Annual Report and Form 20-F 2024 I 2
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 20-F
ANNUAL REPORT
PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934
for the fiscal year ended December 31, 2024
Commission File Number 001-15106
Petróleo Brasileiro S.A. — Petrobras
(Exact name of registrant as specified in its charter)
Brazilian Petroleum Corporation — Petrobras
(Translation of registrant’s name into English)
The Federative Republic of Brazil
(Jurisdiction of incorporation or organization)
Avenida Henrique Valadares, 28 - 20231-030 - Rio de Janeiro – RJ - Brazil
(Address of principal executive offices)
Fernando Sabbi Melgarejo
Chief Financial Officer and Chief Investor Relations Officer
(55 21) 3224-2401 — dfinri@petrobras.com.br
Avenida Henrique Valadares, 28, Tower A, 18th floor - 20231-030 - Rio de Janeiro – RJ - Brazil
(Name, telephone, e-mail 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:
Petrobras Common Shares, without par value*
PBR/PBRA
New York Stock Exchange*
Petrobras American Depositary Shares, or ADSs
(evidenced by American Depositary Receipts, or ADRs), each
representing two Common Shares
PBR/PBRA
New York Stock Exchange
Petrobras Preferred Shares, without par value*
PBR/PBRA
New York Stock Exchange*
Petrobras American Depositary Shares
(as evidenced by American Depositary Receipts), each representing
two Preferred Shares
PBR/PBRA
New York Stock Exchange
8.750% Global Notes due 2026, issued by PGF
PBR
New York Stock Exchange
7.375% Global Notes due 2027, issued by PGF
PBR
New York Stock Exchange
5.999% Global Notes due 2028, issued by PGF
PBR
New York Stock Exchange
5.750% Global Notes due 2029, issued by PGF
PBR
New York Stock Exchange
5.093% Global Notes due 2030, issued by PGF
PBR
New York Stock Exchange
5.600% Global Notes due 2031, issued by PGF
6.500% Global Notes due 2033, issued by PGF
PBR
New York Stock Exchange
New York Stock Exchange
6.000% Global Notes due 2035, issued by PGF
PBR
New York Stock Exchange
6.875% Global Notes due 2040, issued by PGF (successor to PifCo)
PBR
New York Stock Exchange
6.750% Global Notes due 2041, issued by PGF (successor to Pifco)
PBR
New York Stock Exchange
5.625% Global Notes due 2043, issued by PGF
PBR
New York Stock Exchange
7.250% Global Notes due 2044, issued by PGF
PBR
New York Stock Exchange
6.900% Global Notes due 2049, issued by PGF
PBR
New York Stock Exchange
6.750% Global Notes due 2050, issued by PGF
PBR
New York Stock Exchange
5.500% Global Notes due 2051, issued by PGF
PBR
New York Stock Exchange
6.850% Global Notes due 2115, issued by PGF
PBR
New York Stock Exchange
_________________
*
Not for trading, but only in connection with the registration of American Depositary Shares pursuant to the requirements of the New
York Stock Exchange.
Annual Report and Form 20-F 2024 I 3
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
The number of outstanding shares of each class of stock as of December 31, 2024 was:
7,442,231,382 Petrobras Common Shares, without par value
5,446,501,379 Petrobras Preferred Shares, without par value
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. (Check one):
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. ☒
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant
included in the filing reflect the correction of an error to previously issued financial statements. ☐
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based
compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to § 240.10D-1(b). ☐
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 ☒
Annual Report and Form 20-F 2024 I 4
Table of Contents
Disclaimer
6
Glossary
9
About us
25
About us
26
Overview
27
2024 Highlights
30
Risks
32
Risks
33
Cybersecurity Framework and Risk Management
58
Our Business
62
Exploration & Production
63
Refining, Transportation & Marketing
102
Gas & Low Carbon Energies
125
Mergers and Acquisitions
144
External Business Environment
147
Strategic and Business Plans
153
Strategic Plan 2050 and Business Plan 2025-2029
154
Research, Development and Innovation
165
Environment, Social and Governance
168
Environment
169
Social Responsibility
176
Corporate Governance
183
Operating and Financial Review and Prospects
190
Consolidated Financial Performance
191
Financial Performance by Business Segment
198
Liquidity and Capital Resources
200
Annual Report and Form 20-F 2024 I 5
Management and Employees
214
Management
215
Employees
236
Compliance and Internal Controls
245
Compliance
246
Related Party Transactions
251
Controls and Procedures
253
Ombudsman and Internal Investigations
254
Shareholder Information
255
Listing
256
Shares and Shareholders
257
Shareholders’ Rights
264
Shareholder Remuneration
269
Additional Information for Non-Brazilian Shareholders
274
Legal and Tax
277
Regulation
278
Material Contracts
285
Legal Proceedings
289
Tax
296
Additional Information
317
List of Exhibits
318
Signatures
324
Abbreviations
325
Conversion table
327
Cross-Reference to Form 20-F
328
Financial Statements
331
Annual Report and Form 20-F 2024 I 6
Disclaimer
Disclaimer
We have presented the information in this annual report and Form 20-F in a manner consistent with how we
view our business. In order to facilitate your review, this annual report and Form 20-F for the year ended
December 31, 2024 (referred to herein as our “annual report”) has a cross-reference guide to SEC Form 20-F
under “Cross-Reference to Form 20-F”.
Unless the context otherwise indicates, please consider this report the annual report of Petróleo Brasileiro
S.A. – Petrobras. Unless the context otherwise requires, the terms “Petrobras,” “the Company,” “our company,”
“we,” “us” and “our” refer to Petróleo Brasileiro S.A. – Petrobras and its consolidated subsidiaries, joint
operations and structured entities.
Our audited consolidated financial statements, presented in U.S. dollars, included in this annual report and
the financial information contained in this annual report that is derived therefrom are prepared in
accordance with the IFRS Accounting Standards, as issued by the International Accounting Standards Board
(“IASB”).
Our functional currency and the functional currency of all of our Brazilian subsidiaries is the Brazilian real
and the functional currency of most of our entities that operate outside Brazil, such as Petrobras Global
Finance B.V. or PGF, is the U.S. dollar. We have selected the U.S. dollar as our presentation currency to
facilitate a more direct comparison to other oil and gas companies.
In this annual report, references to “real,” “reais” or “R$” are to Brazilian reais and references to “U.S. dollars”
or “US$” are to United States dollars.
The information available on our website, or on any website referenced herein, is not and shall not be deemed
to be incorporated by reference to this annual report.
The 2024 GHG emissions performance results presented in this annual report will be subject to third party
verification, and although we do not expect significant differences, the audited results may differ from the
results presented herein.
Forward-Looking Statements
This annual report includes forward-looking statements that are not based on historical facts and are not
assurances of future results. The forward-looking statements contained in this annual report, which
address our expected business and financial performance, among other matters, contain words such as
“believe,” “expect,” “estimate,” “anticipate,” “intend,” “plan,” “aim,” “will,” “may,” “should,” “could,” “would,”
“likely,” “potential” and similar expressions (which are not the exclusive means of identifying such forward-
looking statements).
Readers are cautioned not to place undue reliance on these forward-looking statements, which speak
only as of the date on which they are made. There is no assurance that the expected events, trends or
results will actually occur.
We have made forward-looking statements that address, among other things:
_ Our marketing and expansion strategy;
_ Our exploration and production activities, including drilling;
_ Our activities related to refining, import, export, transportation of oil, natural gas and oil products,
petrochemicals, power generation, biofuels and other sources of renewable energy;
Annual Report and Form 20-F 2024 I 7
Disclaimer
_ Our commitment with respect to ESG practices and low carbon and environmental sustainability;
_ Our projected and targeted capital expenditures, commitments and revenues;
_ Our liquidity and sources of funding;
_ Our pricing strategy and development of additional revenue sources; and
_ The impact, including cost, of acquisitions and divestments.
Our forward-looking statements are not guarantees of future performance and are subject to assumptions
that may prove incorrect and to risks and uncertainties that are difficult to predict. Our actual results could
differ materially from those expressed or forecast in any forward-looking statements as a result of a variety
of assumptions and factors. These factors include, but are not limited to, the following:
_ Our ability to obtain financing;
_ General economic and business conditions, including crude oil and other commodity prices, refining
margins and prevailing exchange rates;
_ Global economic conditions;
_ Our ability to find, acquire or gain access to additional reserves and to develop our current reserves
successfully;
_ Uncertainties inherent in making estimates of our oil and gas reserves, including recently discovered
oil and gas reserves;
_ Competition;
_ Technical difficulties in the operation of our equipment and the provision of our services;
_ Changes in, or failure to comply with, laws or regulations, including with respect to fraudulent
activity, corruption and bribery;
_ Receipt of governmental approvals and licenses;
_ International and Brazilian political, economic and social developments, including the role of the
Brazilian government, as our controlling shareholder, in our business;
_ Natural disasters, accidents, military operations, acts of sabotage, wars or embargoes;
_ Cybersecurity threats, breaches, and disruptions;
_ Global health crises, such as the COVID-19 pandemic;
_ The impact of expanded regional or global conflict, including the conflict between Russia and
Ukraine, and the conflict in the Middle East;
_ The cost and availability of adequate insurance coverage;
_ Our ability to successfully implement acquisitions, partnerships or asset sales in our portfolio
management program;
_ Our ability to successfully implement our Strategic Plan 2050 and Business Plan 2025-2029, whether
those strategic and business plans remains in place, and the direction of any subsequent strategic
and business plans;
_ The outcome of ongoing corruption investigations and any new facts or information that may arise
in relation to past investigations related to alleged irregularities or corruption;
_ The effectiveness of our risk management policies and procedures, including operational risk;
_ Potential changes to the composition of our Board of Directors and our management team; and
Annual Report and Form 20-F 2024 I 8
Disclaimer
_ Litigation, such as class actions or enforcement or other proceedings brought by governmental and
regulatory agencies.
For additional information on factors that could cause our actual results to differ from expectations
reflected in forward-looking statements, see “Risks” in this annual report.
All forward-looking statements attributed to us or a person acting on our behalf are qualified in their
entirety by this cautionary statement. We undertake no obligation to publicly update or revise any forward-
looking statements, whether as a result of new information or future events or for any other reason.
The crude oil and natural gas reserve data presented or described in this annual report are only estimates,
which involve some degree of uncertainty, and our actual production, revenues and expenditures with
respect to our reserves may materially differ from these estimates.
Documents on Display
We are subject to the information requirements of the Exchange Act. For further information about
obtaining copies of our public filings at the NYSE, please call +1 (212) 656-4050. Our SEC filings are
available to the public at the SEC’s website at www.sec.gov and at our website at
www.petrobras.com.br/ir. You may also inspect our reports and other information at the offices of the
New York Stock Exchange, or NYSE, at 11 Wall Street, New York, New York 10005, on which our ADSs
are listed.
We also furnish reports on Form 6-K to the SEC containing our unaudited consolidated interim financial
statements and other financial information of our company.
We also file audited consolidated financial statements, unaudited consolidated interim financial
information and other periodic reports with the CVM.
Annual Report and Form 20-F 2024 I 9
Glossary
Glossary
Glossary of Certain Terms used in this Annual Report
Unless the context indicates otherwise, the following terms are defined as follows:
ACL
Ambiente de Comercialização Livre (Free Market Environment). Market segment in
which the purchase and sale of electrical energy are the subject of freely negotiated
bilateral agreements, according to specific market rules and procedures.
ACR
Ambiente de Comercialização Regulado (Regulated Market Environment). Market
segment in which the purchase and sale of electrical energy between selling agents
and distribution agents is preceded by a bidding process, except for cases provided by
law, according to specific market rules and procedures.
ADR
American Depositary Receipt.
ADS
American Depositary Share.
AIP
The Acordo de Individualização da Produção (Productions Individualization
Agreement). The AIP applies in situations where the reservoirs extend beyond the
areas granted or contracted, as regulated by ANP.
AMS
The AMS (Assistência Multidisciplinar de Saúde) Plan, that continues as the registered
name in the Agência Nacional de Saúde (National Health Agency) in Brazil, is the
official name of our health care plan.
ANA
The Agência Nacional de Águas e Saneamento Básico (National Water and Sanitation
Agency).
ANEEL
The Agência Nacional de Energia Elétrica (Brazilian Electricity Regulatory Agency).
ANM
The Agência Nacional de Mineração (National Mining Agency).
ANP
The Agência Nacional de Petróleo, Gás Natural e Biocombustíveis (Brazilian National
Petroleum, Natural Gas and Biofuels Agency) is the federal agency that regulates the
oil, natural gas and renewable fuels industry in Brazil.
Annual Report and Form 20-F 2024 I 10
Glossary
ANPD
The Autoridade Nacional de Proteção de Dados (National Data Protection Authority).
ANTAQ
The Agência Nacional de Transportes Aquaviários (Brazilian National Agency of
Waterway Transportation).
ANVISA
The Agência Nacional de Vigilância Sanitária (Brazilian National Agency of Health
Surveillance).
API GRAVITY
Standard measure of oil density developed by the American Petroleum Institute.
APS or Saúde
Petrobras
The Associação Petrobras de Saúde (Petrobras Health Association), a non-profit
association that operates our supplementary health care plan (Saúde Petrobras) since
2021, whose trade name is Saúde Petrobras.
B3
Brasil, Bolsa, Balcão, the Brazilian Stock Exchange.
Barrels
Standard measure of crude oil volume.
Biofuel
Any fuel derived from the conversion of biomass as raw material (vegetable oils, algae
material, crops or animal wastes, etc.) and/or produced through biological processes,
such as fermentation and others.
BioQav
Aviation turbine fuel used to power aircraft, produced from several biomass sources in
different production processes, also known as “biojet”, “biokerosine” or “SAF”
(sustainable aviation fuel) and named by the ANP as “Alternative Jet Fuel”, which must
be added to conventional jet fuel up to a maximum limit that varies from 10% to 50% by
volume depending on the production process, as defined in ASTM (American Society for
Testing and Materials) Annex D-7566 and ANP Resolution No. 778/2019.
BNDES
Banco Nacional de Desenvolvimento Econômico e Social (Brazilian National
Development Bank).
Business Plan 2025-29
Business Plan 2025-2029.
Braskem
Braskem S.A. is currently the largest producer of thermoplastic resins in the Americas
and the largest producer of polypropylene in the United States. Its production focuses
on polyethylene (PE), polypropylene (PP) and polyvinylchloride (PVC) resins, in addition
Annual Report and Form 20-F 2024 I 11
Glossary
to basic chemical inputs such as ethylene, propylene, butadiene, benzene, toluene,
chlorine, soda, and solvents, among others. Together, they make up one of the most
comprehensive portfolios in the industry, by also including the green polyethylene
produced from sugarcane from 100% renewable sources.
