes in proved reserves by region.

TotalEnergies   Form 20-F 2021

   4   

Adjustment Items to net income* (TotalEnergies share)

in millions of dollars

    

2021

    

2020

    

2019

Special items affecting net income (TotalEnergies share)

 

(3,329)

 

(10,044)

 

(892)

Gain (loss) on asset sales

 

(1,726)

 

104

 

Restructuring charges

 

(308)

 

(364)

 

(58)

Impairments

 

(910)

 

(8,465)

 

(465)

Other

 

(385)

 

(1,319)

 

(369)

After-tax inventory effect: FIFO vs. replacement cost

 

1,495

 

(1,280)

 

346

Effect of changes in fair value

 

(194)

 

23

 

(15)

Total adjustments affecting net income (TotalEnergies share)

 

(2,028)

 

(11,301)

 

(561)

*   For details on adjustments to operating income, refer to Note 3(C) to the Consolidated Financial Statements (starting on page F-26).

Cash Flow

in millions of dollars

    

2021

    

2020

    

2019

Operating cash flow before working capital changes w/o financial charges (DACF)

 

30,660

 

17,635

 

28,180

Financial charges

 

(1,520)

 

(1,938)

 

(2,069)

Operating cash flow before working capital changes ( a )*

 

29,140

 

15,697

 

26,111

(Increase) decrease in working capital**

 

188

 

753

 

(1,397)

Inventory effect

 

1,796

 

(1,440)

 

446

Capital gain from renewable project sales

 

(89)

 

(96)

 

Organic loan repayments from equity affiliates

 

(626)

 

(111)

 

(475)

Cash flow from operations

 

30,410

 

14,803

 

24,685

Organic investments ( b )

 

12,675

 

10,339

 

13,397

Free cash flow after organic investments, w/o net asset sales ( a - b )

 

16,465

 

5,358

 

12,714

Net investments ( c )

 

13,307

 

12,989

 

17,449

Net cash flow ( a - c )

 

15,833

 

2,708

 

8,662

*   Operating cash flow before working capital changes, is defined as cash flow from operating activities before changes in working capital at replacement cost, excluding the mark-to-market effect of iGRP’s contracts and including capital gain from renewable projects sales (effective first quarter 2020). Historical data have been restated to cancel the impact of fair valuation of the iGRP segment’s contracts.

**  Changes in working capital are presented excluding the mark-to-market effect of iGRP’s contracts.

Reconciliation of net income (TotalEnergies share) to adjusted EBITDA

in millions of dollars

    

2021

    

2020

    

2019

Net income - TotalEnergies share

 

16,032

 

(7,242)

 

11,267

Less: adjustment items to net income (TotalEnergies share)

 

2,028

 

11,301

 

561

Adjusted net income - TotalEnergies share

 

18,060

 

4,059

 

11,828

Adjusted items

 

  

 

  

 

  

Add: non-controlling interests

 

331

 

8

 

262

Add: income taxes

 

9,211

 

1,309

 

5,663

Add: depreciation, depletion and impairment of tangible assets and mineral interests

 

12,735

 

13,312

 

14,811

Add: amortization and impairment of intangible assets

 

401

 

352

 

262

Add: financial interest on debt

 

1,904

 

2,140

 

2,318

Less: financial income and expense from cash & cash equivalents

 

(340)

 

(68)

 

19

Adjusted EBITDA

 

42,302

 

21,112

 

35,163

2021 vs. 2020

In terms of market environment parameters:

the Brent price increased by 69% to $70.9/b on average in 2021 from $41.8/b on average in 2020;

TotalEnergies’ average liquids price realization1 increased by 76% to $65.0/b in 2021 from $37.0/b in 2020;

TotalEnergies’ average gas price realization2 was $6.60/Mbtu in 2021, or 2.2 times greater than $2.96/Mbtu in 2020;

TotalEnergies’ average LNG price realization3 increased by 82% to $8.80/Mbtu in 2021 from $4.83/Mbtu in 2020;

TotalEnergies’ variable cost margin – Refining Europe (VCM)4 decreased by 9% to $10.5/t on average in 2021 compared to $11.5/t in 2020.

1   Consolidated subsidiaries.

2   Consolidated subsidiaries.

3   Consolidated subsidiaries and equity affiliates.

4   This indicator represents TotalEnergies’ average margin on variable cost for refining in Europe (equal to the difference between TotalEnergies European refined product sales and crude oil purchases with associated variable costs divided by volumes refined in tons).

Form 20-F 2021   TotalEnergies

   5

Hydrocarbon production was 2,819 kboe/d for the full-year 2021, down 2% year-on-year, comprised of:

+3% due to start-ups and ramp-ups, including North Russkoye in Russia, Iara in Brazil and Johan Sverdrup in Norway, as well as the resumption of production in Libya;

+3% due to the increase in gas demand and OPEC+ quotas,

-1% due to portfolio effect, notably the disposals of assets in the UK and the CA1 block in Brunei;

-1% due to the price effect;

-3% due to planned maintenance and unplanned downtime, particularly in the UK and Norway (Snøhvit);

-3% due to the natural field decline.

The euro-dollar exchange rate averaged $1.1827/€ in 2021, compared to $1.1422/€ in 2020.

Sales were $205,863 million in 2021 compared to $140,685 million in 2020, an increase of 46%. In 2021, external sales were 2 times greater than 2020 for the Integrated Gas, Renewables & Power segment, 1.5 times greater for the Exploration & Production segment, 1.5 times greater for Refining & Chemicals segment and 1.3 times greater for the Marketing & Services segment.

Net income (TotalEnergies share) increased to $16,032 million in 2021 compared to $(7,242) million in 2020, due to higher oil and gas prices. In 2021, total adjustments to net income (TotalEnergies share), which include the after-tax inventory effect, special items and the impact of changes in fair value, had an impact of ($2,028) million, comprised of $(910) million for impairments (including $(305) million for the withdrawal of TotalEnergies from Myanmar and the $(89) million impairment related to the end of the Qatargas 1 contract) and $(170) million for the loss on the sale of TotalEnergies’ interest in Yucal Placer in Venezuela, as well as notably the $(1,379) million loss on the sale of TotalEnergies’ interest in Petrocedeño1 to PDVSA in Venezuela and the $(177) million loss on the Utica sale in the United States, restructuring charges related to the voluntary departure plan in France and Belgium, and a positive inventory effect of $1,495 million for the year. For a detailed overview of adjustment items for 2021, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19). In 2020, total adjustments to net income (TotalEnergies share), which include the after-tax inventory effect, special items and the impact of changes in fair value, had an impact of $(11,301) million, including $(8.5) billion of impairments, related mainly to oil sands assets in Canada.

Total income taxes in 2021 amounted to $(9,587) million, 30 times greater than $(318) million in 2020. For further detail on income taxes, refer to Note 11 to the Consolidated Financial Statements (starting on page F-57).