Brazilian Treasury
The Tesouro Nacional (Brazilian National Treasury) is a Secretariat of the Ministry of
Finance, responsible for financial programming, accounting, management of the
federal public debt, federal financial and securities assets and the Brazilian federal
government’s financial relationship with states and municipalities in Brazil. The
Brazilian National Treasury's mission is to seek fiscal balance through efficient,
proactive and transparent management of public accounts and act in the structuring of
financing channels that can make sustainable public interest policies viable,
contributing to Brazil's intertemporal economic and social development.
Brent Crude Oil
A major trading classification of light crude oil that serves as a major benchmark price
for commercialization of crude oil worldwide.
CADE
Conselho Administrativo de Defesa Econômica (Administrative Council for Economic
Defense).
Câmara de Arbitragem
do Mercado
An arbitration chamber governed and maintained by B3.
Capital Expenditures
or CAPEX
Capital expenditures based on the cost assumptions and financial methodology
adopted in our Strategic Plan, which includes acquisition of PP&E and intangible assets,
acquisition of equity interests, as well as other items that do not necessarily qualify as
cash flows used in investing activities, comprising geological and geophysical expenses,
research and development expenses, pre-operating charges, purchase of property,
plant and equipment on credit and borrowing costs directly attributable to works in
progress.
Carbon Intensity in
E&P
E&P GHG Emissions Intensity. GHG emissions, in terms of CO₂e, from E&P activities in
relation to the total oil and gas operated production (wellhead) registered in the same
period. Scope 1 and 2 GHG emissions are considered. This indicator represents the rate
of GHG emissions per barrel of oil equivalent produced. It covers oil and gas exploration
and production activities under operational control, and is used to analyze the carbon
performance of the assets in our current and future portfolio.
Carbon Intensity in
Refining
Refining GHG Emissions Intensity represents GHG emissions, in terms of CO₂e, from
Refining activities in relation to Complexity Weighted Tone (CWT). This indicator covers
refining activities with operational control and composes the analysis of the carbon
performance of the assets in our current and future portfolio.
Annual Report and Form 20-F 2024 I 12
Glossary
CBA
Acordo Coletivo de Trabalho (Collective Bargaining Agreement).
CCUS
Carbon Capture, Utilization and Storage.
Central Bank of Brazil
The Banco Central do Brasil.
Central Depositária
The Central Depositária de Ativos e de Registro de Operações do Mercado, which
serves as the custodian of our common and preferred shares (including those
represented by ADSs) on behalf of our shareholders.
CEO
Chief Executive Officer.
CFO
Chief Financial Officer.
CMN
The Conselho Monetário Nacional (National Monetary Council) is the highest authority
of the Brazilian financial system, responsible for the formulation of the Brazilian
currency, exchange and credit policy, and for the supervision of financial institutions.
CNODC
CNODC Brasil Petróleo e Gás Ltda., a subsidiary in Brazil of the China National
Petroleum Corporation (CNPC).
CNOOC
China National Offshore Oil Corporation (CNOOC), or its subsidiary that operates in
Brazil, CNOOC Petroleum Brasil Ltda.
CNPC
China National Petroleum Corporation (CNPC).
CNPE
The Conselho Nacional de Política Energética (National Energy Policy Council), chaired
by the Minister of Mines and Energy, is an advisory body to the Brazilian President for
the formulation of energy policies and guidelines.
CONAMA
Conselho Nacional do Meio Ambiente (National Council for the Environment in Brazil).
Condensate
Hydrocarbons that are in the gaseous phase at reservoir conditions but condense into
liquid as they travel up the wellbore and reach separator conditions.
Annual Report and Form 20-F 2024 I 13
Glossary
CVM
The Comissão de Valores Mobiliários (Brazilian Securities and Exchange Commission).
CWT
Complexity Weighted Tone, which represents a measure of activity, similar to UEDC
(Utilized Equivalent Distillation Capacity), which considers the potential for GHG
emissions, equivalent to distillation, per process unit, allowing better comparability
between refineries of different complexities.
D&M
DeGolyer and MacNaughton, an independent petroleum engineer consulting firm that
conducts reserves evaluation of part of our proved crude oil, Condensate and natural
gas reserves.
Deepwater
Between 300 and 1,500 meters (984 and 4,921 feet) deep.
Depositary
JPMorgan.
Digital Twin
Digital representation of a physical asset, system or process. It uses real-time data, AI
and simulations to mirror the physical counterpart's behavior and performance,
allowing for monitoring, analysis and optimization. This technology is widely used in
various industries to improve efficiency, predict maintenance needs and enhance
decision-making.
Distillation
Physical process involving vaporization and condensation, whereby petroleum is
separated (refined) into oil products.
E&P or Exploration &
Production
Exploration & Production is our business segment that covers the activities of
exploration, development and production of crude oil, NGL and natural gas in Brazil
and abroad.
EPCI
Engineering, Procurement, Construction and Installation, a form of contracting
arrangement common within the offshore industry.
ESG
Environmental, Social and Governance.
ESI
Energy Sustainability Index recognizes the impact of these low carbon energy sources,
at a regional or country-level, without losing sight of the consumption-side efficiency
of refinery process units which refiners understand is key for long term carbon
reduction worldwide.
Annual Report and Form 20-F 2024 I 14
Glossary
EWT
Extended well test.
Exchange Act
Securities Exchange Act of 1934, as amended.
Fitch
Fitch Ratings Inc., a credit rating agency.
FPSO
Floating production, storage and offloading unit.
G&LCE or Gas & Low
Carbon Energies
Gas & Low Carbon Energies is our business segment that covers the activities of
logistics and trading of natural gas and electricity, the transportation and trading of
LNG, the generation of electricity by means of thermoelectric power plants, as well as
natural gas processing. It also includes renewable energy businesses, low carbon
services (carbon capture, utilization and storage) and the production of biodiesel and
its co-products.
BOAVENTURA or
BOAVENTURA Cluster
(formerly GASLUB)
Located in southeastern Brazil (Itaboraí, in the state of Rio de Janeiro), the
BOAVENTURA Cluster, formerly GASLUB, is comprised of the UPGNs and other
underlying utilities.
GASBOL
The 557 km gas pipeline system in the Bolivian section of the Bolivia-Brazil gas
pipeline.
Gaspetro
Petrobras Gás S.A., or Gaspetro, was our subsidiary from which we divested in July
2022, in which we had a 51% equity interest and a holding company with equity
interests in 18 Brazilian local gas distribution companies, with Mitsui holding the
remaining 49% interest.
GHG
Greenhouse gas.
Gross revenues
Gross revenues represent Sales revenues plus sales taxes, which mainly includes the
following taxes imposed in Brazil: Contribution for Intervention in the Economic
Domain (CIDE), social contributions PIS and COFINS, and tax over services and goods
(ICMS).
GSA
Long-term Gas Supply Agreement entered into with the Bolivian state-owned
company Yacimientos Petroliferos Fiscales Bolivianos.
Annual Report and Form 20-F 2024 I 15
Glossary
GTB or Gas
Transboliviano S.A.
Gas Transboliviano S.A. is a company operating in the natural gas transportation
industry, responsible for the administration and operation of the 557 km gas pipeline
system in GASBOL, with an installed capacity of 30 million m³/d. GTB is connected to
TBG on the Bolivia-Brazil border in the state of Mato Grosso do Sul.
HDT or Hydrotreating
Process widely used in the oil refining industry to remove heteroatoms such as sulfur
and nitrogen from gasoline, kerosene and/or diesel in the presence of specific
catalysts, hydrogen and adequate conditions of temperature and pressure. The aim is
to adjust composition to comply with fuel specifications.
HSE
Health, Safety and Environment.
IAGEE
Índice de Atendimento às Metas de Gases do Efeito Estufa (Greenhouse Gas Emissions
Target Achievement Indicator). The indicator of compliance with the Greenhouse Gas
Emissions Targets.
IASB
International Accounting Standards Board.
IBAMA
The Instituto Brasileiro do Meio Ambiente e dos Recursos Naturais Renováveis
(Brazilian Institute of the Environment and Renewable Natural Resources).
Ibovespa or IBOV
The gross total return index weighted by free float market cap and comprised of the
most liquid stocks traded on the B3. It was created in 1968.
ICMBio
The Instituto Chico Mendes de Conservação da Biodiversidade (Chico Mendes Institute
for Biodiversity Conservation).
ICMS
Brazilian tax over services and goods.
IPHAN
The Instituto do Patrimônio Histórico e Artístico Nacional (National Institute of
Historic and Artistic Heritage).
IFRS Accounting
Standards
IFRS Accounting Standards as issued by the International Accounting Standards
Board.
IOF
Imposto sobre Operações Financeiras (Brazilian taxes over financial transactions).
Annual Report and Form 20-F 2024 I 16
Glossary
IPCA
The Índice Nacional de Preços ao Consumidor Amplo (National Consumer Price Index).
JPMorgan
JPMorgan Chase Bank, N.A.
Just energy transition
A just energy transition is an energy transition committed to promoting equity and
social participation, minimizing negative impacts on communities, workers, companies
and social segments vulnerable to transformations in the energy system and
maximizing opportunities for socioeconomic development, increasing the
competitiveness of the productive sector and combating inequality and poverty, at
international, regional and local levels.
KPI
Key Performance Indicators.
Lava Jato
Operação Lava Jato (Lava Jato Operation), as detailed in “Legal and Tax – Legal
Proceedings – Lava Jato Investigation” in this annual report.
LIBOR
The London Interbank Offered Rate was a benchmark interest rate at which major
global banks lend to one another in the international interbank market for short-term
loans until June 30, 2023.
Lifting Cost
An indicator that represents the unit lifting cost of an equivalent barrel, considering
the relationship between costs and production. It includes expenses for the execution
and maintenance of production processes. Costs related to the chartering of third-
party platforms, production taxes, depreciation, depletion, and amortization are not
considered in this indicator.
LNG
Liquefied natural gas.
LPG
Liquefied petroleum gas, which is a mixture of hydrocarbons with up to four carbon
atoms.
LUBNOR
Refinery Lubrificantes e Derivados de Petróleo do Nordeste.
Partially state-owned
Company
Means a mixed joint stock corporation (public and private shareholders).
Annual Report and Form 20-F 2024 I 17
Glossary
MME
The Ministério de Minas e Energia (Ministry of Mines and Energy) of Brazil.
Moody’s
Moody’s Investors Service, Inc., a credit rating agency.
MTF
Euro Multilateral trading Facility.
Natural Gasoline (C5+)
Natural Gasoline C5+ is a NGL produced at natural gas processing plants with a vapor
pressure intermediate between Condensate and LPG, which may compose a gasoline
blend.
Nelson Complexity
Index or NCI
The Nelson Complexity Index or NCI is a measure of the sophistication of an oil
refinery, where more complex refineries are able to process heavier oils and produce
lighter and more valuable products from a barrel of oil. The NCI is measured on a scale
of one to 20, where higher numbers correspond to more complex and expensive
refineries.
New frontier areas
Geographic areas that have not yet been widely explored for the production of oil and
natural gas.
NGL
Natural Gas Liquids (NGL), the liquid resulting from the processing of natural gas and
containing the heavier gaseous hydrocarbons.
NTS
Nova Transportadora do Sudeste S.A.
NYSE
The New York Stock Exchange.
NYSE Arca Oil Index or
Arca Oil
(formerly AMEX Oil
Index)
The NYSE Arca Oil Index, formerly the AMEX Oil Index, ticker symbol XOI, is a price-
weighted index of the leading companies involved in petroleum exploration,
production and development. It measures the oil industry’s performance through
changes in the sum of the prices of component stocks. The index was developed with a
base level of 125 as of August 27, 1984.
OCF
Operating Cash Flow (net cash provided by operating activities).
Oil
Crude oil, including NGLs and Condensates.
Annual Report and Form 20-F 2024 I 18
Glossary
Oil Products
Petroleum products, produced through processing in refineries (diesel, gasoline, LPG
and other products).
ONS
The Operador Nacional do Sistema Elétrico (National Electric System Operator) of
Brazil.
Operated Production
Production of a gas or oil field, including Petrobras’ and partners’ respective shares.
Operating Income
Equivalent to the caption income before net finance expense, results of equity-
accounted investments and income taxes derived in our audited consolidated financial
statements.
Organic Reserves
Replacement Ratio or
Organic RRR
Measures the amount of Proved Reserves added to a company’s reserve base during
the year, excluding disposals and acquisitions of Proved Reserves, relative to the
amount of oil and gas produced.
OSRL
Oil Spill Response Limited.
PDV
Programa de Desligamento Voluntário (Voluntary Severance Program).
Petrochemicals
Chemicals mainly obtained from oil and natural gas (as opposed to fuels) such as
ethane, ethylene, propane, propylene, benzene, xylenes, polypropylene, polyethylene
and others. Renewable resources can also be used as raw materials.
Petros
Fundação Petros de Seguridade Social, Petrobras’ employee pension fund.
PGF
Petrobras Global Finance B.V.
PifCo
Petrobras International Finance Company S.A.
PLR
The Participação nos Lucros e Resultados (Profit Sharing Program) is a remuneration
model based on the division of profits with our employees. Our PLR is governed by
Brazilian Law No.10,101/2000 and follows the guidelines of the SEST. These annual
guidelines define various aspects of this type of reward, such as format, flow,
governance, financial and remuneration limits.
Annual Report and Form 20-F 2024 I 19
Glossary
PLSV
Pipe laying support vessel.
Post-salt
A geological formation containing oil or natural gas deposits located above a salt
layer.
PP&E
Property, plant and equipment.
PPP
The Prêmio por Performance (Performance Award Program) is part of our Variable
Remuneration Program, exclusive to members of the Executive Board (Officers) 5.
PPSA
Pré-Sal Petróleo S.A.
PRD
The Prêmio por Desempenho – PRD (Accomplishment Award) is part of our Variable
Remuneration Program.
Pre-salt Polygon
Underground region formed by a vertical prism of undetermined depth, with a
polygonal surface defined by the geographic coordinates of its vertices established by
Law No. 12,351/2010, as well as other regions that may be delimited by the Brazilian
federal government, according to the evolution of geological knowledge.
Pre-salt
A geological formation containing oil or natural gas deposits located beneath a salt
layer.