TotalEnergies SE bought back, in 2021, 37,306,005 TotalEnergies SE shares on the market, i.e., 1.4% of the share capital as of December 31, 2021, of which 30,665,526 million for cancellation and, in 2020, 13,236,044 TotalEnergies SE shares on the market, i.e., 0.50% of the share capital as of December 31, 2020, of which 12,233,265 for cancellation. See also “- 5.4.3 Shareholders’ equity”, below.

Fully-diluted earnings per share was $5.92 in 2021 compared to $(2.90) in 2020.

Finalized asset sales amounted to:

$2,652 million for the full-year 2021, including the sale of TotalEnergies’ interests in 7 mature non-operated offshore fields and the Cap Lopez oil terminal in Gabon and the sale of a 30% interest in TRAPIL in France as well as the payment by GIP of more than $750 million as part of the tolling agreement for the infrastructure of the Gladstone LNG project in Australia, the sale in France of a 50% interest in a portfolio of renewable projects with a total capacity of 285 MW (100%), the sale of the 10% stake in onshore block OML 17 in Nigeria, the price supplement related to the sale of Block CA1 in Brunei, the sale of the Lindsey refinery in the United Kingdom, the sale of interests in the TBG pipeline in Brazil, the sale of shares in Clean Energy Fuels Corp. (NASDAQ: CLNE)2 , and the sale of its interests in Tellurian Inc. (NASDAQ: TELL) in the United States; and
$1.5 billion for the full-year 2020, comprised notably of the sale of Enphase shares by SunPower (NASDAQ: SPWR)3, the sale of TotalEnergies’ corporate offices in Brussels, the sale of non-strategic assets in the UK North Sea, the completion of the sale of Block CA1 in Brunei, the sale of TotalEnergies’ interest in the Fos Cavaou regasification terminal in France, and the sale of 50% of a portfolio of solar and wind assets from Total Quadran in France.

Finalized acquisitions4 amounted to:

$3,284 million for the full-year 2021, including the acquisition of Blue Raven Solar by SunPower in the United States as well as notably the acquisition of a 20% interest for $2 billion in Adani Green Energy Limited, the renewable project developer in India, the acquisition of Fonroche Biogaz in France, the interest in the Yunlin wind project in Taiwan and the 10% increase in its interest in the Lapa block in Brazil.
$4.2 billion for the full-year 2020, comprised notably of the acquisition of Tullow’s entire interest in the Lake Albert project in Uganda, the acquisition of CCGT assets and of a portfolio of customers from Energías de Portugal in Spain, the acquisition in India of 50% of a portfolio of installed solar activities from Adani Green Energy Limited, the finalization of the acquisition of 37.4% stake in Adani Gas Ltd, the acquisition of interests in Blocks 20 and 21 in Angola and the payment for a second bonus tranche linked to taking the 10% stake in the Arctic LNG 2 project in Russia.

TotalEnergies’ cash flow from operating activities for the full-year 2021 was $30,410 million, 2.1 times greater than $14,803 million for the full-year 2020. The change in working capital as determined using the replacement cost method5 excluding the mark-to-market effect of iGRP’s contracts, including capital gain from renewable project sales (effective first quarter 2020) and including organic loan repayment from equity affiliates was a decrease of $1,269 million for the full-year 2021, compared to an increase of $894 million for the full-year 2020. For the full-year 2021, the change in working capital was an increase of $616 million in accordance with IFRS. The difference of $1,885 million between IFRS and replacement cost method corresponds to the following adjustments: (i) the pre-tax inventory valuation effect of $1,796 million, (ii) plus the mark-to-market effect of iGRP’s contracts of $804 million, (iii) less the capital gains from renewables project sale of $89 million and (iv) less the organic loan repayments from equity affiliates of $626 million.

1   Sale of TotalEnergies’ interest in Petrocedeño S.A. to Corporation Venezolana de Petróleos (CVP), an affiliate of Petróleos de Venezuela (PDVSA).

2   As at December 31, 2021, TotalEnergies held an interest of 19.09% in Clean Energy Fuels Corp., an American company listed on NASDAQ and based in California.

3   As at December 31, 2021, TotalEnergies held an interest of 50.83% in SunPower, an American company listed on NASDAQ and based in California.

4   Acquisitions net of operations with non-controlling interests.

5   For information on the replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

TotalEnergies   Form 20-F 2021

   6   

Operating cash flow before working capital changes1 totaled $29,140 million for the full-year 2021, an increase of 86% compared to $15,697 million for the full-year 2020. Operating cash flow before working capital changes without financial charges (DACF)2 totaled $30,660 million for the full-year 2021, an increase of 74% compared to $17,635 million for the full-year 2020.

TotalEnergies’ net cash flow3 totaled $15,833 million in 2021 compared to $2,708 million in 2020, reflecting the $13.4 billion increase in operating cash flow before working capital changes and a $318 million increase in net investments to $13,307 million in 2021.

See also “- 5.4 Liquidity and Capital Resources”, below.

2020 vs. 2019

In 2020, market conditions were less favorable than in 2019 due to the COVID-19 pandemic and the oil crisis. The Brent price decreased to $41.8/b on average in 2020 from $64.2/b on average in 2019, while remaining volatile throughout 2020. TotalEnergies’ average liquids price realization4 decreased by 38% to $37.0/b in 2020 from $59.8/b in 2019. TotalEnergies’ average gas price realization5 decreased by 24% to $2.96/Mbtu in 2020 from $3.88/Mbtu in 2019. TotalEnergies’ average LNG price realization6 decreased by 24% to $4.83/Mbtu in 2020 from $6.31/Mbtu in 2019. TotalEnergies’ variable cost margin – Refining Europe (VCM) decreased by 67% to $11.5/t on average in 2020 compared to $34.9/t in 2019, mainly due to decreasing crude oil prices.

For the full-year 2020, hydrocarbon production was 2,871 kboe/d, a decrease of 5% compared to 3,014 kboe/d in 2019, comprised of:

-5% due to compliance with OPEC+ quotas, notably in Nigeria, the United Arab Emirates and Kazakhstan, as well as voluntary reductions in Canada and disruptions in Libya;

+5% due to the ramp-up of recently started projects, notably Culzean in the United Kingdom, Johan Sverdrup in Norway, Iara in Brazil, Tempa Rossa in Italy and North Russkoye in Russia;

-3% due to the natural decline of fields; and

-2% due to maintenance, and unplanned outages, notably in Norway.

The euro-dollar exchange rate averaged $1.1422/€ in 2020, compared to $1.1195/€ in 2019.

Sales were $140,685 million in 2020 compared to $200,316 million in 2019, a decrease of 30% reflecting the decreased hydrocarbon prices and the decrease in global energy demand due to the COVID-19 pandemic. In 2020, external sales decreased by 32% for the Exploration & Production segment, 14% for the Integrated Gas, Renewables & Power segment, 35% for Refining & Chemicals segment and 27% for the Marketing & Services segment compared to 2019.

Net income (TotalEnergies share) decreased to $(7,242) million in 2020 compared to $11,267 million in 2019, due to exceptional asset impairments, notably on Canadian oil sands assets. In 2020, total adjustments to net income (TotalEnergies share), which include the after-tax inventory effect, special items and the impact of changes in fair value, had a negative impact of $11,301 million, including $8.5 billion of impairments, related mainly to oil sands assets in Canada. For a detailed overview of adjustment items for 2020, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19). In 2019, adjustments to net income (TotalEnergies share), which include the after-tax inventory effect, special items and the impact of changes in fair value, had a negative impact of $561 million mainly due to impairments of assets mainly located in the United States (Utica, Chinook).

Total income taxes in 2020 amounted to $(318) million, a decrease of 95% compared to $(5,872) million in 2019, due to the relative weight and lower tax rates in the Upstream segment and a lower hydrocarbon price environment.

TotalEnergies SE bought back, in 2020, 13,236,044 of its shares on the market, i.e., 0.50% of its share capital as of December 31, 2020, of which 12,233,265 for cancellation and, in 2019, 52,389,336 of its shares on the market, i.e., 2.01% of its outstanding share capital as of December 31, 2019, of which 32,723,365 for cancellation. See also “- 5.4.3 Shareholders’ equity”, below.

Fully-diluted earnings per share was $(2.90) in 2020 compared to $4.17 in 2019.

Finalized asset sales amounted to $1.5 billion in 2020, comprised notably of the sale of Enphase shares by SunPower7, the sale of TotalEnergies’ corporate offices in Brussels, the sale of non-strategic assets in the UK North Sea, the completion of the sale of Block CA1 in Brunei, the sale of TotalEnergies’ interest in the Fos Cavaou regasification terminal in France, and the sale of 50% of a portfolio of solar and wind assets from Total Quadran in France. Finalized asset sales amounted to $1,939 million for the full-year 2019, comprised notably of the payment received upon the take-over of the Toshiba LNG portfolio in the United States, the sale of the interest in the Wepec refinery in China and the sale of TotalEnergies’ interest in the Hazira terminal in India and polystyrene activities in China.

Finalized acquisitions amounted to $4.2 billion for the full-year 2020, comprised notably of the acquisition of Tullow’s entire interest in the Lake Albert project in Uganda, the acquisition of CCGT assets and of a portfolio of customers from Energías de Portugal in Spain, the acquisition in India of 50% of a portfolio of installed solar activities from Adani Green Energy Limited, the finalization of the acquisition of 37.4% stake in Adani Gas Ltd, the acquisition of interests in Blocks 20 and 21 in Angola and the payment for a second bonus tranche linked to taking the 10% stake in the Arctic LNG 2 project in Russia. Finalized acquisitions amounted to $5,991 million for the full-year 2019, comprised mainly of the acquisition of Anadarko’s interest in Mozambique LNG, the acquisition of a 10% stake in the Arctic LNG 2 project in Russia and the acquisition of Chevron’s interest in the Danish Underground Consortium in Denmark.

1   Operating cash flow before working capital changes is defined as cash flow from operating activities before changes in working capital at replacement cost, excluding the mark-to-market effect of iGRP’s contracts and including capital gain from renewable projects sales (effective first quarter 2020). Operating cash flow before working capital changes provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the replacement cost method, refer to refer to Note 3 to the Consolidated Financial Statements (starting on page F-19). The reconciliation table for different cash flow figures is set forth under “Cash Flow” on page 5.

2   DACF = debt adjusted cash flow, is defined as operating cash flow before working capital changes and without financial charges.

3   See the reconciliation table for different cash flow figures set forth under “Cash Flow” on page 5.

4   Consolidated subsidiaries.

5   Consolidated subsidiaries.

6   Consolidated subsidiaries and equity affiliates.

7   As at December 31, 2020, TotalEnergies held an interest of 51.61% in SunPower, an American company listed on NASDAQ and based in California.

Form 20-F 2021   TotalEnergies

   7

TotalEnergies’ cash flow from operating activities for the full-year 2020 was $14,803 million, a decrease of 40% compared to $24,685 million for the full-year 2019. The change in working capital as determined using the replacement cost method excluding the mark-to-market effect of iGRP’s contracts, including capital gain from renewable project sales (effective first quarter 2020) and including organic loan repayment from equity affiliates was an increase of $894 million for the full-year 2020, compared to an increase of $1,426 million for the full-year 2019. For the full-year 2020, the change in working capital was a decrease of $1,869 million in accordance with IFRS. The difference of $2,763 million between IFRS and replacement cost method corresponds to the following adjustments: (i) the pre-tax inventory valuation effect of $1,440 million, (ii) plus the mark-to-market effect of iGRP’s contracts of $1,116 million, (iii) plus the capital gains from renewables project sale of $96 million and (iv) plus the organic loan repayments from equity affiliates of $111 million.

Operating cash flow before working capital changes totaled $15,697 million for the full-year 2020, a decrease of 40% compared to $26,111 million for the full-year 20191. Operating cash flow before working capital changes without financial charges (DACF) totaled $17,635 million for the full-year 2020, a decrease of 37% compared to $28,180 million for the full-year 2019.

TotalEnergies’ net cash flow was $2,708 million in 2020 compared to $8,662 million in 2019, due to the decrease of $10,414 million in operating cash flow before working capital changes, partially offset by a reduction in net investments of $4,460 million.

See also “- 5.4 Liquidity and Capital Resources”, below.

5.3    Business segment reporting

Financial information by business segment is reported in accordance with the internal reporting system and shows internal segment information that is used to manage and measure the performance of TotalEnergies and which is reviewed by the main operational decision-making body of TotalEnergies, namely the Executive Committee.

Due to their unusual nature or particular significance, certain transactions qualifying as “special items” are excluded from the business segment figures. In general, special items relate to transactions that are significant, infrequent or unusual. In certain instances, certain transactions such as restructuring costs or asset disposals, which are not considered to be representative of the normal course of business, may qualify as special items although they may have occurred in prior years or are likely to occur again in following years.

In accordance with IAS 2, TotalEnergies values inventories of petroleum products in its financial statements according to the First-In, First-Out (FIFO) method and other inventories using the weighted-average cost method. Under the FIFO method, the cost of inventory is based on the historic cost of acquisition or manufacture rather than the current replacement cost. In volatile energy markets, this can have a significant distorting effect on the reported income. Accordingly, the adjusted results of the Refining & Chemicals and Marketing & Services segments are presented according to the replacement cost method. This method is used to assess the segments’ performance and facilitate the comparability of the segments’ performance with those of its main competitors. In the replacement cost method, which approximates the Last-In, First-Out (LIFO) method, the variation of inventory values in the statement of income is, depending on the nature of the inventory, determined using either the month-end price differential between one period and another or the average prices of the period rather than the historical value. The inventory valuation effect is the difference between the results under the FIFO and replacement cost methods.