Proved Developed
Reserves
Reserves that can be expected to be recovered through: (i) existing wells with existing
equipment and operating methods or for which the cost of the required equipment is
relatively minor compared to the cost of a new well; and (ii) installed extraction
equipment and infrastructure operational at the time of the reserve estimate if the
extraction is by means not involving a well.
Proved Reserves
Consistent with the definitions of Rule 4-10(a) of Regulation S-X, proved oil and gas
reserves are those quantities of oil and gas, which, by analysis of geoscience and
engineering data, can be estimated with reasonable certainty to be economically
producible – from a given date forward, from known reservoirs, and under existing
economic conditions, operating methods, and government regulations. Existing
economic conditions include prices and costs at which economic producibility from a
reservoir is to be determined. The price is the unweighted arithmetic average of the
first-day-of-the-month price during the twelve- month period prior to December 31,
unless prices are defined by contractual arrangements, excluding escalations based
upon future conditions. The project to extract the hydrocarbons must have
commenced or we must be reasonably certain that we will commence the project
Annual Report and Form 20-F 2024 I 20
Glossary
within a reasonable time. Reserves that can be produced economically through
application of improved recovery techniques (such as fluid injection) are included in
the “proved” classification when successful testing by a pilot project, or the operation
of an installed program in the reservoir or an analogous reservoir, provides support
for the engineering analysis on which the project or program was based.
Proved Undeveloped
Reserves
Reserves that are expected to be recovered from new wells on undrilled acreage, or
from existing wells where a relatively major expenditure is required. Reserves on
undrilled acreage are limited to those directly offsetting development spacing areas
that are reasonably certain of production when drilled, unless evidence using reliable
technology exists that establishes reasonable certainty of economic producibility at
greater distances. Undrilled locations are classified as having undeveloped reserves
only if a development plan has been adopted indicating that they are scheduled to be
drilled within five years, unless the specific circumstances justify a longer time. Proved
undeveloped reserves do not include reserves attributable to any acreage for which an
application of fluid injection or other improved recovery technique is contemplated,
unless such techniques have been proved effective by actual projects in the same
reservoir or an analogous reservoir or by other evidence using reliable technology
establishing reasonable certainty.
Production Sharing
Contract or PSC
Production Sharing Contract regulates the rights and obligations under the
exploration and production regime for oil, natural gas, and other fluid hydrocarbons,
where the contractor undertakes exploration, appraisal, development, and production
activities at its own risk and expense. In the event of a commercial discovery, the
contractor is entitled to recover cost oil, the production volume corresponding to
royalties due, and a share of profit oil, as per the proportions, conditions, and terms
established in the contract, in accordance with Law No. 12.351/2010.
REFAP
Refinery Alberto Pasqualini.
REGAP
Refinery Gabriel Passos.
REMAN
Refinery de Manaus.
REPAR
Refinery Presidente Getúlio Vargas.
RD&I
Research, Development and Innovation.
RLAM
Refinery Landulpho Alves.
Annual Report and Form 20-F 2024 I 21
Glossary
RNEST
Refinery do Nordeste Abreu e Lima.
Reserves Replacement
Ratio or RRR
Measures the amount of Proved Reserves added to a company’s reserve base during
the year relative to the amount of oil and gas produced.
Reserves to
production ratio or
R/P
Calculated as the amount of Proved Reserves of the year relative to the amount of oil
and gas produced during the year, indicating the number of years reserves would last
if production remains constant.
RT&M or Refining,
Transportation &
Marketing
Refining, Transportation & Marketing is our business segment that covers the
activities of refining, logistics, transport, acquisition and exports of crude oil, as well
as trading of oil products, in Brazil and abroad. This segment also includes the
petrochemical operations (which includes holding interests in petrochemical
companies in Brazil), and fertilizer production.
S&P
Standard & Poor’s Financial Services LLC, a credit rating agency.
SCC-CO2 production
losses
Measures the absolute production loss resulting from stress corrosion cracking,
induced by CO2 in production pipelines.
SEC
The United States Securities and Exchange Commission.
SELIC
The Central Bank of Brazil base interest rate.
SEST
The Secretaria de Coordenação e Governança das Empresas Estatais (Secretary of
Coordination and Governance of State-Owned Companies).
Sete Brasil
Sete Brasil Participações, S.A.
Shell
Shell Plc, or its subsidiary that operate in Brazil, Shell Brasil Petróleo Ltda.
SIX
Shale Industrialization Unit.
SOFR
The Secured Overnight Financing Rate is a benchmark interest rate based on
transactions in the Treasury repurchase marketing, for dollar-denominated
Annual Report and Form 20-F 2024 I 22
Glossary
derivatives and loans that replaced the LIBOR.
SPE
Society of Petroleum Engineers.
Strategic Plan or SP
2050
Strategic Plan 2050.
Synthetic Oil and
Synthetic Gas
A mixture of hydrocarbons derived by upgrading (i.e., chemically altering) natural
bitumen from oil sands, kerogen from oil shales, or processing of other substances such
as natural gas or coal. Synthetic Oil may contain sulfur or other non-hydrocarbon
compounds and has many similarities to crude oil.
TAG
Transportadora Associada de Gás S.A.
TBG
Transportadora Brasileira Gasoduto Bolívia-Brasil S.A. is a company operating in the
natural gas transportation industry, in which we have a 51% equity interest, owner of
2,593 km gas pipeline system, located mainly in the South and Southeast regions of
Brazil, with installed capacity of 30 million m³/d. TBG is connected to GTB, which is
responsible for the Bolivian side of the gas pipeline, which permits access to Bolivian
natural gas, and is connected to Nova Transportadora do Sudeste S.A.’s (NTS) gas
pipeline, which permits access to Brazilian natural gas.
TCU
The Tribunal de Contas da União (Federal Auditor’s Office) is a constitutionally
established body linked to the Brazilian Congress, responsible for assisting it in
matters related to the supervision of the Brazilian federal government and its
resources with respect to accounting, finance, budget, operational and public property
(patrimônio público) matters.
TJLP
The Taxa de Juros de Longo Prazo (Brazil’s long-term interest rate) is set quarterly by
the CMN (as defined above). The rate is one of the benchmark rates used by BNDES in
its loans to companies.
ToR Surplus
Volume that exceeds what has been contracted under the Transfer of Rights
agreement in specified Pre-salt areas. See “Legal and Tax —Material Contracts” in this
annual report.
TotalEnergies
TotalEnergies SE, or its subsidiary that operates in Brazil, Total E&P do Brasil Ltda.
Transfer of Rights
An agreement under which the Brazilian federal government assigned to us the right
to explore and produce up to five billion barrels of oil equivalent (bnboe) in specified
Annual Report and Form 20-F 2024 I 23
Glossary
Agreement or ToR
Pre-salt areas in Brazil. See “Legal and Tax —Material Contracts” in this annual report.
Transpetro
Petrobras Transporte S.A.
TRIR
Total recordable injury per million man-hour frequency rate. Number of fatal
accidents, lost-time injuries, injuries involving substitute work and medical treatment
injuries per million hours worked. It is a performance indicator used by the industry to
measure occupational safety performance. This indicator is analyzed at all
management levels, including the board of directors.
Ultra-deepwaters
Over 1,500 meters (4,921 feet) deep.
UPGN
Unidade de Processamento de Gás Natural (Natural-gas processing Units). A natural
gas processing plant is a facility designed to process raw natural gas from the
offshore production fields by separating impurities and various non-methane
hydrocarbons and fluids through different technologies to produce specified natural
gas for final consumption. Through the process, a gas processing plant can also
recover natural gas liquids (condensate, natural gasoline and liquefied petroleum gas)
with higher added value.
UTE
Usina Termoelétrica (Thermal Power Plant). A thermoelectric plant is a power
generation plant in which heat energy is converted to electrical energy.
Utilization of Refining
Capacity
Measures how much crude oil refineries are processing or "running" as a percentage of
their maximum capacity.
VAZO Indicator
Oil and Oil Products Spilled Volume indicator. The total volume of oil or oil products
spilled in events of leakages individually greater than 1 bbl (0.159 m³) that reached
water bodies or soil that wasn’t made impermeable. This volumetric criterion (>1
barrel) is aligned with the ANP Manual for reporting incidents for E&P activities.
Sabotage and theft-related spills are not considered.
Vibra
Vibra Energia S.A., formerly “Petrobras Distribuidora.”
Well Connection Cost
Measures the evolution of the average connection cost of production development
wells. This KPI represents the sum of the total cost of well connections concluded in
the corresponding year over the total cost of well connections planned in the strategic
plan for the same well connections.
Additionally, this KPI only includes Pre-salt wells.
Annual Report and Form 20-F 2024 I 24
Glossary
Well Construction
Cost
Measures the evolution of the average cost of wells construction. This KPI represents
the sum of the average cost of drilling and completion concluded in the corresponding
year.
The reference database includes only production development wells drilling and
completion in the corresponding year, excluding exploratory and reservoir data
acquisition wells.
Well Construction
Duration
Measures the evolution of the average duration of well construction. This KPI
represents the sum of the average duration of drilling and completion concluded in
the corresponding year.
The reference database includes only production development well drilling and
completion in the corresponding year, excluding exploratory and reservoir data
acquisition wells.
Wildcat Well
An exploration well that is drilled in areas with no oil and gas production history.
Wildcat wells face a substantial risk of being dry holes.
YPF
YPF Sociedad Anónima or YPF S.A.
YPFB
Yacimientos Petroliferos Fiscales Bolivianos.
About us
Annual Report and Form 20-F 2024 I 26
About us
About us
We are a Brazilian partially state-owned company, one of the largest producers of oil and gas in the world
according to Bloomberg, primarily engaged in exploration and production, refining, energy generation and
trading. We have expertise in exploration and production in deep and Ultra-deepwaters as a result of almost
50 years of developing Brazil’s offshore basins, a leader worldwide in this segment.
We are committed to being the best energy company in terms of diversification, integration and value
generation, reconciling the focus on oil and gas with low carbon businesses. Accordingly, we are adopting
different strategies for the specific segments in which we operate, investing in the decarbonization of our
operations, in the generation of renewable energy, and in sustainable fuels. Furthermore, we are expanding
our research in the field of low carbon businesses.
We seek to build a more sustainable world, with the principles of safety, respect for the environment, and
full attention to people’s needs, such as: policies and implementation actions to promote diversity, equity
and inclusion, in the countries where we operate, as well as the health, well-being and physical and
psychological safety of employees.
We are one of the largest companies in market capitalization in Latin America according to Bloomberg, with
a market capitalization of US$81.0 billion as of December 31, 2024. We have over 49 thousand employees
(including subsidiaries in Brazil and abroad).
Datasheet
Name of the company: Petróleo Brasileiro S.A. – Petrobras
Date of Incorporation: 1953
Country of Incorporation: Brazil
Registration number at the CVM: 951-2
Central Index Key (CIK) at the SEC: 0001119639
Address of principal executive office: Avenida Henrique Valadares, 28, 20231-030, Rio de Janeiro, RJ,
Brazil
Telephone number: (55 21) 3224 2401
Corporate and investor relations websites: www.petrobras.com and www.petrobras.com.br/ir.
Corporate purpose established in our Bylaws: research, extraction, refining, processing, trading and
the transport of oil, its by-products, natural gas and other fluid hydrocarbons from wells, shale and
other rocks, in addition to energy-related activities, and the research, development, production,
transport, distribution, sale and trading of all forms of energy, and other related activities or similar
purposes.
Annual Report and Form 20-F 2024 I 27
About us
Overview
We have a large base of Proved Reserves and operate and produce most of Brazil’s oil and gas. The most
significant part of our Proved Reserves is located in the adjacent offshore Campos and Santos basins in
southeast Brazil. Their proximity allows us to optimize our infrastructure and our costs of exploration,
development and production. The Campos and Santos basins are expected to remain an important source
of Proved Reserves and oil and gas production.
Our business, however, goes beyond oil and gas exploration and production. It entails a long process
through which we get the oil and gas to our refineries and gas treatment units, which are themselves in
constant evolution to supply the best products.
We operate the majority of the refining capacity in Brazil. Our refining capacity is distributed throughout
the southeast, south and northeast regions of Brazil, reaching the largest market share in these and other
regions of the country through direct deliveries, pipelines and also cabotage. We mostly meet our demand
for oil products by domestic refining of crude oil, as defined in a periodic process of integrated operational
planning which constantly seeks to maximize value for the company. We are also involved in the production
of petrochemicals and biofuels through interests in some companies. We distribute oil products through
wholesalers, retailers and direct sales.
We also participate in the Brazilian natural gas market, including the logistics and processing of natural gas.
To meet our clients’ and our own internal demand, we process natural gas derived from our onshore and
offshore production (mainly from fields of the Campos, Espírito Santo and Santos basins), import natural
gas from Bolivia and import LNG through our regasification terminals. We also participate in the domestic
power market primarily through our investments in gas-fired thermoelectric power plants.
Annual Report and Form 20-F 2024 I 28
About us
We currently divide our business into three main segments:
_
Exploration & Production (E&P): this segment covers the activities of exploration, development and
production of crude oil, NGL and natural gas in Brazil and abroad, for the primary purpose of
supplying our domestic refineries. This segment also operates through partnerships with other
companies, including holding interests in non-Brazilian companies in this segment.
_
Refining, Transportation & Marketing (RT&M): this segment covers the activities of refining,
logistics, transport, acquisition and exports of crude oil, as well as trading of oil products in Brazil
and abroad. This segment also includes petrochemical operations (which involves holding interests
in petrochemical companies in Brazil), and fertilizer production.
_
Gas & Low Carbon Energies (G&LCE): this segment covers the activities of logistics and trading of
natural gas and electricity, the transportation and trading of LNG, the generation of electricity by
means of thermoelectric power plants, as well as natural gas processing. It also includes renewable
energy businesses, low carbon services (carbon capture, utilization and storage) and the production
of biodiesel and its co-products.
Activities that are not attributed to business segments are classified as “Corporate and Other Businesses,”
including general corporate matters, in addition to distribution businesses. Corporate items mainly include
those related to corporate financial management, overhead central administration, and other expenses,
including actuarial costs associated with pension and health plans for beneficiaries. The other businesses
cover the distribution of oil products throughout South America.
For further information regarding our business segments, see Note 13 to our audited consolidated financial
statements, as well as “Operating and Financial Review and Prospects” in this annual report.
In 2024, we had activities, as described below, in seven countries besides Brazil (i.e., Argentina, Bolivia,
Colombia, the U.S., the Netherlands, Democratic Republic of São Tomé and Príncipe, and Singapore).