The effect of changes in fair value presented as an adjustment item reflects, for trading inventories and storage contracts, differences between internal measures of performance used by TotalEnergies’ Executive Committee and the accounting for these transactions under IFRS. IFRS requires that trading inventories be recorded at their fair value using period-end spot prices. In order to best reflect the management of economic exposure through derivative transactions, internal indicators used to measure performance include valuations of trading inventories based on forward prices. TotalEnergies, in its trading activities, enters into storage contracts, the future effects of which are recorded at fair value in TotalEnergies’ internal economic performance. IFRS precludes recognition of this fair value effect. Furthermore, TotalEnergies enters into derivative instruments to risk manage certain operational contracts or assets. Under IFRS, these derivatives are recorded at fair value while the underlying operational transactions are recorded as they occur. Internal indicators defer the fair value on derivatives to match with the transaction occurrence.

The adjusted business segment results (adjusted operating income, adjusted net operating income, adjusted net income) are defined as replacement cost results, adjusted for special items, excluding the effect of changes in fair value. For further information on the adjustments affecting operating income on a segment-by-segment basis, and for a reconciliation of segment figures to figures reported in TotalEnergies’ audited consolidated financial statements, see Note 3 to the Consolidated Financial Statements (starting on page F-19).

TotalEnergies measures performance at the segment level on the basis of adjusted net operating income. Net operating income comprises operating income of the relevant segment after deducting the amortization and the depreciation of intangible assets other than leasehold rights, translation adjustments and gains or losses on the sale of assets, as well as all other income and expenses related to capital employed (dividends from non-consolidated companies, income from equity affiliates and capitalized interest expenses) and after income taxes applicable to the above. The income and expenses not included in net operating income that are included in net income are interest expenses related to long-term liabilities net of interest earned on cash and cash equivalents, after applicable income taxes (net cost of net debt and non-controlling interests). Adjusted net operating income excludes the effect of the adjustments (special items and the inventory valuation effect) described above. For further discussion of the calculation of net operating income and the calculation of return on average capital employed (ROACE)2, see Note 3 to the Consolidated Financial Statements (starting on page F-19). Performance indicators excluding the adjustment items, such as adjusted incomes and ROACE are meant to facilitate the analysis of the financial performance and the comparison of income between periods.

The profitable growth in the gas and low carbon electricity integrated value chains is one of the key axes of TotalEnergies’ strategy. In order to give more visibility to these businesses, a new reporting structure for the business segments’ financial information has been put in place, effective January 1, 2019.

1   2019 data restated to cancel impact of fair valuation of iGRP segment contracts.

2   ROACE = ratio of adjusted net operating income to average capital employed between the beginning and the end of the period.

TotalEnergies   Form 20-F 2021

   8   

The organization of TotalEnergies’ activities is structured around the four following segments:

-

an Integrated Gas, Renewables & Power segment comprising integrated gas (including LNG) and low carbon electricity businesses. It includes the upstream and midstream LNG activity;  

-

an Exploration & Production segment. Starting September 2021, it notably includes the carbon sink activity (carbon storage and nature-based solutions) that was previously reported in the Integrated Gas, Renewables & Power segment. Business segment information relating to fiscal years 2019 and 2020 have not been restated due to the non-material impact of this change;

-

a Refining & Chemicals segment constituting a major industrial hub comprising the activities of refining, petrochemicals and specialty chemicals. This segment also includes the activities of oil Supply, Trading and marine Shipping; and

-

a Marketing & Services segment including the global activities of supply and marketing in the field of petroleum products.

5.3.1    Integrated Gas, Renewables & Power (iGRP) segment

Hydrocarbon production and Liquefied Natural Gas (LNG) sales

Hydrocarbon production for LNG

2021

2020

2019

iGRP (kboe/d)

529

530

560

Liquids (kb/d)*

63

69

71

Gas (Mcf/d)**

2,541

2,519

2,656

*   Including condensates and NGLs, associated with the production of gas.

**  2019 data restated.

LNG sales

    

2021

    

2020

    

2019

Overall LNG sales (Mt)

42.0

38.3

34.3

including sales from equity production*

 

17.4

 

17.6

 

16.3

including sales by TotalEnergies from equity production and third-party purchases

 

35.1

 

31.1

 

27.9

*   The Company’s equity production may be sold by TotalEnergies or by joint ventures.

Renewables & Electricity

    

2021

    

2020

    

2019

Portfolio of renewable power generation gross capacity (GW) (1),(2)

43.0

28.6

o/w installed capacity

10.3

7.0

3.0

o/w capacity in construction

6.5

4.1

o/w capacity in development

26.2

17.5

Gross renewables capacity with PPA (GW) (1),(2)

28.0

17.5

Portfolio of renewable power generation net capacity (GW) (1),(2)

31.7

19.2

o/w installed capacity

5.1

3.1

o/w capacity in construction

4.6

2.3

o/w capacity in development

22.0

13.8

Net power production (TWh) (3)

 

21.2

 

14.1

 

11.4

incl. power production from renewables

 

6.8

 

4.0

 

2.0

Clients power – BtB and BtC (Million) (2)

 

6.1

 

5.6

 

4.1

Clients gas – BtB and BtC (Million) (2)

 

2.7

 

2.7

 

1.7

Sales power – BtB and BtC (TWh)

 

56.6

 

47.3

 

46.0

Sales gas – BtB and BtC (TWh)

101.2

95.8

95.0

1   Includes 20% of Adani Green Energy Limited (AGEL) gross capacity effective first quarter 2021.

2   End of period data.

3   Solar, wind, biogas, hydroelectric and combined-cycle gas turbine (CCGT) plants.

Results (in millions of dollars except ROACE)

    

2021

    

2020

    

2019

External sales

 

30,704

 

15,629

 

18,167

Operating income(a)

 

3,350

 

(527)

 

1,184

Net income (loss) from equity affiliates and other items

 

2,745

 

794

 

2,330

Tax on net operating income

 

(602)

 

71

 

(741)

Net operating income(a)

 

5,493

 

338

 

2,773

Adjustments affecting net operating income

 

750

 

1,440

 

(384)

Adjusted net operating income(b)

 

6,243

 

1,778

 

2,389

including adjusted income from equity affiliates

 

2,696

 

375

 

1,009

Organic investments(c)

 

3,341

 

2,720

 

2,259

Net acquisitions(d)

 

1,165

 

2,183

 

3,921

Net investments(e)

 

4,506

 

4,903

 

6,180

ROACE

 

12.3%

4.1%

6.3%

(a)

For the definitions of “operating income” and “net operating income”, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

(b)

Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

(c)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(d)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(e)

Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

Form 20-F 2021   TotalEnergies

   9

2021 vs. 2020

Gross installed renewable power generation capacity grew to 10.3 GW at year-end 2021, up 3.3 GW year-on-year, due in particular to the acquisition by AGEL of the operating assets of SB Energy India’s 5 GW renewable portfolio, the continued growth of start-ups in India and the commissioning of the Dunkirk battery-powered storage site in France.

TotalEnergies continues to implement its strategy of integrating the electricity and gas chain in Europe. Net electricity production stood at 21.2 TWh in 2021, up 50% compared to 2020, due to strong growth in electricity production from renewable sources as well as combined cycle gas turbine (CCGT) power plants, strengthened by the acquisition of four CCGT plants in France and Spain in the fourth quarter 2020. The portfolio of electricity customer exceeded 6 million at year-end 2021.

External sales for the iGRP segment for the full-year 2021 were $30,704 million, 2 times greater than $15,629 million in 2020.

Adjusted net operating income for the iGRP segment was $6,243 million for the full-year 2021, a 3.5-fold increase from 2020, due to higher LNG prices and the strong performance of the gas, LNG and electricity trading activities.

Adjusted net operating income for the iGRP segment excludes special items and the impact of changes in fair value. For the full-year 2021, the exclusion of special items had a positive impact of $750 million on the segment’s adjusted net operating income, compared to a positive impact of $1,440 million for the full-year 2020.

For the full-year 2021, the segment’s operating cash flow before working capital changes without financial charges (DACF)1 was $6,124 million, up 79% compared to $3,148 million for the full-year 2020, for the same reasons as adjusted net operating income.

For the full-year 2021, the segment’s cash flow from operating activities excluding financial charges, except those related to leases was $827 million, a decrease of 61% from $2,129 million for 2020, mainly due to variations in margin calls related to hedging mechanisms in a context of high volatility in the gas and electricity markets.

In this context, the iGRP segment’s ROACE for the full-year 2021 was 12.3% compared to 4.1% for the full-year 2020.

For information on the segment’s investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference. See also “- 5.4 Liquidity and Capital Resources”, below.

2020 vs. 2019

Hydrocarbon production for LNG in 2020 decreased by 5% compared to a year ago, notably due to the shutdown of Snøhvit LNG following a fire at the end of September 2020. Total LNG sales increased by 12% in volume in 2020 compared to 2019 due to the start-up of three trains at Cameron LNG in the United States, the ramp-up of Yamal LNG in Russia and Ichthys LNG in Australia and the increase in trading activities.

TotalEnergies’ gross installed renewable power generation capacity more than doubled during 2020 to reach 7 GW at the end of the fourth quarter 2020, notably thanks to the acquisition in India of 50% of a 3 GWp portfolio from the Adani Group.

TotalEnergies continued to implement its strategy to integrate along the electricity and gas chain in Europe and has increased the number of its electricity and gas customers by 1.5 million and 1 million since 2019, respectively, notably due to the finalization of the acquisition in the fourth quarter 2020 of a portfolio of customers from Energías de Portugal in Spain.

External sales for the iGRP segment in 2020 were $15,629 million compared $18,167 million in 2019, a decrease of 14%.

The iGRP segment’s adjusted net operating income was $1,778 million in 2020, a decrease of 26% compared to $2,389 million in 2019, mainly due to a decrease in the LNG price.

Adjusted net operating income for the iGRP segment excludes special items. In 2020, the exclusion of special items had a positive impact of $1,440 million on the iGRP segment’s adjusted net operating income. Special items included impairments of LNG assets located in Australia. For further information on the recognition of impairment of assets for the iGRP segment, refer to Note 3.D to the Consolidated Financial Statements (starting on page F-27). In 2019, the exclusion of special items had a negative impact of $384 million on the iGRP segment’s adjusted net operating income.

For the full-year 2020, the iGRP segment’s operating cash flow before working capital changes without financial charges (DACF) was $3,418 million, stable compared to $3,409 million for the full-year 20192.

For the full-year 2020, the iGRP segment’s cash flow from operating activities excluding financial charges, except those related to leases was $2,129 million, a decrease of 38% compared to $3,461 million for the full-year 2019.

In this context, the iGRP segment’s ROACE for the full-year 2020 was 4.1% compared to 6.3% for the full-year 2019.

5.3.2    Exploration & Production segment

Hydrocarbon production

    

2021

    

2020

    

2019

EP (kboe/d)

 

2,290

 

2,341

 

2,454

Liquids (kb/d)*

 

1,437

 

1,474

 

1,601

Gas (Mcf/d)

 

4,662

 

4,727

 

4,653

*   Including condensates and NGLs, associated with the production of gas.

1   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charges of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases, excluding the impact of contracts recognized at fair value for the segment and including capital gains on the sale of renewable projects.

2   2019 data restated.

TotalEnergies   Form 20-F 2021

   10   

Results (in millions of dollars except effective tax rate and ROACE)

2021

2020

2019

External sales

7,246

4,973

7,261

Operating income(a)

16,310

(5,514)

10,542

Net income (loss) from equity affiliates and other items

(760)

697

610

Effective tax rate(b)

45.2%

29.4%

41.5%

Tax on net operating income

(7,506)

(208)

(4,572)

Net operating income(a)

8,044

(5,025)

6,580

Adjustments affecting net operating income

2,395

7,388

929

Adjusted net operating income(c)

10,439

2,363

7,509

including adjusted income from equity affiliates

1,230

928

996

Organic investments(d)

6,690

5,519

8,635

Net acquisitions(e)

(167)

544

14

Net investments(f)

6,523

6,063

8,649

ROACE

13.9%

2.8%

8.4%

(a)

For the definitions of “operating income” and “net operating income”, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

(b)

Effective tax rate = tax on adjusted net operating income/(adjusted net operating income – adjusted income from equity affiliates - dividends received from investments - impairment of goodwill + tax on adjusted net operating income).

(c)

Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

(d)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(e)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(f)

Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

2021 vs. 2020

External sales for the EP segment in 2021 were $7,246 million compared to $4,973 million in 2020, an increase of 46%.

The Exploration & Production (EP) segment’s adjusted net operating income was $10,439 million in 2021, more than four times higher than in 2020, due to the sharp increase in oil and gas prices. Adjusted net operating income for the EP segment excludes special items. For the full-year 2021, the exclusion of special items had a positive impact of $2,395 million on the segment’s adjusted net operating income compared to a positive impact of $7,388 million for the full-year 2020. The effective tax rate increased from 29.4% in 2020 to 45.2% in 2021.

For the full-year 2021, the segment’s operating cash flow before working capital changes without financial charges (DACF)1 was $18,717 million, an increase of 93% compared to $9,684 million for the full-year 2020, in line with higher oil and gas prices.

For the full-year 2021, the segment’s cash flow from operating activities excluding financial charges, except those related to leases was $22,009 million, 2.2 times greater than $9,922 million for the full-year 2020.

In this context, the EP segment’s ROACE for the full-year 2021 was 13.9% compared to 2.8% for the full-year 2020.

For additional information on the EP segment’s capital expenditures, refer to point 1.6 (starting on page 30) of chapter 1 and point 2.3.2 (on page 89) of chapter 2 of the Universal Registration Document 2021, incorporated herein by reference. See also “- 5.4 Liquidity and Capital Resources”, below.

2020 vs. 2019

External sales for the EP segment in 2020 were $4,973 million compared to $7,261 million in 2019, a decrease of 32%.

The EP segment’s adjusted net operating income was $2,363 million in 2020, a decrease of 69% compared to $7,509 million in 2019, due to the sharp drop in oil and gas prices and lower production. The effective tax rate decreased from 41.5% in 2019 to 29.4% in 2020, in line with this sharp drop.  Adjusted net operating income for the EP segment excludes special items. In 2020, the exclusion of special items had a positive impact of $7,388 million on the EP segment’s adjusted net operating income. Special items included impairments of TotalEnergies’ oil sands assets in Canada. For further information on the recognition of impairment of assets for the EP segment, refer to Note 3.D to the Consolidated Financial Statements (starting on page F-29). In 2019, the exclusion of special items had a positive impact of $929 million on the EP segment’s adjusted net operating income.