In Latin America, our operations include upstream, marketing and retail services. In North America, we
produce oil and gas through an interest in a joint venture. We have subsidiaries that support our trading
and financial activities in Rotterdam, Houston, Buenos Aires and Singapore. These companies act as
complete and active trading desks for markets worldwide and are responsible for market intelligence and
trading of oil, oil products, natural gas, biofuels, commodity derivatives and shipping. In Africa, we have
exploratory operations in the Democratic Republic of São Tomé and Príncipe.
We operate through 13 direct subsidiaries (11 incorporated under the laws of Brazil and two incorporated
abroad) and one direct joint operation as listed below. We also have indirect subsidiaries, including
Petrobras Global Trading B.V., Petrobras Global Finance B.V., Petrobras America Inc. and Petrobras
Netherlands B.V.
Annual Report and Form 20-F 2024 I 29
About us
Companies
Location
Our
shareholding
Other
shareholders
Petrobras Transporte S.A. – Transpetro
Brazil
100.00%
—
Petrobras Logística de Exploração e
Produção S.A. – PB-LOG
Brazil
100.00%
—
Petrobras Biocombustível S.A.
Brazil
100.00%
—
Transportadora Brasileira Gasoduto Bolívia-
Brasil S.A. – TBG
Brazil
51.00%
BBPP Holdings Ltda. (29%)
YPFB Transporte S.A. (19.88%)
Corumba Holding S.À.R.L. (0.12%)
Procurement Negócios Eletrônicos S.A.
Brazil
72.00%
SAP Brasil Ltda. (17%)
Accenture do Brasil S.A. (11%)
Araucária Nitrogenados S.A.
Brazil
100.00%
—
Termomacaé S.A.
Brazil
100.00%
—
Termobahia S.A.
Brazil
98.85%
Petros (1.15%)
Baixada Santista Energia S.A.
Brazil
100.00%
—
Fundo de Investimento Imobiliário RB
Logística – FII
Brazil
99.15%
Pentágono SA DTVM (0.85%)
Petrobras Comercializadora de Gás e Energia
e Participações S.A. – PBEN-P
Brazil
100.00%
—
Fábrica Carioca de Catalisadores S.A. – FCC(1)
Brazil
50.00%
Ketjen Brazil Holding Ltda. (50%)(2)
Petrobras International Braspetro – PIB BV
Abroad
100.00%
Petrobras Comercializadora de Gás
e Energia e Participações S.A.
(antiga 5283 Participações S.A.)
(0.0007%)
Braspetro Oil Services Company – Brasoil
Abroad
100.00%
—
Associação Petrobras de Saúde - APS(3)
Brazil
93.12%
Transpetro (6.34%)
TBG (0.35%)
Pbio (0.14%)
Termobahia (0.05%)
(1)
Joint operations.
(2)
Former Albemarie Brazil Holding Ltda
(3)
A non-profit association that operates our supplementary health care plan (AMS - Saúde Petrobras) since 2021. The percentage variation of each company
is due to changes in the beneficiary base (retirees, pensioners, dependents and active employees), including additions and dismissals, over the period
analyzed.
For an extended list of our subsidiaries and joint operations, including each of their full names, jurisdictions
of incorporation and our percentage of equity interest, see Exhibit 8.1 to this annual report and Note 28 to
our Financial Statements. Additionally, we participate in consortia that engage in the exploration of blocks
and the production of oil fields in Brazil – see “Our Business — Exploration & Production — Overview” for
more details.
Annual Report and Form 20-F 2024 I 30
About us
2024 Highlights
Annual Report and Form 20-F 2024 I 31
About us
Risks
Annual Report and Form 20-F 2024 I 33
Risks
Risks
We are exposed to a number of risks that, individually or jointly, may have an effect on our business and/or
financial performance. The risk factors are presented in the following groups:
Risks related to (1) our company; (2) our shareholders, in particular our controlling shareholders; (3) our
directors; (4) our suppliers; (5) our customers; (6) the sectors of the economy in which we act; (7) the
regulation of the sectors in which we are involved; (8) foreign countries where we are involved; (9) social
issues; (10) environmental issues; (11) climate issues, including physical and transition risks; (12) the use of
our trademark; and (13) our shares and debt securities.
Risk Factors
1) Risks related to our company
1.a) We are exposed to health, safety and environmental risks in our operations, which may lead to
accidents, significant losses, administrative proceedings and legal liabilities.
Activities related to the oil and gas business present high risks, generally because they involve high
temperatures and pressures. In particular, deepwater and Ultra-deepwater activities, and refining and
petrochemicals, performed by us, our subsidiaries or our affiliate companies present several risks, such as
oil and product leakage, collapses, aeronautical accidents, fires, and explosions in refineries and exploration
and production units, including platforms, ships, pipelines, mines, terminals, laboratories, and losses of
containment in dams, among other assets owned or operated by us, our subsidiaries or our affiliate
companies. These events can occur due to technical or human failures or natural disasters, among other
factors. The occurrence of one of these events, or other related incidents, may result in health impacts on
our workforce and/or surrounding communities, fatalities, and environmental damage. They can cause
material damage, production losses, financial losses and, in certain circumstances, liability in civil, labor,
criminal, environmental and administrative proceedings. As a result, we may incur expenses related to
mitigation, recovery and/or compensation for the damages caused.
We are also exposed to corporate security risks arising from acts of intentional interference by third parties
in our pipelines and nearby areas, especially illegal taps (thefts) of oil and oil products, mainly in the states
of São Paulo and Rio de Janeiro. Despite our efforts and the actions of public authorities to combat illegal
taps, if this interference continues, it may result in accidents of small or large proportions, including leaks
or damage to our facilities and to communities near our facilities, which may affect the continuity of our
operations and lead to the payment of fines and indemnities to the affected parties, all of which may
negatively impact our results.
Finally, due to risks such as those mentioned above, we may face difficulties in obtaining or maintaining
operating licenses and may suffer damages to our image and reputation.
1.b) Failures in our information technology systems, information security systems (cybersecurity) and
telecommunications systems and services can adversely impact our operations and reputation.
Our operations are highly dependent on information technology and telecommunications systems and
services, as well as the degree of technological protection and the strength of the associated internal
controls. Interruptions or malfunctions affecting these systems and/or their infrastructure, caused by
obsolescence, technical failures, deliberate acts, or even arising from geopolitical factors or derived from
third-party systems, digital infrastructure and the cloud may harm or even paralyze our business and
adversely impact our operations and reputation. These situations may also lead to unforeseen costs for the
recovery of information and assets, in addition to the imposition of fines or legal sanctions.
Annual Report and Form 20-F 2024 I 34
Risks
Failures in information security (including industrial and automation systems), whether external,
intentional or not (e.g., malware, hackers, cyberterrorism) or internal (e.g., neglect or misuse of IT assets by
employees or contractors who are in a hybrid work environment working on-site and remotely), may also
impact our business and reputation, our relationship with stakeholders and external agents (government,
regulatory bodies, partners, suppliers, among others), our strategic positioning towards our competitors
and our operational and financial results. Additionally, the use of artificial intelligence (AI) in cyberattacks
or in decision-making systems and processes may amplify existing risks and create new threats that may
impact our businesses.
Artificial intelligence systems can demonstrate disparities among subgroups or languages due to biased
training data or may be subject to risks such as data poisoning, which can compromise the integrity of the
model, or hallucination, which can generate incorrect or misleading information. Biased training data, data
poisoning and hallucination may all negatively impact internal decision-making processes based on AI.
Moreover, AI may be used by external agents to automate and escalate already known cyber-attacks,
making them more efficient and difficult to detect in a timely manner.
Additionally, we are subject to increasing regulations related to AI, cybersecurity and information security,
including among other aspects, adequate protection of data and digital assets, supervision of cyber risks,
and incident reporting. Failure to comply with these regulations at the national and international levels may
result in legal sanctions, as well as impacts on our image and reputation, and affect our operational and
financial results.
1.c) Maintaining our long-term oil production objectives depends on our ability to successfully
incorporate and develop our reserves.
Our ability to incorporate additional reserves depends on exploration activities, which expose us to its
inherent risks and may not lead to the discovery of commercially viable oil or natural gas reserves.
In addition, competition in the oil and gas sector in Brazil or difficulties in obtaining environmental licensing
in New Frontier areas, both in Brazil or abroad, may make it more difficult or costly to (i) obtain additional
acreage in bidding rounds for new contracts, and (ii) develop existing contracted areas.
Adding new reserves depends on our ability to conceive and implement development projects. Exploration
and development activities in deepwater and Ultra-deepwater require significant capital investments and
involve several factors that are beyond our control, such as significant changes in economic conditions,
climate and environmental regulations and obtaining and/or renewing environmental permits, supply
market capacity, and unexpected operating conditions, including equipment failures or incidents, which
may restrict, delay or cancel our operations.
1.d) We may incur losses and spend time and financial resources defending pending litigations and
arbitrations.
We are currently party to several administrative, legal and arbitration proceedings related to civil,
administrative, tax, labor, environmental and corporate claims filed against us. These claims involve
substantial amounts of money and other resources, and the total cost of unfavorable decisions can have a
material adverse effect on our results and financial condition.
These legal, administrative and arbitration proceedings can have a negative impact on our results in the
event of unfavorable outcomes, such as contracts’ termination and/or revision of governmental
authorizations. Depending on the outcome, litigation can result in restrictions on our operations and have
a material adverse effect on some of our business.
We can be affected by changes in rules, regulations and jurisprudence that can have a material adverse
effect on our financial condition and results.
Annual Report and Form 20-F 2024 I 35
Risks
1.e) The selection and development of our investment projects have risks that may affect our expected
results.
We constantly evaluate new project opportunities for our investment portfolio. As most projects are
characterized by a long period of development and maturation, we may face changes in market conditions,
such as fluctuations in input and finished product prices, new regulatory requirements, consumer
preferences, and demand profile, exchange and interest rates, and financing conditions that may jeopardize
our expected rates of return. We may also adjust our project approval criteria, increasing our focus on those
aimed at decarbonizing operations, resulting in different risk and return profiles.
We face specific risks for oil and gas projects. Despite our experience in deepwater and
Ultra-deepwater oil exploration and production and the continuous development of studies during the
planning stages, the quantity and quality of oil and gas produced in a certain field will only be fully known
in the production phase, which may require adjustments throughout the project life cycle and its expected
rate of return.
There are also risks related to potential delays in the execution of oil and gas projects, which may result in
the mismatch of required dates between upstream and downstream projects (e.g., delay in onshore
infrastructure, impacting offshore oil and gas flow, and onshore gas transportation). We, along with part of
our supply chain, also face risks associated with international conflicts, wars or unplanned unavailability of
critical assets and/or resources (such as drilling rigs, special vessels, and the natural gas and LNG chains)
that may also impact the offshore and onshore flow and may compromise the continuity of our business
production chain. Additionally, our failure to meet obligations established by the regulatory agencies may
generate fines and liabilities.
Moreover, despite our expertise in exploration and production and refining, we may face new technical
challenges as we move closer to the technological frontier.
Our Strategic Plan and our Business Plan include initiatives related to climate change, as such commitments
are becoming increasingly relevant in the oil and gas business. Climate change risks include physical risks,
such as extreme weather events and their impact on our operations, as well as risks inherent in the energy
transition to a low-carbon economy, including political and/or regulatory changes and shifting market
demands. To address these risks, we may need to increase our investments in climate change mitigation
and adaptation measures, which may result in increased capital expenditures and significantly impact our
Strategic Plan and our Business Plan. For further information on how climate change could impact our
results and strategy, please see risk factor "11.a) Climate change could impact our results and strategy” in
this section.
1.f) We have substantial liabilities and may be exposed to significant liquidity constraints in the short
and medium term, which may materially and adversely affect our financial condition and results.
We have substantially reduced the level of our debt in recent years. However, our liabilities are still relevant
and could potentially weaken our liquidity in adverse times. Considering that there may be liquidity
constraints on the debt market to finance our planned investments, pay principal and interest obligations
in contracted terms, and honor our financial commitments, any difficulty in raising significant amounts of
debt capital in the future may affect our results and the ability to fulfill our Business Plan or any subsequent
plan adopted.
Our lack of investment grade credit rating and any lowering of our credit ratings may have adverse
consequences on our ability to obtain financing in the market through debt or equity securities, or may
affect our financing cost, making it more difficult and/or costly to refinance maturing obligations. The
impact on our ability to obtain resources and the cost of such resources may adversely affect our results
and financial condition.
In addition, our credit rating is sensitive to any change in the credit rating of the Brazilian federal
government. Any lowering in the credit ratings of the Brazilian federal government may have additional
Annual Report and Form 20-F 2024 I 36
Risks
adverse consequences on our ability to obtain financing and/or on the cost of our financing and,
consequently, on our results and financial condition.
1.g) Differing interpretations of tax regulation or changes in tax policies may have an adverse effect on
our financial condition and results.
We and our Brazilian and foreign subsidiaries are subject to tax rules and regulations that may, over time,
result in different interpretations between us, our subsidiaries and tax authorities (including federal, state
and municipal authorities), which do not have uniform interpretations. As a result of such divergences, we
and our subsidiaries may have to assume unanticipated provisions and charges. In some cases, when we
and/or our subsidiaries exhaust all administrative remedies related to a tax contingency, further appeals
may be filed in the judicial courts, which may require guarantees, such as the deposit of an amount equal to
the amount of the charge. In some of these cases, the settlement of such charges through tax transactions
or incentivized regularization programs may be a more favorable option for us and our subsidiaries, in which
case we evaluate the alternatives, and make an informed decision on whether to proceed with the
settlement of charges.
In addition, the Brazilian Congress may approve tax law changes that could substantially alter the Brazilian
tax framework and impact our business. The tax authorities of Brazil (including the federal, state and
municipal) and foreign tax authorities may also publish new legislation and/or regulation that impacts the
fulfillment of tax obligations (primary and ancillary) requiring relevant efforts (human and systemic
resources) by taxpayers to implement the obligations within the legal deadline. The obligation to adapt the
taxpayer’s processes to the new legislation in a short time may have an adverse effect on our results and
the results of our subsidiaries.
Any of these occurrences may have a material adverse effect on our financial condition and results.
1.h) Our crude oil and natural gas reserve estimates involve some degree of uncertainty, which could
adversely affect our ability to generate income.
Our proved crude oil and natural gas reserves set forth in this annual report are the estimated quantities of
crude oil and natural gas that geoscience and engineering data demonstrate with reasonable certainty to
be economically producible from a given date forward from known reservoirs under existing economic and
operating conditions according to SEC Regulation S-X, and other applicable regulations.