For the full-year 2020, the EP segment’s operating cash flow before working capital changes without financial charges (DACF) was $9,684 million, a decrease of 46% compared to $18,030 million for the full-year 2019.

For the full-year 2020, the segment’s cash flow from operating activities excluding financial charges, except those related to leases was $9,922 million, a decrease of 41% compared to $16,917 million for the full-year 2019.

In this context, the EP segment’s ROACE for the full-year 2020 was 2.8% compared to 8.4% for the full-year 2019.

1   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charge of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases. Operating cash flow before changes in working capital at replacement cost provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the inventory effect and the replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

Form 20-F 2021   TotalEnergies

   11

5.3.3    Downstream (Refining & Chemicals and Marketing & Services segments)

Results (in millions of dollars)

    

2021

    

2020

    

2019

External sales

 

167,888

 

120,066

 

174,878

Operating income(a)

 

5,923

 

627

 

5,394

Net income (loss) from equity affiliates and other items

 

626

 

(356)

 

423

Tax on net operating income

 

(1,806)

 

(456)

 

(1,068)

Net operating income(a)

 

4,743

 

(185)

 

4,749

Adjustments affecting net operating income

 

(1,216)

 

2,448

 

(93)

Adjusted net operating income(b)

 

3,527

 

2,263

 

4,656

Organic investments(c)

 

2,576

 

2,023

 

2,395

Net acquisitions(d)

 

(368)

 

32

 

118

Net investments(e)

 

2,208

 

2,055

 

2,513

(a)

For the definitions of “operating income” and “net operating income”, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

(b)

Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

(c)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(d)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(e)

Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

The Downstream’s operating cash flow before working capital changes without financial charges (DACF)1 was $5,502 million for the full-year 2021, an increase of 18% compared to $4,652 million for the full-year 2020.

The Downstream’s cash flow from operating activities excluding financial charges, except those related to leases was $8,806 million for the full-year 2021, an increase of 94% compared to $4,539 million for the full-year 2020.

A.    Refining & Chemicals segment

Refinery throughput and utilization rates(a)

    

2021

    

2020

    

2019

Total refinery throughput (kb/d)

 

1,180

 

1,292

 

1,671

France

 

190

 

244

 

456

Rest of Europe

 

568

 

618

 

754

Rest of World

 

423

 

430

 

462

Utilization rates based on crude only(b)

 

64%

61%

80%

(a)

Includes refineries in Africa reported in the Marketing & Services segment.

(b)

Based on distillation capacity at the beginning of the year, excluding Grandpuits (shut down first quarter 2021) from 2021 and Lindsey refinery (divested) from second quarter 2021.

Petrochemicals production and utilization rate

    

2021

    

2020

    

2019

Monomers* (kt)

 

5,775

 

5,519

 

5,219

Polymers (kt)

 

4,938

 

4,934

 

4,862

Vapocracker utilization rate**

 

90%

83%

83%

*   Olefins.

**  Based on olefins production from steamcrackers and their treatment capacity at the start of the year.

Results (in millions of dollars except ROACE)

    

2021

    

2020

    

2019

External sales

 

87,600

 

56,615

 

87,598

Operating income(a)

 

3,564

 

(814)

 

3,342

Net income (loss) from equity affiliates and other items

 

518

 

(393)

 

322

Tax on net operating income

 

(1,068)

 

59

 

(470)

Net operating income(a)

 

3,014

 

(1,148)

 

3,194

Adjustments affecting net operating income

 

(1,105)

 

2,187

 

(191)

Adjusted net operating income(b)

 

1,909

 

1,039

 

3,003

Organic investments(c)

 

1,502

 

1,209

 

1,426

Net acquisitions(d)

 

(217)

 

(54)

 

(44)

Net investments(e)

 

1,285

 

1,155

 

1,382

ROACE

 

19.6%

8.8%

26.3%

(a)

For the definitions of “operating income” and “net operating income”, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

(b)

Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

(c)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(d)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(e)

Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

1   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charge of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases. Operating cash flow before changes in working capital at replacement cost provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the inventory effect and replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

TotalEnergies   Form 20-F 2021

   12   

2021 vs. 2020

Refinery throughput decreased by 9% in 2021 compared to 2020, due to the prolonged shutdown of the Donges refinery for economic reasons, the shutdown of the Grandpuits refinery for conversion to a zero-oil platform and the sale of the Lindsey refinery in the United Kingdom as well as the planned major shutdown of the Leuna refinery in Germany in the second quarter 2021. For further information on the shutdowns, refer to point 2.4.1.1 of chapter 2 of the Universal Registration Document 2021 (starting on page 100), incorporated herein by reference.

Monomer production increased 5% in 2021 compared to 2020, supported by demand, and notably due to the restart of the Port Arthur steam cracker in the United States, in maintenance in 2020. Polymer production was stable for full-year 2021 compared to full-year 2020.

External sales for the Refining & Chemicals segment in 2021 were $87,600 million, 1.5 times greater than $56,615 million in 2020.

Adjusted net operating income for the Refining & Chemicals segment increased 84% to $1,909 million in 2021, compared to $1,039 million in 2020, linked to the strong performance of petrochemicals and the increase in European and American refining margins, despite the increase in energy costs. Adjusted net operating income for this segment excludes any after-tax inventory valuation effect and special items. For the full-year 2021, the exclusion of the inventory valuation effect had an impact of $(1,296) million on the segment’s adjusted net operating income, compared to a positive impact of $1,165 million for the full-year 2020. For the full-year 2021, the exclusion of special items had a positive impact of $191 million on the segment’s adjusted net operating income, compared to a positive impact of $1,022 million for the full-year 2020.

For the full-year 2021, the Refining & Chemicals segment’s operating cash flow before working capital changes without financial charges (DACF)1 was $2,946 million, an increase of 19% year-on-year compared to $2,472 million for the full-year 2020, in line with the strong performance of petrochemicals and refining margins that increased, although still low, at the end of 2021.

For the full-year 2021, the Refining & Chemicals segment’s cash flow from operating activities excluding financial charges, except those related to leases was $6,473 million, 2.7 times greater than $2,438 million for the full-year 2020.

In this context, the Refining & Chemicals segment’s ROACE for the full-year 2021 was 19.6% compared to 8.8% for the full-year 2020.

For information on the Refining & Chemicals segment’s investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference. See also “- 5.4 Liquidity and Capital Resources”, below.

2020 vs. 2019

Refinery throughput volumes decreased by 23% in 2020 year-on-year mainly due to high inventories of refined products and the drop in demand which notably led to the economic shutdown of the Donges refinery as well as the prolonged shutdown of the distillation unit at the Normandy platform following a fire that affected the distillation unit at the end of 2019.

Monomer production increased 6% in 2020 year-on-year, supported by demand, and notably as a result of the 2019 planned maintenance on the steamcracker at Daesan in South Korea. Polymer production was stable for full-year 2020 compared to full-year 2019.

External sales for the Refining & Chemicals segment in 2020 were $56,615 million compared to $87,598 million in 2019, a decrease of 35%.

The Refining & Chemicals segment’s adjusted net operating income was $1,039 million for the full-year 2020, a decrease of 65% compared to $3,003 million for the full-year 2019, due to refining margin deterioration, partially offset by resilient petrochemical margins and outperformance of the trading activities. Adjusted net operating income for this segment excludes any after-tax inventory valuation effect and special items. For the full-year 2020, the exclusion of the inventory valuation effect had a positive impact of $1,165 million on the segment’s adjusted net operating income, compared to a negative impact of $371 million for the full-year 2019. For the full-year 2020, the exclusion of special items had a positive impact of $1,022 million on the segment’s adjusted net operating income, compared to a positive impact of $180 million for the full-year 2019. Special items in 2020 included impairments of refining cash-generating units located in France and the United Kingdom. For further information on the recognition of impairment of assets for the Refining & Chemicals segment, refer to Note 3.D to the Consolidated Financial Statements (starting on page F-27).

For the full-year 2020, the Refining & Chemicals segment’s operating cash flow before working capital changes without financial charges (DACF) was $2,472 million, a decrease of 39% compared to $4,072 million for the full-year 2019.

For the full-year 2020, the segment’s cash flow from operating activities excluding financial charges, except those related to leases was $2,438 million, a decrease of 36% compared to $3,837 million for the full-year 2019.

In this context, the Refining & Chemicals segment’s ROACE for the full-year 2020 was 8.8% compared to 26.3% for the full-year 2019.

B.    Marketing & Services segment

Petroleum product sales(a) (kb/d)

    

2021

    

2020

    

2019

Total Marketing & Services sales

 

1,503

 

1,477

 

1,845

Europe

 

826

 

823

 

1,021

Rest of world

677

654

824

(a)

Excludes trading and bulk Refining sales.

1   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charge of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases. Operating cash flow before changes in working capital at replacement cost provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the inventory effect and replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

Form 20-F 2021   TotalEnergies

   13

Results (in millions of dollars except ROACE)

    

2021

    

2020

    

2019

External sales

 

80,288

 

63,451

 

87,280

Operating income(a)

 

2,359

 

1,441

 

2,052

Net income (loss) from equity affiliates and other items

 

108

 

37

 

101

Tax on net operating income

 

(738)

 

(515)

 

(598)

Net operating income(a)

 

1,729

 

963

 

1,555

Adjustments affecting net operating income

 

(111)

 

261

 

98

Adjusted net operating income(b)

 

1,618

 

1,224

 

1,653

Organic investments(c)

 

1,074

 

814

 

969

Net acquisitions(d)

 

(151)

 

86

 

162

Net investments(e)

 

923

 

900

 

1,131

ROACE

 

18.4%

14.3%

22.3%

(a)

For the definitions of “operating income” and “net operating income”, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

(b)

Adjusted for special items, inventory valuation effect and the effect of changes in fair value. See Note 3 to the Consolidated Financial Statements (starting on page F-19).

(c)

Organic investments = net investments excluding acquisitions, asset sales and other operations with non-controlling interests. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

(d)

Net acquisitions = acquisitions - assets sales - other operations with non-controlling interests.

(e)

Net investments = organic investments + net acquisitions. For additional information on investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference.

2021 vs. 2020

Petroleum product sales showed year-on-year growth of 2% for the full-year 2021, due to the improvement in the health situation and the global economic rebound.  This increase reflects mainly the recovery in retail activity and, at the end of 2021, of the aviation activity.

External sales for the Marketing & Services segment in 2021 were $80,288 million, 1.3 times greater than $63,451 million in 2020.

Adjusted net operating income for the Marketing & Services segment was $1,618 million for the full-year 2021, an increase of 32% compared to $1,224 million for the full-year 2020. Adjusted net operating income for this segment excludes any after-tax inventory valuation effect and special items. For the full-year 2021, the exclusion of the inventory valuation effect had a negative impact of $236 million on the segment’s adjusted net operating income, compared to a positive impact of $137 million for the full-year 2020. For the full-year 2021, the exclusion of special items had a positive impact of $125 million on the segment’s adjusted net operating income, compared to a positive impact of $124 million for the full-year 2020.

For the full-year 2021, the Marketing & Services segment’s operating cash flow before working capital changes without financial charges (DACF)1 was $2,556 million, an increase of 17% compared to $2,180 million for the full-year 2020. These results are back to levels comparable to those of the pre-crisis period, despite a 19% drop in sales in 2021 compared to 2019 (most of which is linked to the strategy to arbitrage low margin sales).

For the full-year 2021, the Marketing & Services segment’s cash flow from operating activities excluding financial charges, except those related to leases was $2,333 million, an increase of 11% compared to $2,101 million for the full-year 2020.

In this context, the Marketing & Services segment’s ROACE for the full-year 2021 was 18.4% compared to 14.3% for the full-year 2020.

For information on the Marketing & Services segment’s investments, refer to point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference. See also “- 5.4 Liquidity and Capital Resources”, below.

2020 vs. 2019

Petroleum product sales volumes decreased by 20% in 2020 compared to 2019, in response to the significant slowdown in global activity related to the COVID-19 pandemic. Aviation and marine activities remain severely affected in this context; however, the decline in retail sales was mitigated by network growth in Angola, Saudi Arabia, Brazil and Mexico.

External sales for the Marketing & Services segment in 2020 were $63,451 million compared to $87,280 million in 2019, a decrease of 27%.

The Marketing & Services segment’s adjusted net operating income decreased by 26% in 2020 to $1,224 million compared to $1,653 million in 2019. Adjusted net operating income for the Marketing & Services segment excludes any after-tax inventory valuation effect and special items. For the full-year 2020, the exclusion of the inventory valuation effect had a positive impact of $137 million on the segment’s adjusted net operating income, compared to a positive impact of $14 million for the full-year 2019. For the full-year 2020, the exclusion of special items had a positive impact of $124 million on the segment’s adjusted net operating income, compared to a positive impact of $84 million for the full-year 2019.

For the full-year 2020, the Marketing & Services segment’s operating cash flow before working capital changes without financial charges (DACF) $2,180 million, a decrease of 14% compared to $2,546 million for the full-year 2019.

For the full-year 2020, the segment’s cash flow from operating activities excluding financial charges, except those related to leases was $2,101 million, a decrease of 19% compared to $2,604 million for the full-year 2019.

In this context, the Marketing & Services segment’s ROACE for the full-year 2020 was 14.3% compared to 22.3% for the full-year 2019.

1   DACF = debt adjusted cash flow. Operating cash flow before working capital changes without financial charge of the segment is defined as the cash flow from operating activities before changes in working capital at replacement cost, without financial charges except those related to leases. Operating cash flow before changes in working capital at replacement cost provides information on underlying cash flow without the short-term impacts of changes in inventory and other working capital elements at replacement cost. For information on the inventory effect and replacement cost method, refer to Note 3 to the Consolidated Financial Statements (starting on page F-19).