The reserve estimates presented are prepared based on assumptions and interpretations that are subject
to risks and uncertainties. The geoscience and engineering data that we use to estimate our reserves
present uncertainties that may result in differences between the expected productions in the reported
reserves and those actually produced. In addition, reserve estimates may be affected by significant changes
in economic conditions and climate regulations.
Technical, economic, and climate regulations uncertainties may lead to reductions in our reserve estimates
and lower future productions, which may have an adverse effect on our results and financial condition.
1.i) Decommissioning projects have become more relevant in our portfolio, in addition to being subject to
increasing regulatory requirements and stakeholder expectations, which may result in damage to our
image and increased costs.
Decommissioning projects have become more relevant to our portfolio as concession contracts expire or
production systems lose economic viability. Despite the publication of ANP Resolution 817/2020
establishing the rules for conducting the decommissioning of production systems, we may face some
difficulties in defining the scope of these projects and in meeting regulatory requirements, especially due
to our and the industry’s learning curve in this area, as well as the evolution of applicable regulations.
Closure of operations and decommissioning can negatively impact the environment and the surrounding
communities of the sites due to the processes of dismantling structures and facilities. Although our
decommissioning plans have been developed in compliance with applicable law, it is possible that these
plans will also face scrutiny or fail to meet stakeholder demands or expectations regarding environmental,
Annual Report and Form 20-F 2024 I 37
Risks
social and governance practices. As a result, the resource demands for the projects may increase, as well as
the total project and operational costs. In addition, our image and reputation may be adversely affected.
1.j) Obligations relating to Petros and health care benefits are annually revised estimates and may
diverge from future obligations due to changes in market and economic conditions, as well as changes in
actuarial assumptions, which may require additional contributions to rebalance the plans.
The calculation of actuarial obligations, both for our pension plans and for our health care plan benefits, is
based on estimates and actuarial assumptions, as well as on the modeling of business rules, observing the
applicable regulations of each plan and the applicable law. Thus, the value of the obligations corresponds
to an estimate that may change over time, as the assumptions and estimates are not confirmed.
In addition, we and Petros face risks related to supplementary pension, including a gradual increase in the
longevity of the population covered, legal risks accentuating the level of benefits and risks that affect the
financial assets held by Petros to cover obligations of the benefit plans sponsored by us, which may not
generate the necessary returns to cover the relevant liabilities, in which case additional contributions from
us and participants may be necessary, subject to the constitutional contributory parity rule.
Regarding health benefits, projected cash flows may also be impacted by the following factors:
_ higher increase in medical costs than expected;
_ additional claims arising from benefits extension; and
_ difficulty in adjusting the contributions of participants to reflect increases in health costs.
These factors may result in an increase in our liabilities and may adversely affect our results and our
financial condition.
1.k) Difficulties in attracting, developing and retaining people with the necessary skills and
qualifications can negatively impact the implementation of our strategy.
Our success depends on the capacity to continue training and qualifying our personnel so that they are
qualified to assume senior positions in the future.
The entry of employees in a public position or employment in Brazil is made possible by a public selection
process, as provided for in the Federal Constitution. Since the Consolidação das Leis do Trabalho
(Consolidation of Labor Laws) does not allow us to require more than six months’ previous experience, we
cannot guarantee that new employees have the adequate experience to perform the activities for which
they are designated, that is, with qualifications, experience and skills previously developed in the market.
There is no guarantee that we will adequately allocate and train our employees, nor that we will be able to
do so without incurring additional costs. Any failure may adversely affect our results and business.
1.l) Strikes, work stoppages or labor unrest by our employees or by the employees of our suppliers or of
our contractors may adversely affect our results and our business.
Several factors may lead to legal issues and labor claims, giving rise to strikes and stoppages, such as:
_ disagreements and dissatisfaction regarding our business strategy, in particular, those related to
portfolio management and its implications for the workforce;
_ human resources policies regarding remuneration, benefits and number of employees;
_ workers' contributions to cover the deficit of the pension plan (Petros);
_ implementation of regulations recently created for health care and pension plans; and
_ changes in labor legislation.
Strikes, work stoppages or other forms of labor demands at any of our facilities or in our major suppliers,
contractors or their facilities or in sectors of society that affect our business may impair our ability to
Annual Report and Form 20-F 2024 I 38
Risks
continue our operations and complete our projects, adversely impacting our results and our financial
condition.
1.m) Our business may be materially and adversely affected by the emergence of epidemics or pandemics,
such as COVID-19.
Epidemics and pandemics caused by infectious agents, such as the COVID-19 pandemic, can impact the
health of our workforce, our partners and suppliers, as well as demand the redesign of routines, procedures
and organization of work in general, and may consequently affect the continuity of various activities and
our productivity. The operation of facilities such as platforms, refineries, terminals, among others may be
impacted, as well as the full functioning of the supply chain. In addition, such public health events may
affect oil prices and demand, which, consequently, may negatively impact our results and financial
condition.
1.n) We do not maintain insurance against business interruption in operations in Brazil and most of our
assets are not insured against war or sabotage.
We generally do not maintain insurance coverage for business interruptions of any nature for our
operations in Brazil, including business interruptions caused by labor disputes. If, for instance, our workers
or those of our main suppliers, vendors and service providers were to strike, the resulting work stoppages
could have an adverse effect on us. In addition, as a general rule, there is no insurance for our assets in case
of war or sabotage. Therefore, an attack or incident that causes the interruption of operations may have a
material adverse effect on our results and financial condition.
Additionally, our insurance policies do not cover all types of risks and liabilities in the area of safety,
environment, health, government fees, fines or punitive damages, which may impact our results. We cannot
guarantee that incidents will not occur in the future, that there will be insurance to cover the damages or
that we will not be held responsible for these events, which may negatively affect our results.
Furthermore, we cannot guarantee that the amounts of insurance coverage contracted for risks related to
our activities will be sufficient to guarantee, in the event of a claim, the payment of all damages caused,
which may adversely affect our business and results.
1.o) Maintaining our competitiveness depends on our ability to develop, adapt and gain access to new
technologies.
Technology and innovation are central elements to ensure our competitiveness, safety and future value
generation. We direct our research, development and innovation efforts both to improve the efficiency and
growth of the current business, as well as to diversify future businesses, whether through incremental or
disruptive innovation.
If we do not innovate in the areas of knowledge of the industry in which we operate, from the improvement
of processes and assets to the conception of the industry of the future, we may face adverse effects on our
competitiveness, our ability to implement our long-term strategy and our ability to expand value creation.
In addition, without technological innovation, we may have difficulties identifying and developing
decarbonization solutions at lower costs to society, as well as difficulties offering access to increasingly
clean energy, compromising our competitiveness and ability to respond to new environmental regulations
and market trends in a timely manner.
1.p) Our development in the energy transition segment, which includes low-carbon products and services,
is subject to uncertainties that may negatively impact the risk profile and rate of return of our portfolio.
We may carry out acquisition projects or partnerships in the energy transition segment that may negatively
impact the risk profile and rate of return of our portfolio, due to the risks associated with these new project
opportunities.
The success of acquisition projects or partnerships in energy transition – which includes the development
of low-carbon products and services – depends on the development of new processes, operational
Annual Report and Form 20-F 2024 I 39
Risks
synergies, government regulations, recruitment and training as new skills may be needed. Therefore, the
development of low-carbon products and services is subject to uncertainties that may have an adverse
effect on our expected financial results.
The demand for fossil fuels is expected to decline as alternative technologies become increasingly viable
and popular. Our ability to remain competitive while transitioning toward cleaner energy sources depends
on factors such as regulatory developments and consumer preferences influenced by climate change and
the energy transition toward cleaner energy sources. Uncertainties regarding the pace of this energy
transition may affect product demand, leading to potential production and supply constraints, which could
hinder the development of new profitable businesses opportunities. Failures related to the diversification
of our operations may negatively impact our revenues.
1.q) As a result of acquisitions, divestments and partnerships, we are exposed to risks that could lead to
financial losses.
Upon completion of each acquisition, divestment or partnership (post-closing stage), we must perform
management and monitoring of the actions required and provided under the contracts related to each
project, taking into account the rights and compliance with the obligations established in the documents
that formalize these transactions. Failure to comply with such contractual obligations or non-exercise of
rights may result in financial losses.
Furthermore, as determined by ANP, in case of the total or partial sale of our participation in E&P contracts,
we remain jointly liable for abandonment costs after the new concessionaire’s production ends, should it
default on this task. Such joint liability covers obligations arising prior to or after the transfer, provided that
it arises from activities carried out on a date prior to the transfer. The same applies to environmental
liabilities, regardless of the segment of which the divested asset is part. According to environmental
legislation, liability for environmental damage is the responsibility of all those who directly or indirectly
contributed to its realization, and the adjustments made between the buyer and seller parties do not release
those parties of their liability.
Additionally, the sale of assets may negatively impact existing synergies and logistical integration within
our company, which may adversely affect our results.
Our current or future partners may not be able to meet their obligations, including financial ones, which
may jeopardize the viability of some of the projects in which we participate. Depending on the corporate
structure model that rules the partnership, our partners may have the right to veto certain decisions, which
may also affect the viability of some projects.
Regardless of the partner responsible for the operations of each E&P project, we may be exposed to risks
associated with those operations, including litigation (where joint liability could apply) and the risks of
government sanctions arising from such partnerships, which could have a material adverse effect on our
operations, reputation, cash flow and financial condition.
Regarding acquisition and partnership processes, the target asset may not perform as expected during the
time of acquisition or partnership formation. This inherent risk can be attributed to a variety of factors,
including market price volatility, regulatory and economic changes, as well as the cultural and operational
integration between the organizations involved.
1.r) We are subject to the risk that internal control over financial reporting may become inadequate due
to changes in the control environment, or that the degree of compliance with our policies and procedures
may deteriorate.
Limitations inherent in internal control over financial reporting may cause them to fail to prevent or detect
errors and may adversely affect our ability to report financial results in future periods accurately and in a
timely manner. In addition, it is difficult to project the effectiveness of internal control over financial
reporting for future periods, as our controls may become inadequate due to changes in the control
environment, or because our degree of compliance with our policies and procedures may deteriorate.
Annual Report and Form 20-F 2024 I 40
Risks
The identification of a material weakness in our internal control over financial reporting or any of the above
occurrences may adversely affect our business and operations and may generate negative market reactions
regarding us, potentially affecting our financial conditions and leading to a decline in the value of our
shares.
1.s) Investigations conducted by Brazilian or foreign authorities regarding the possibility of
noncompliance with the U.S. Foreign Corrupt Practices Act or other related laws may adversely affect us.
Potential adverse developments related to past investigations conducted by Brazilian or foreign authorities
may negatively impact us and could divert the efforts and attention of our management team from our
ordinary business operations. In the case of any future investigation or proceeding carried by any
authorities in Brazil or any other jurisdiction arising out of any possible noncompliance with the U.S. Foreign
Corrupt Practices Act or other laws, we may be required to pay fines or other types of financial convictions,
or to comply with court orders on future conduct or suffer other penalties, any of which may have a material
adverse effect on us. The outcome of any such investigation or proceeding may negatively impact our image
and reputation.
1.t) We may face additional proceedings arising from past investigations related to alleged irregularities
or corruption.
We are currently party to a collective action commenced in the Netherlands, a collective action and
arbitration proceedings in Argentina and arbitration and judicial proceedings commenced in Brazil, all
related to the Lava Jato investigation. In each case, the proceedings were brought by investors (or entities
that allegedly represent investors’ interests) who purchased our shares traded on the B3 Stock Exchange
or other securities issued by us outside the United States, alleging damages caused by facts uncovered in
the Lava Jato investigations.
In Argentina, we are defendants in two criminal lawsuits brought by Consumidores Financieros Asociación
Civil para su Defensa, currently named Consumidores Damnificados Asociación Civil.
In addition, EIG Management Company, LLC and eight of its managed funds filed a complaint against us on
February 23, 2016, before the United States District Court for the District of Columbia. However, since the
case was settled on March 7, 2025, we were released from any rights EIG could claim in relation to the
dispute.
For additional information on relevant legal proceedings in which we or our subsidiaries are parties, see
“Legal and Tax – Legal Proceedings” in this annual report.
It is possible that additional demands or claims might be filed in the future in the United States, Brazil or
elsewhere against us relating to the Lava Jato investigation. It is also possible that further information
damaging to us and our interests will come to light in the course of any investigations of corruption by
Brazilian authorities. Our management may be required to direct its time and attention to the defense of
these claims, which could prevent them from focusing on our core business.
In addition, substantive additional information may come to light in the future that would make the
estimate that we made in 2014 for overpayments incorrectly capitalized appear, retrospectively, to have
been materially low or high. In previous years, we were required to write off capitalized costs representing
amounts that we overpaid for the acquisition of property, plant and equipment. We may be required to
restate our financial statements to further adjust the write-offs representing the overstatement of our
assets recognized in our audited consolidated financial statements from prior years.
1.u) Operations with related parties may not be properly identified and handled.
In accordance with our Related Party Transaction Policy, transactions with related parties must be carried
out under market conditions, executed in our best interest, without conflict of interest and meeting the
necessary requirements: competitiveness, compliance, transparency, equity and commuting. The decision
processes involving these transactions must be objective and documented. In addition, we must comply
Annual Report and Form 20-F 2024 I 41
Risks
with the rules of adequate disclosure of information, in accordance with applicable legislation and as
determined by the CVM and the SEC. Any failure in our process of identification and treatment of these
situations may adversely affect our economic and financial condition, as well as lead to regulatory
assessments by agencies.
1.v) Violations of applicable data protection laws may result in fines and other types of sanctions that
may adversely affect us.
According to Brazilian Law No. 13,709/2018 – Lei Geral de Proteção de Dados Pessoais (General Personal
Data Protection Law - “LGPD”), we will be subject to penalties in cases of disclosure or misuse of personal
data.
We process personal data from various stakeholders, such as: employees, outsourced employees,
customers, suppliers, investors, visitors to our physical facilities and websites, among others. Failure to
comply with the requirements set by the LGPD may result in legal claims and/or administrative penalties,
including warnings, fines, publication of the infringement, blocking access to personal data, deletion of
personal data, partial suspension of database operations, suspension of data processing activities, and
partial or total prohibition of activities related to data processing.
2) Risks related to our shareholders, in particular our controlling shareholder
2.a) Our controlling shareholder may pursue certain objectives that may differ from those of certain
minority shareholders, or that may affect our long-term strategy.
Brazilian law requires that the Brazilian federal government owns the majority of our voting stock and, so
long as it does, it will have the power to elect a majority of the members of our Board of Directors and,
through them, the executive officers, who are responsible for our day-to-day management.