TotalEnergies   Form 20-F 2021

   14   

5.4    Liquidity and capital resources

(M$)

    

2021

    

2020

    

2019

Cash flow from operating activities

 

30,410

 

14,803

 

24,685

Including (increase) decrease in working capital

 

(616)

 

1,869

 

(1,718)

Cash flow used in investing activities

 

(13,656)

 

(13,079)

 

(17,177)

Total expenditures

 

(16,589)

 

(15,534)

 

(19,237)

Total divestments

 

2,933

 

2,455

 

2,060

Cash flow from / (used) in financing activities

 

(25,497)

 

1,398

 

(7,709)

Net increase (decrease) in cash and cash equivalents

 

(8,743)

 

3,122

 

(201)

Effect of exchange rates

 

(1,183)

 

794

 

(354)

Cash and cash equivalents at the beginning of the period

 

31,268

 

27,352

 

27,907

Cash and cash equivalents at the end of the period

 

21,342

 

31,268

 

27,352

TotalEnergies’ cash requirements for working capital, capital expenditures, acquisitions and dividend payments over the past three years were financed primarily by a combination of funds generated from operations, net borrowings and divestments of assets. In the current environment, TotalEnergies expects its external debt to be principally financed from the international debt capital markets. TotalEnergies continually monitors the balance between cash flow from operating activities and net expenditures. In TotalEnergies SE’s opinion, its working capital is sufficient for its present requirements.

5.4.1    Cash flow

Cash flow from operating activities in 2021 was $30,410 million compared to $14,803 million in 2020 and $24,685 million in 2019. The increase of $15,607 million from 2020 to 2021 was mainly due to the increase in net income.

Cash flow used in investing activities in 2021 was $13,656 million compared to $13,079 million in 2020 and $17,177 million in 2019. The increase of $577 million from 2020 to 2021 was mainly due to higher expenditures in the Exploration & Production segment. The decrease of $4,098 million from 2019 to 2020 was mainly due to lower expenditures in the Exploration & Production segment and the Integrated Gas, Power & Renewables segment. Total expenditures in 2021 were $16,589 million compared to $15,534 million in 2020 and $19,237 million in 2019. During 2021, 44% of the expenditures were made by the Exploration & Production segment (as compared to 44% in 2020 and 47% in 2019), 38% by the Integrated Gas, Power & Renewables segment (as compared to 40% in 2020 and 37% in 2019), 10% by the Refining & Chemicals segment (compared to 9% in 2020 and 9% in 2019) and 7% by the Marketing & Services segment (compared to 7% in 2020 and 7% in 2019). The main source of funding for the expenditures was cash from operating activities and net repayment in 2021 and cash from operating activities and issuances of non-current debt in 2020 and 2019.

For additional information on expenditures, please refer to the discussions in “- 5.1 Overview”, “- 5.2 TotalEnergies results 2019-2021” and “- 5.3 Business segment reporting”, above, and point 1.6 of chapter 1 of the Universal Registration Document 2021 (starting on page 30), incorporated herein by reference and Note 15.1.D to the Consolidated Financial Statements on page F-71.

Divestments, based on selling price and net of cash sold, in 2021 were $2,933 million compared to $2,455 million in 2020 and $2,060 million in 2019. In 2021, TotalEnergies’ principal divestments were assets sales of $2,652 million compared to $1,539 million in 2020, consisting mainly of the sales described in “- 5.2 TotalEnergies results 2019-2021” above.

Cash flow from/(used in) financing activities in 2021 was $(25,497) million compared to $1,398 million in 2020 and $(7,709) million in 2019. The significant use of cash in financing activities in 2021 compared to a net inflow in 2020 was primarily due to the net repayment of non-current debt of $(359) million in 2021 compared to a net issuance of $15,800 million in 2020, to a significant increase in current financial assets and liabilities ($8,075 million in 2021 compared to $604 million in 2020) due to an increase in initial margins held as part of TotalEnergies’ activities on organized markets and to the increase in buyback of shares ($1,823 million in 2021 compared to $611 million in 2020). The decrease in cash flow used in financing activities in 2020 compared to 2019 was primarily due to the decrease in buyback of shares ($611 million in 2020 compared to $2,810 million in 2019), the increase in the net issuance of non-current debt ($15,800 million in 2020 compared to $8,131 million in 2019) and the increase in current financial assets and liabilities ($604 million in 2020 compared to $536 million in 2019).

5.4.2    Indebtedness

TotalEnergies’ non-current financial debt at year-end 2021 was $49,512 million, compared to $60,203 million at year-end 2020 and $47,773 million at year-end 2019. For further information on the level of borrowing and the type of financial instruments, including maturity profile of debt and currency and interest rate structure, see point 1.10.2 of chapter 1 in the Universal Registration Document 2021 (starting on page 55), incorporated herein by reference and Note 15 (“Financial structure and financial costs”) to the Consolidated Financial Statements starting on page F-67. For further information on the treasury policies, including the use of instruments for hedging purposes and the currencies in which cash and cash equivalents are held, see “Item 11. Quantitative and Qualitative Disclosures About Market Risk”.  

Cash and cash equivalents at year-end 2021 were $21,342 million compared to $31,268 million at year-end 2020 and $27,352 million at year-end 2019.

5.4.3    Shareholders’ equity

Shareholders’ equity at year-end 2021 was $114,999 million, compared to $106,085 million at year-end 2020 and $119,305 million at year-end 2019.

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Changes in shareholders’ equity in 2021 were primarily due to the impacts of comprehensive income, dividend payments, the buy-back of TotalEnergies SE shares and the issuance of perpetual subordinated notes issued by TotalEnergies SE in January 2021, in two tranches of €1.5 billion (callable in 2027 and 2032), recorded as equity for approximately €3.3 billion (or approximately $3.6 billion using the €/$ exchange rate on January 29, 2021 of €1=$1.2135 as released by the Board of Governors of the Federal Reserve System February 1, 2021).

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Changes in shareholders’ equity in 2020 were primarily due to the impacts of comprehensive income, dividend payments, the buy-back of TotalEnergies SE shares and the issuance of common shares of TotalEnergies SE and perpetual subordinated notes

Form 20-F 2021   TotalEnergies

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issued by TotalEnergies SE in September 2020 (callable in 2030) recorded as equity for €1 billion (or approximately $1.2 billion using the €/$ exchange rate on September 4, 2020 of €1 = $1.1820 as released by the Board of Governors of the Federal Reserve System on September 7, 2020).

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Changes in shareholders’ equity in 2019 were primarily due to the impacts of comprehensive income, dividend payments, the buy-back of TotalEnergies SE shares and the issuance of common shares of TotalEnergies SE and perpetual subordinated notes in April 2019 (callable in 2024) recorded as equity for €1.5 billion (or approximately $1.7 billion using the €/$ exchange rate on April 19, 2019 of €1 = $1.1246 as relea