As a result, the Brazilian federal government, as our controlling shareholder, exercises substantial influence
over the strategic direction of our business, and has guided, and may continue to guide, certain
macroeconomic and social policies through us, as permitted by law.
The interests of our controlling shareholder may differ from and not be in the best interest of our minority
shareholders, and the decisions taken by our controlling shareholder may involve different considerations,
strategies and policies than they have in the past.
For additional information on our rules for appointment of Senior Management and conflicts of interest,
see “Environment, Social and Governance – Corporate Governance”, “Compliance and Internal Controls –
Compliance” and “Management and Employees – Management – Additional Information on our Board of
Directors and Executive Officers” in this annual report.
2.b) The payment of dividends and the amount allocated for distribution to shareholders depends on our
shareholder remuneration policy, which is subject to change.
Our ability to pay dividends to shareholders may be affected by a variety of factors, including our financial
performance, debt level, capital requirements, future prospects, and other business considerations.
According to our shareholder remuneration policy, the distribution of dividends and interest on capital
values depends, among other factors, on our level of investments and operating cash flow. If we decide on
a strategic plan that requires a greater volume of investments, or amend our strategic plan to do so, the
amount allocated to the distribution of dividends may be reduced. In addition, operating cash flow can be
impacted by several factors, including oil price and production, thus influencing dividend distribution.
Our shareholder remuneration policy may be amended by the Board of Directors at any time, potentially
impacting parameters such as periodicity of payments, calculation formula, financial indicators, minimum
payment (if any), among others. The payment of dividends above the statutory and legal minimum in
previous periods is not a guarantee of future payments and does not serve as a reference level.
Annual Report and Form 20-F 2024 I 42
Risks
In addition, changes to the composition of our Board of Directors and our management may result in
changes to our shareholder remuneration policy. There is a possibility that any such changes will be material
and may result in the payment of fewer or no dividends in the future.
3) Risks related to our directors
3.a) Failures to prevent, detect in a timely manner, or correct behaviors inconsistent with our ethical
principles and rules of conduct may have a material adverse effect on our results and financial condition.
We are subject to the risk that our directors, management, employees, contractors or any person doing
business with us may engage in fraudulent activities, corruption or bribery, circumvent or override our
internal controls and procedures or misappropriate or manipulate our assets for its personal or third-party
benefit, against our interest.
In addition, we are subject to the risk of cases of harassment and discrimination, which may involve our
workforce, employees in the supply chain and/or people from the communities where we operate, and which
may impact our image and reputation.
We cannot guarantee that all our directors, management, employees, contractors or any other person doing
business with us will comply with our principles and rules of ethical behavior and professional conduct aimed
at guiding our directors, management, employees and service providers. Any failure, whether actual or
perceived, to abide by our ethical principles or to comply with applicable governance or regulatory
obligations could harm our reputation, limit our ability to obtain financing and have a material adverse
effect on our results and financial condition.
4) Risks related to our suppliers
4.a) We rely on suppliers of goods and services for the operation and execution of our projects and, as a
result, we may be adversely affected by failures or delays by such suppliers.
We are susceptible to the risks of contracting, performance, product quality and capacity within our supply
chain. If our suppliers and service providers delay or fail to deliver the goods and services owed to us, we
may not meet our operational goals within the expected cost and/or timeframe. In this case, we may
ultimately need to postpone one or more of our projects, which may have an adverse effect on our results
and financial condition.
Our Strategic Plan foresees contracts for oil production units in the coming years. Due to new technological
obstacles, FPSOs have increased in complexity, size and weight of its process plants and this will pose a
challenge to the supplier market to fully respond to the demand in this timeframe.
Moreover, due to the large volume of resources to be contracted for our project portfolio, the supplier
market may be unable to absorb the total demand, causing delays in the completion of projects, especially
in the procurement of subsea lines and EPC (Engineering Procurement and Construction) for downstream
works.
Additionally, there may be risks of delays in the customs clearance process caused by external factors, which
may impact the supply of goods to us and affect our operations and projects.
Annual Report and Form 20-F 2024 I 43
Risks
5) Risks related to our customers
5.a) We are exposed to credit risks of some of our customers and the associated default risks. Any material
payment default or non-compliance by some of our customers may adversely affect our cash flow, results
and financial condition.
Some of our customers may experience financial constraints or liquidity issues that could have a significant
negative effect on their creditworthiness. Serious financial issues encountered by our customers could limit
our ability to collect amounts owed to us or to enforce the performance of obligations owed to us under
contractual arrangements.
In addition, many of our customers finance their activities through their cash flow from operations, the
incurrence of short and long-term debts, with no availability of reserves for contingencies.
Since many of our customers are Brazilian, our cash flow, results and financial conditions may be affected
in the event of declining economic conditions in Brazil, resulting in decreased cash flows, combined with the
difficulty of access to financing from our clients.
This could result in a decrease in our cash flow and may also reduce or curtail our customers’ future demand
for our products and services, which may have an adverse effect on our results and financial condition.
Due to the possibility of us being obliged in court to guarantee the supply of products or services to
counterparties who are in default, as stated in the risk factor “5.b) We may be required by courts to
guarantee the supply of products or services to counterparties who are in default”, our cash flow may be
reduced, which may have an adverse effect on our results and financial condition.
5.b) We may be required by courts to guarantee the supply of products or services to counterparties who
are in default.
We may be required by the Brazilian courts to provide products and services to clients, whether public or
private institutions, with the purpose of guaranteeing supplies to the domestic oil, natural gas, products
and energy market. In this case, we may be required to provide products and services even in situations in
which these clients and institutions are in default with contractual or legal obligations, where we have no
legal and contractual obligations to provide such services or products or in unfavorable economic and
commercial conditions. Although we typically appeal these decisions to higher courts, a requirement that
we provide such supply in exceptional situations may adversely affect our economic and financial condition.
For more information on legal proceedings in which we or our subsidiaries are parties, see item “Legal and
Tax – Legal Proceedings” in this annual report.
6) Risks related to sectors of the economy in which we act
6.a) Our cash flow and profitability are exposed to the volatility of prices of oil, gas, LNG and oil products.
Most of our revenue derives primarily from sales of crude oil, oil products and, to a lesser extent, natural
gas. International prices for oil and oil products are determined by several factors that are beyond our
control. Volatility and uncertainty in international oil prices will likely continue because they are structural
and influenced by conditions and expectations of global supply and demand. Changes in oil prices usually
result in changes in the prices of oil products and natural gas. Substantial or extended declines in
international oil prices may have a material adverse effect on our business, results and financial condition
and may also affect the value of our Proved Reserves.
On May 16, 2023, we announced the approval of our commercial strategy for setting diesel and gasoline
prices, replacing the gasoline and diesel pricing policy sold by our refineries. The commercial strategy uses
market references such as: (a) the customer's alternative cost, as the value to be prioritized in pricing, and
(b) the marginal value for us. The customer's alternative cost considers the main supply alternatives,
whether suppliers of the same or substitute products, while the marginal value for us is based on the
opportunity cost given the various alternatives for the company, among them, production, imports and
Annual Report and Form 20-F 2024 I 44
Risks
exports of the product and/or the oils used in the refining process. The commercial strategy is premised on
competitive prices per sales hub, places where the ownership of our products is transferred to third parties,
in balance with the national and international markets, taking into account the best alternative accessible
to customers.
Price adjustments will continue to be made without a previously defined periodicity, avoiding the transfer
of the conjunctural volatility of international quotations and of the exchange rate to domestic prices.
In the past, our management has adjusted our pricing of oil, gas and oil products from time to time. In the
future, there may be periods during which our product prices will not be in parity with international product
prices. Actions and legislation imposed by the Brazilian federal government, as our controlling shareholder,
could affect these pricing decisions. Representatives of the Brazilian federal government have at times
expressed their views on the need for our prices to take into account domestic conditions. Our Executive
Board and management team or Board of Directors may propose new changes to our commercial strategy.
Such actions by our controlling shareholder may not be in line with the best interest of our minority
shareholders and could result in material adverse effects on our financial condition and results of operation.
See risk factor 2.a) “Our controlling shareholder may pursue certain objectives that may differ from those
of certain minority shareholders, or that may affect our long-term strategy.”
In our Gas & Low Carbon Energies segment, in addition to natural gas own production, we import gas from
Bolivia and LNG worldwide. The costs of imported LNG are volatile and strongly influenced by conditions
and expectations of world supply and demand, including international geopolitics. In addition the imported
volume is primarily a function of the level of thermoelectric power generation, which is directly related to
hydrological conditions in Brazil. Changes in sales prices in the domestic market occur influenced by
contract lengths and indexes, agreed when signed, in a way that there is a risk of discrepancy between sale
prices and costs incurred with LNG.
We cannot guarantee that our way of setting prices will not change in the future. Changes to our commercial
strategy for setting fuel prices could have a material adverse impact on our business, results, financial
condition and the value of our securities.
6.b) The competitive environment of the Brazilian oil and gas market may intensify the requirements for
our performance levels to remain in line with the best companies in the sector. The need to adapt to a
competitive and complex environment may compromise our ability to implement our current Strategic
Plan or any subsequent plans adopted.
In 2019, we signed two agreements with the CADE, one related to the refining market (further amended on
May 22, 2024), and another related to commitments of the natural gas market. These agreements include
covenants regarding the activities carried out by us in the supply of oil and oil products to third parties in
Brazil. If we fail to comply with these agreements, we may face negative impacts, such as administrative
proceedings and fines, as well as harm to our image and reputation. For more details on these agreements,
see items “Mergers and Acquisitions”, “Regulation – Refining, Transportation & Marketing” and “Regulation
– Gas and Low Carbon Energies” in this annual report.
Regulatory changes in antitrust and competition laws may impose penalties, business restrictions and
difficulties in renewing concessions, which could adversely impact our operations and results and
compromise our sustainable growth. Additionally, in the exploration and production segment, we may not
be successful bidding for exploratory blocks in future auctions. In this case, we may have difficulties in
repositioning our portfolio in exploration and production assets that offer greater profitability and
competitive advantage, especially in the Pre-salt layer, which could negatively affect our results.
On September 4, 2023, based on the new strategic elements approved by the Board of Directors, we made
decisions regarding the divestment processes that had not yet reached the stage of signing the sales
agreements and communicated these decisions to the market. The permanence of assets in the portfolio is
periodically reassessed based on updated assumptions of profitability, strategic adherence,
decarbonization opportunities and stage of their productive life, among others. Those assets whose
Annual Report and Form 20-F 2024 I 45
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divestments are approved by us will be communicated to the market in due course. These decisions are the
result of a process of active management of our portfolio, through which the various assets are constantly
evaluated in line with our up-to-date strategic drivers.
6.c) Fragility in the performance of the Brazilian economy, instability in the political environment, legal
or regulatory changes and investor perception of these conditions may adversely affect the results of our
operations and our financial performance and may have a relevant adverse effect on us.
Our activities are strongly concentrated in Brazil. Economic policies adopted by the Brazilian federal
government may have important effects on Brazilian companies, including us, and on market conditions
and prices of Brazilian securities. Our financial conditions and results may be adversely affected by several
factors, such as:
_ exchange rate movements and volatility;
_ inflation;
_ financing of government fiscal deficits;
_ price instability;
_ interest rates;
_ liquidity of domestic capital and lending market;
_ tax policy;
_ legal or regulatory policy for state owned companies and their subsidiaries;
_ wages and labor costs;
_ regulatory policy for the oil and gas industry, including pricing, new taxes or tariffs, local content
requirements;
_ policies and regulatory requirements associated with climate change mitigation and the transition
to a low-carbon economy;
_ political instability resulting from allegations of corruption involving political parties, elected
officials or other public officials; and
_ other political, diplomatic, social and economic developments affecting Brazil.
Uncertainty about whether the Brazilian federal government will implement changes in policy or regulations
that may affect any of the factors mentioned above or other factors in the future may lead to economic
uncertainty in Brazil and increase the volatility of the Brazilian securities market and securities issued
abroad by Brazilian companies, which may have a material adverse effect on our results and financial
condition.
Increased tensions in the Brazilian political environment may result in difficulties for the Brazilian federal
government in obtaining a majority of votes in the National Congress, which may lead to an increase in
political uncertainty and adversely affect Brazil’s economic growth with a potential negative impact on our
operating results and financial condition.
6.d) Market fluctuations related to political instability, acts of terrorism, insurrection, armed conflicts
and wars in various regions of the world may have a material adverse effect on our business.
Geopolitical risk factors have recently become more prominent in the world. For example, as a result of
ongoing military conflicts involving Russia and Ukraine, and in the Middle East, the prices of oil, natural gas
and LNG remain extremely volatile. Such military conflicts, and the resulting economic sanctions imposed
on the Russian government, certain Russian citizens and enterprises, could have a negative effect on the
global economy, including Brazil. We cannot predict the extent of these conflicts and their impact on our
business. These events also impact crude oil flows and the related markets as could other similar events or
Annual Report and Form 20-F 2024 I 46
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acts. One example is the change in oil exports offered by Russia, which have moved to China and India,
restricting residual demand from these markets to other bidders.
Other examples include the attacks by the Yemeni Houthis on ships in the Red Sea, Iran’s entry into the
conflict between Israel and Hamas, and the collapse of the Syrian government, increasing tensions in the
world's largest oil-producing region. Also, Venezuelan land claims within the territory of Guyana may
increase volatility in the oil and gas market.
Protectionist measures have gained prominence on the world stage at the beginning of 2025, raising
concerns about the potential effects of increased sanctions on Iran, Russia and Venezuela, as well as the
enactment of import tariffs by the US on major oil players such as China (a major consumer) and Canada (a
major producer). These developments could affect global trade flows, intensify competition in international
markets, and increase operational costs, creating challenges for us in securing supplies, maintaining cost
efficiency, and accessing affected markets.
In addition, potential supply chain delays or interruptions, significant increase in costs, as well as
heightened volatility in oil, LNG and natural gas prices, could have an adverse effect on demand for our
goods and services and the price of our securities.
6.e) We are vulnerable to increased debt service resulting from depreciation of the real in relation to the
U.S. dollar and increases in prevailing market interest rates.
As of December 31, 2024, 77.3% of our finance debt was denominated in currencies other than the real. A
depreciation of the real against other currencies will increase our debt service in reais, as the amount of
reais necessary to pay principal and interest on foreign currency debt will increase with this depreciation.
Foreign exchange variations may have an immediate impact on our reported expenses and incomes. Some
of our operating expenses, capital expenditures, investments and import costs will increase in the event of
a depreciation of the real. In turn, as most of our revenues are denominated in reais, but linked to
international oil and oil products dollar prices, unless we increase the prices of our products in the local
market to reflect the depreciation of the real, our cash generation relative to our capacity to service debt
may decline.
Debt service can also be impacted by changes in interest rates. To the extent we refinance our maturing
obligations with newly contracted debts, we may incur additional interest expenses.
As of December 31, 2024, 38.4% of our finance debt consisted of floating rate debt. We generally do not
enter into derivative contracts or similar financial instruments or make other agreements with third parties
to hedge against the risk of an increase in interest rates.
To the extent that floating rates rise, we may incur in additional expenses. Moreover, as we refinance our
existing debt in the coming years, the mix of our indebtedness may change, specifically as it relates to the
ratio of fixed to floating interest rates, the ratio of short-term to long-term debt, and the currencies in
which our debt is denominated or to which it is indexed. Changes that affect the composition of our debt
and cause rises in short- or long-term interest rates may increase our debt service payments, which could
have an adverse effect on our results and financial condition.
6.f) External factors could impact the successful implementation of our partnerships and portfolio
management.
In accordance with our business planning, portfolio management encompasses the acquisitions,
partnerships and divestment movements. In this context, we have assets at different stages.
External factors, such as the decline of oil prices, exchange rate fluctuations, the deterioration of the
Brazilian economy and global economic conditions, the Brazilian political scenario, judicial and
administrative decisions, the passing of new legislation, regulatory policies, among other unpredictable
factors, may reduce, delay or hinder opportunities to buy and/or sell assets, or affect the price at which we
can buy and/or sell them.
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Our Business Plan is reviewed annually. If our Strategic and Business Plans are amended, including due to
decisions of the Brazilian federal government as our controlling shareholder, our portfolio management
guidelines might be revised. See risk factor “2.a) Our controlling shareholder may pursue certain objectives
that may differ from those of certain minority shareholders, or that may affect our long-term strategy” in
this section. In addition, any changes to our Board of Directors, Executive Board and our management team
may affect not only our ability to implement our Strategic and Business Plans, but also whether that
Strategic Plan remains in place, as well as the direction of any subsequent plans, including decisions related
to the management of our operations and investments.
6.g) Developments in the economic environment, the oil and gas industry and other factors have resulted,
and may result, in substantial write-downs of the carrying amount of certain of our assets, which could
adversely affect our results.
We evaluate on an annual basis, or more frequently when necessary, the carrying amount of our assets for
possible impairments. Our impairment tests are performed by a comparison of the carrying amount of an
individual asset or a cash generating unit with its recoverable amount, whether in operation or in
implementation. Whenever the recoverable amount of an individual asset or cash generating unit is less
than its carrying amount, an impairment loss is recognized to reduce the carrying amount to the recoverable
amount.
Changes in the economic, regulatory, business or political environment in Brazil or other markets where we
operate may have a material impact on the assumptions used to conduct impairment tests. For example, a
significant decline in international crude oil and gas prices, depreciation of the real, changes in financing
conditions, such as deterioration of risk perception and interest rates for assets and projects, among other
factors, may affect the original profitability estimates of our projects, which could imply impairment and
adversely affect our results.
7) Risks related to the regulation of the sectors in which we are involved
7.a) Divergences in interpretations and new legal and/or regulatory agency requirements in our sectors
of operation may result in the need to increase investments, expenses and operating costs, and it may
cause delays in production or even reduce the market for our products.
Our activities are subject to regulation and supervision by regulatory agencies, such as ANP, ANEEL, ANA,
ANTAQ, ANVISA and ANM, as well as other agencies, such as CADE, ANPD, IBAMA, ICMBio, IPHAN and others
in the Brazilian States and Municipalities. The following issues, among others, are subject to a regulatory
regime overseen by Brazilian regulatory agencies:
_ market concentration along the natural gas and oil products value chains;
_ allocation of natural gas transportation costs among market participants;
_ oil product specifications;
_ percentage of mandatory addition of biofuels to fossil fuels;
_ compliance with local content requirements;
_ procedures for the unification of areas;
_ rules related to the monitoring and decommissioning of wells;
_ definition of reference prices for the calculation of royalties and government participation;
_ procedures for mandatory investment in research, development and innovation;
_ mediation/determination of allocation of handling capacity in pipelines and maritime terminals; and
_ requirements established within the scope of environmental licensing processes.
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Regulatory changes considered unfavorable by the industry, as well as change or differences of
interpretation between us and regulatory agencies may directly affect the technical and economic
assumptions that guide our investment decisions and materially impact our results and financial condition.
Furthermore, there are regulatory uncertainties with respect to low-carbon technologies and energy
transition projects.
Legal changes may impact the markets for aviation fuels, diesel and gasoline, for example, with increased
mandates for biofuels or the imposition of restrictions for internal combustion engines. The Brazilian legal
frameworks related to the low-carbon economy and energy transition, such as carbon capture and storage,
offshore wind power plants and production of hydrogen from renewable sources, are still being defined.
Therefore, the markets and projects for these initiatives, for now, are gradually evolving in Brazil. As a result,
potential delays in establishing such frameworks could hinder us from achieving low-carbon and energy
transition goals.
7.b) We do not own any subsoil accumulations of crude oil and natural gas in Brazil.
Under Brazilian law, the Brazilian federal government is the owner of all the country’s mineral resources,
including subsoil accumulations of crude oil and natural gas. According to Brazilian regulations, the
concessionaire or contracted party owns the oil and gas it produces from these subsoil accumulations
pursuant to the exploration and production contracts signed with the Brazilian federal government. We
possess, as a concessionaire or contracted party of certain oil and natural gas fields in Brazil, the exclusive
right to develop and produce the volumes of crude oil and natural gas included in our reserves pursuant to
the respective exploration and production contracts, for a specific time frame. The access to crude oil and
natural gas reserves is essential to an oil and gas company’s sustained production and generation of
income, and our ability to generate income could be adversely affected if there are restrictions on the
exploitation of these crude oil and natural gas reserves or on the exploration of exploratory blocks, due to
changes in current legislation, environmental restrictions or implementation of exception measures.
8) Risks related to foreign countries where we are involved
8.a) We have assets and investments in other countries, where the political, economic and social situation
may negatively impact our business.
We have presence in other countries in South America and Africa, and may operate business in countries
where there may be political, economic and social instabilities. In such regions, external factors may
negatively affect the results and financial condition of our subsidiaries, including:
_ imposition of price control;
_ imposition of restrictions on hydrocarbon exports;
_ fluctuation of local currencies against the real;
_ nationalization of our oil and gas reserves and our assets;
_ increases in export tax and income tax rates for oil and oil products;
_ unilateral (governmental) and contractual institutional changes, including controls on investments
and limitations on new projects; and
_ geopolitical crisis.
If one or more of the risks described above occurs, we may fail to achieve our strategic objectives in these
countries or in our international operations as a whole, which may negatively impact our results and financial
resources.
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9) Risks related to social issues
9.a) Our projects and operations may negatively affect different communities, especially in relation to
human rights. Such projects and operations may also be affected by the expectations and dynamics of
these populations, impacting our business, image and reputation.
It is part of our policy to respect human rights, mitigate risks, remedy violations, and maintain responsible
relationships with employees and the communities where we operate and to be diligent with suppliers and
partners. However, throughout the life of projects and operations, we may inadvertently commit or
contribute to human rights violations in our activities, operations, and contracts due to non-compliance
with the guidelines of the Code of Ethical Conduct, and the Human Rights Guidelines, as well as any error in
the process of identifying and assessing human rights risks in HR management, the supply chain,
partnerships and communities.
Our activities can have an impact on the social dynamics of the communities where we operate, including
but not limited to, economy, culture, political system, environment, health and well-being, individual and
property rights, and people’s fears and aspirations. We have no control over changes in local dynamics or
the expectations of the communities where we operate.
Our direct and indirect decisions and activities may cause social impacts, especially due to investments,
mergers, acquisitions, divestments, decommissioning and operations in new production frontiers, which
may affect the schedule or budget of our projects, hinder our operations due to possible lawsuits, have a
negative financial impact and damage our image and reputation.
Furthermore, the various locations where we operate are exposed to a wide range of issues related to
political, social and economic instability, as well as intentional acts such as illegal taps, crime, theft,
sabotage, roadblocks and protests.
For further information regarding our main activities, initiatives, management practices, indicators and
commitments related to ESG issues, please see our Sustainability Report or our Human Rights and
Corporate Citizenship Supplement available on our website at www.petrobras.com.br/ir.
9.b) Considering that our projects and operations involve third-party suppliers, the risk of violation of
human rights by such suppliers is possible, which may harm our image and reputation.
Despite the compliance mechanisms that our suppliers must adhere to, including contractual human rights
clauses and compliance with our Ethical Conduct Guide for Supplies and labor obligations, the risk of
violation of labor laws or human rights by our suppliers is possible, which may result in legal liabilities,
financial penalties, and damage to our reputation.
10) Risks related to environmental issues
10.a) Differing interpretations of numerous health, safety, environmental regulations and industry
standards that are becoming more stringent may result in increased capital and operating expenditures
and reduced production, as well as the application of sanctions and difficulty in obtaining or renewing
licenses.
Our activities are subject to evolving industry standards, best practices and a wide variety of federal, state
and local laws, regulations and permit requirements related to the protection of human health, safety and
the environment, climate change policy, regulation of carbon emissions and the enactment of new
regulatory frameworks for activities of interest, both in Brazil and in other jurisdictions where we operate
or market our products. These laws, regulations and requirements may result in significant additional costs,
which may have a negative impact on the profitability of projects that we intend to implement or may make
such projects economically unfeasible.
Any substantial increase in expenditures for compliance with health, safety or environmental regulations
may have a material adverse effect on our results and financial condition. These increasingly stringent laws,
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regulations and requirements may result in significant decreases in our production, including unplanned
shutdowns, which may also have a material adverse effect on our results and financial condition.
There are constant changes in norms and laws related to occupational health, and often, there are
divergences between them. In addition, the judicialization of health-related issues is increasingly frequent,
as are issues related to the characterization of work accidents and all its consequences, in the civil, labor,
administrative and even criminal spheres.
In addition, the implementation of the Digital Bookkeeping System of Tax, Social Security and Labor
Obligations (eSocial), established by Decree No. 8373/2014, has resulted in government oversight agencies
having easier access to workers' information (including those related to accidents at work), and
consequently these agencies have been more proactive in their activities.
Additionally, we have operational units in several metropolitan regions of the country and, in some of these
locations, the concentration of pollutants generated by a variable set of polluters (industries, passenger
cars, trucks, etc.) may exceed the air quality standards defined by legislation. In 2024, with the publication
of CONAMA Resolution 506/2024, more restrictive air quality standards coming into effect in 2025, 2033,
and 2044 were defined. This is likely to increase the requirements for the implementation of technological
improvements that aim to reduce air pollution in industrial units such as refineries, power plants and
terminals installed in regions that already have or are expected to present air quality problems. This may
include obstacles to obtaining or renewing operating licenses and the need to adopt new environmental
control practices, such as new types of practices, increasing frequency monitoring emissions and installing
new environmental protection equipment, generating higher costs for us. There is also a risk that the use
of fuels will be subject to restrictions related to the level of pollutant emissions, which may increase the
need for investments in refineries or market loss. It is possible that our efforts to comply with such
regulations result in increased expenditures, and failure to comply with such regulations may cause damage
to our reputation and lead to the payment of fines and indemnities to the affected parties.
We cannot guarantee that the planned schedules and budgets of our investment projects, acquisitions,
decommissioning and divestments, are not affected by the internal procedures of regulatory and
environmental agencies regarding the issuance of relevant licenses and permits in a timely manner.
Potential delays in obtaining permits and consents can impact our oil and natural gas production goals,
especially in New Frontiers, negatively influencing our results and financial condition.
We are also subject to sanctions that may result in delays in the delivery of some of our projects and
difficulties in achieving our oil and gas production goals, such as partial or total embargoes or interdictions.
In addition, changes in interpretation or differing interpretations regarding health, safety and
environmental regulations, as well as our decision to settle any claims related to such regulations, may have
a material adverse effect on our financial condition and results.
10.b) Our commitments to protect the environment rely on our efforts, but also our engagement with
suppliers and management of other external factors, which affect the achievement of our strategy.
Our Business Plan establishes environmental commitments related to a circular economy, water security,
climate change and biodiversity gains focused on forests and oceans, among others, that have highly
complex activities associated with them in the coming years. These commitments rely on different
stakeholders to be implemented, and we face various challenges in fulfilling them. If we are not able to
overcome these challenges properly, we may need to review our environmental commitments ambitions.
Annual Report and Form 20-F 2024 I 51
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11) Risks related to climate issues, including physical and transitional risks
11.a) Climate change could impact our results and strategy.
Climate change poses new challenges and opportunities for our business. With the aggravation of climate
change and the advances in regulations, if we do not adapt to new global challenges, we may be subject to
financial, reputational and legal impacts, which could adversely affect our cash flow, and result in the
reduction of our competitiveness, diminishing shareholder value and failure to meet other stakeholders’
expectations. Changes in environmental conditions could potentially affect some of the operating
conditions in our assets, such as water availability or meteorological and oceanographic patterns.
There is growing concern that climate change will affect the frequency of regional atmospheric circulation
patterns leading to changes in meteorological and oceanographic conditions. These conditions may result
in extreme weather events, such as waves, wind, and changes in ocean current patterns, which may cause
significant damage and deterioration to our offshore facilities. Our resilience studies for offshore facilities
use a return period of 50 to 100 years to account for extreme wind and wave conditions. However, due to
climate change, this return period may be significantly reduced.
Stricter environmental regulations, including policy-driven responses aimed at mitigating climate change,
such as GHG emission permits and other mitigation responses, can potentially increase operating costs and
reduce production.
Law No. 15,402/2024 which establishes general rules for the Carbon Market in Brazil, was approved in
November 2024 by the Senate and the House of Representatives and was signed into law by Brazil’s
president in December 2024. However, the definition of emissions caps and reduction factors will depend
on future regulations, which could lead to increased expenses and affect our Business Plan.
A growing number of investors are seeking to align their investments with medium and long-term climate
policies. Investors’ increased perception of climate risks and more significant regulatory restrictions related
to carbon-intensive sectors, can lead to greater difficulty accessing capital and increased costs.
We foresee increasing pressure to develop and use more advanced technologies to improve our operational
performance in emissions to keep up with the demands of a world oriented towards a low-carbon economy.
Risk arises from the loss of competitiveness due to the non-implementation of technologies or the
implementation of ineffective technologies that could apply to our business. This could also potentially
impact our reputation related to our climate change mitigation initiatives and targets.
Increased demand for energy and other products with lower carbon intensity may negatively impact the
demand for oil and cause a drop in oil prices more significant than predicted in our planning. In Brazil, the
replacement of fossil fuels, particularly in the transportation sector, due to public policies such as “Fuel of
the Future” (Combustível do Futuro) or Renovabio and other potential initiatives and trends may affect
Brazil’s market and compromise our expected revenues.
Furthermore, we are subject to increasing demands related to transparency and ESG management. Any
misalignment between these demands and the approach adopted by us in our governance and management
could result in questions from regulatory bodies. Failure to comply with regulatory standards or the
perception of a lack of transparency could harm our image and reputation and affect our financial results.
These factors may have a negative impact on demand for our products and services and may jeopardize or
even impair the implementation and operation of our business, adversely impacting our results and
financial condition and limiting some of our growth opportunities.
For further information on how climate changes could impact our Strategic Plan, please see risk factor “1.e)
The selection and development of our investment projects have risks that may affect our expected results”
in this section.
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11.b) Water scarcity events in some regions where we operate may impact the availability of water in
quantity a n d / o r quality required for our operations, as well as difficulties in obtaining water use
permits, impacting the business continuity of our industrial units.
We have industrial facilities that use water, ranging from large users, such as refineries, to small users, such
as transport terminals that, although not very hydro intensive, are logistically important within our value
chain. In recent years, several regions of the world, including some regions in Brazil, have experienced events
of temporary freshwater shortage, including for public consumption. In case of water scarcity, our water use
permits may be suspended or temporarily modified and, as a result, we may be required to reduce or
suspend our production activities, since the water availability for human and animal consumption has
priority over industrial use. This may temporarily jeopardize our business continuity, as well as generate
financial impacts on us and our image.
Situations of water scarcity in a watershed where industrial units are located may also result in the
formulation or expansion of requirements of water resources management agencies in relation to the
restriction of freshwater use for industrial purposes, and may require, for example, the installation of water
reuse units in operational units or even purchase of reused water from external sources. Such situations can
lead to the need for investments and increased operating costs for this purpose.
Water scarcity may also result in the more intense activation of thermoelectric plants, which serve as a
complementary energy generating source to renewable energy. In addition, given that the Brazilian
northern region strongly depends on the rivers to carry on logistics, the water scarcity may affect
navigability in that region, impacting the logistics processes of products and inputs and, consequently, the
operational continuity and the fulfillment of customer commitments.
12) Risks related to the use of our trademark
12.a) The performance of companies licensed to use our brands may impact our image and reputation.
Our former divestment plan, which we followed until 2022, included the partial or total sale of our companies
in the fuel distribution segment and some of these deals involved licensing agreements for our brands.
Once a licensee holds the right to display our brands in products, services and communications, it may be
perceived by stakeholders as us; our legitimate representative or spokesperson. Licensees’ actions or
events related to their business, such as: failures, accidents, human rights violations, errors in business
performance, environmental crisis, corruption scandals and improper use of our brands, among other
factors – may negatively impact our image and reputation, with possible financial losses.
13) Risks related to shares and debt securities
13.a) The size, volatility, liquidity or regulation of the Brazilian securities markets may curb the ability
of holders of ADSs to sell the common or preferred shares underlying our ADSs.
Our shares are among the most liquid traded on the B3, but overall, the Brazilian securities markets are
smaller, more volatile and less liquid than the major securities markets in the United States and other
jurisdictions, and therefore may be regulated differently from the way in which U.S. investors are
accustomed. Factors that may specifically affect the Brazilian stock markets may limit the ability of holders
of ADSs to sell the common or preferred shares underlying our ADSs for the price and time they desire.
13.b) Holders of our ADSs may be unable to exercise preemptive rights with respect to the shares
underlying the ADSs.
Holders of ADSs who are residents of the United States may not be able to exercise the preemptive rights
relating to the shares underlying our ADSs, unless a registration statement under the Securities Act is
effective with respect to those rights or an exemption from the registration requirements of the Securities
Act is available. We are not obligated to file a registration statement with respect to shares relating to these
Annual Report and Form 20-F 2024 I 53
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preemptive rights and therefore we may not file such registration statement. If a registration statement is
not filed or there is no exemption from registration, JPMorgan, as the depositary institution, will attempt
to sell the preemptive rights and the holders of ADSs will be entitled to receive the proceeds of the sale.
However, the preemptive rights will expire if the depositary cannot sell them. For a more complete
description of the preemptive rights with respect to the common or preferred shares, see “Shareholders
Information – Shareholders’ Rights – Other Shareholders’ Rights” in this annual report.
13.c) If holders of our ADSs exchange their ADSs for shares, they risk losing the ability to timely remit
foreign currency abroad and other related advantages.
The Brazilian custodian of our shares underlying our ADSs must obtain a certificate of registration from the
Central Bank of Brazil to be entitled to remit U.S. dollars abroad for payments of dividends and other
distributions relating to our shares or upon the disposal of the shares.
The conversion of ADSs directly into ownership of the underlying shares is governed by CMN Resolution No.
4,373 and foreign investors wishing to do so are required to appoint a representative in Brazil for the
purposes of CMN Resolution No. 4,373, who will be in charge of keeping and updating the investors’
certificates of registration with the Central Bank of Brazil, which entitles registered foreign investors to buy
and sell directly on the B3. Such arrangements may require additional expenses from the foreign investor.
Moreover, if such representatives fail to obtain or update the pertinent certificates of registration,
investors may incur additional expenses or be subject to operational delays which could affect their ability
to receive dividends or distributions relating to the common or preferred shares or the return of their capital
in a timely manner.
The custodian’s certificate of registration or any foreign capital registration directly obtained by such
holders may be affected by future legislative or regulatory changes, and we cannot assure such holders that
additional restrictions applicable to them, the disposal of the underlying common or preferred shares or
the repatriation of the proceeds from the process will not be imposed in the future.
13.d) Holders of our ADSs may face difficulties in protecting their interests.
Our corporate affairs are governed by our Bylaws and Law No. 6,404/76 (“Brazilian Corporate Law”), which
differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States
or elsewhere outside Brazil. In addition, the rights of an ADS holder, which are derivative of the rights of the
holders of our shares, as the case may be, to protect their interests, are different under Brazilian Corporate
Law than under the laws of other jurisdictions. The laws concerning insider trading, self-dealing,
shareholder rights, and the preservation of shareholders’ interests may also be different in Brazil compared
to the United States.
Additionally, the structure of a class action in Brazil is different from that in the United States. Under
Brazilian law, shareholders of Brazilian companies do not have standing to bring a class action and, under
our Bylaws, must, generally with respect to disputes concerning rules regarding the operation of capital
markets, arbitrate such disputes. For more information, see “Shareholder Information – Shares and
Shareholders – Dispute Resolution” in this annual report.
We are a state-owned company controlled by the Brazilian federal government organized under the laws of
Brazil and all our directors and officers reside in Brazil. Substantially all of our assets and those of our
directors and officers are located in Brazil.
As a result, it may not be possible for holders of ADSs to effect service of proceedings upon us or our
directors and officers within the United States or other jurisdictions outside Brazil or to enforce against us
or our directors’ and officers’ judgments obtained in the United States or other jurisdictions outside Brazil.
Because judgments in U.S. courts for civil liability based on U.S. federal securities laws may only be enforced
in Brazil if certain requirements are met, holders of ADSs may face more difficulties in protecting their
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interest in actions against us or our directors and officers than the shareholders of a company incorporated
in a state or other jurisdiction of the United States.
13.e) Holders of our ADSs do not have the same voting rights as the holders of our shares. In
addition, holders of ADSs representing preferred shares are not entitled to vote most of decisions.
Holders of our ADSs do not have the same voting rights as holders of our shares. Holders of our ADSs are
entitled to the contractual rights set forth for their benefit under the terms of the deposit agreements. ADS
holders exercise voting rights by providing instructions to the depositary, as opposed to attending
shareholders’ meetings or voting by other means available to shareholders. In practice, the ability of a
holder of ADSs to instruct the depositary as to voting will depend on the time and procedures for providing
instructions to the depositary, either directly or through the holder’s custodian and clearing system.
In addition, a portion of our ADSs represents our preferred shares. Under Brazilian Corporate Law and our
Bylaws, holders of preferred shares are entitled to vote on specific agenda items in shareholder meetings,
such as the separate election of the Board of Directors and the Fiscal Council. Holders of ADSs representing
preferred shares are not entitled to vote most of decisions. For more information, see “Shareholder
Information – Shareholders’ Rights – Shareholders’ Meetings and Voting Rights” in this annual report.
13.f) The market for PGF’s debt securities may not be liquid.
Some of PGF’s notes are not listed on any securities exchange and are not quoted through an automated
quotation system. Most of PGF’s notes are currently listed both on the NYSE and the Luxembourg Stock
Exchange and are traded on the NYSE Euronext and MTF markets, respectively, although some trading in
PGF’s notes occurs over-the-counter. PGF can issue new notes that can be listed on markets other than the
NYSE and the Luxembourg Stock Exchange and traded on markets other than the NYSE Euronext and the
MTF market. We can make no assurance as to the liquidity of or trading markets for PGF’s notes. We cannot
guarantee that the holders of PGF’s notes will be able to sell their notes in the future. If a market for PGF’s
notes does not develop, holders of PGF’s notes may not be able to resell the notes for an extended period
of time, if at all.
13.g) We would be required to pay judgments of Brazilian courts enforcing our obligations under the
guarantee relating to PGF’s notes only in reais.
If proceedings were brought in Brazil seeking to enforce our obligations in respect of the guarantee relating
to PGF’s notes, we would be required to discharge our obligations only in reais. Under Brazilian exchange
controls, an obligation to pay amounts denominated in a currency other than reais, which is payable in Brazil
pursuant to a decision of a Brazilian court, will be satisfied in reais at the exchange rate in effect on the date
of payment, as determined by the Central Bank of Brazil.
13.h) A finding that we are subject to U.S. bankruptcy laws and that the guarantee executed by us was a
fraudulent conveyance could result in PGF’s noteholders losing their legal claim against us.
PGF’s obligation to make payments on the PGF notes is supported by our obligation under the
corresponding guarantee. We have been advised by our external U.S. counsel that the guarantee is valid
and enforceable in accordance with the laws of the state of New York and the United States. In addition, we
have been advised by our general counsel that the laws of Brazil do not prevent the guarantee from being
valid, binding and enforceable against us in accordance with its terms. In the event that U.S. federal
fraudulent conveyance or similar laws are applied to the guarantee, and we, at the time we entered into the
relevant guarantee:
_ were either insolvent or rendered insolvent by reason of our entry into such guarantee;
_ were either engaged in business or transactions for which the remaining assets with us constituted
unreasonably small capital; or
_ intended to incur or incurred, or believe or believed that we would incur, debts beyond our ability to
pay such debts as they mature; and
Annual Report and Form 20-F 2024 I 55
Risks
_ in each case, intended to receive or received less than reasonably equivalent value or fair
consideration therefor, then our obligations under the guarantee could be avoided, or claims with
respect to that agreement could be subordinated to the claims of other creditors.
Among other things, a legal challenge to the guarantee on fraudulent conveyance grounds may focus on
the benefits, if any, realized by us as a result of the issuance of the PGF notes. To the extent that the
guarantee is held to be a fraudulent conveyance or unenforceable for any other reason, the holders of the
PGF notes would not have a claim against us under the relevant guarantee and would solely have a claim
against PGF. We cannot ensure that, after providing for all prior claims, there will be sufficient assets to
satisfy the claims of PGF noteholders relating to any avoided portion of the guarantee.
Corporate Risk Management
We believe that integrated and proactive risk management is essential for the delivery of results in a safe
and sustainable way. Our risk management policy establishes guidelines and responsibilities, and is based
on the following fundamental principles:
_ respect for life and life diversity;
_ full alignment and consistency with our Strategic Plan;
_ ethical behavior and compliance with legal and regulatory requirements;
_ integrated risk management; and
_ the risk response actions consider the possible long-term cumulative consequences, the possible
impacts on our stakeholders and should be oriented towards preserving and adding value and for
business continuity.
The risk management organizational structure, that is under the supervision of our CFO, is responsible for:
_ establishing a corporate methodology for risk management guided by an integrated and systemic
view, which allows for an environment of continuous monitoring of risks in several hierarchical levels;
_ disseminating knowledge and supporting the use of risk management practices in organizational
units; and
_ identifying, monitoring and reporting periodically to our Executive Officers and Board of Directors
regarding our major risks.
In order to support the risk management process, our corporate risk management policy specifies
authorities to be consulted, responsibilities to be undertaken, and five principles and ten guidelines that
drive our risk management initiatives.
This policy has a comprehensive approach to corporate risk management, which combines the traditional
economic and financial risk management approach with other relevant areas of interest, such as protection
of life, health and environment, assets and business information protection (property and security) and
combating fraud and corruption (legal and compliance), among other corporate risks.
For further information regarding our revised business risk management policy, please visit our website at
www.petrobras.com.br/ir.
Annual Report and Form 20-F 2024 I 56
Risks
Disclosures about Market Risk
Commodity Price Risk
We operate in an integrated manner throughout the various stages of the oil industry. A significant portion
of our results relate directly to oil exploration and production, refining and the sale of natural gas, biofuels,
and electricity in Brazil. As our purchases and sales of crude oil and oil products are linked to international
commodity prices, we are exposed to their price fluctuations, which may influence our profitability, our cash
flow from operations and our financial situation.
We prefer to maintain exposure to the price cycle than use financial derivatives to systematically protect
purchases and sale transactions that focus on fulfilling our operation needs. However, based on crude oil
market conditions and prospects of realization of our Strategic Plan, we may decide to implement
protection strategies using financial instruments to manage our cash flows.
In addition, we are party to derivative contracts in order to protect our margins for short-term commercial
transactions carried out abroad. Our derivatives contracts provide economic hedges for oil product
purchases and sales in the global markets, generally expected to occur within a 30 to 360-day period.
For more information about our commodity derivatives transactions, including a sensitivity analysis
demonstrating the net change in fair value of an adverse change in the price of the underlying commodity
for options and futures, see Note 33 to our audited consolidated financial statements.
Exposure to interest rate and exchange rate risk
For information about interest rate and exchange rate risk, see “Operating and Financial Review and
Prospects” in this annual report.
Insurance
Regarding operational risks, our policy is to maintain insurance coverage when the obligation to maintain
such coverage derives from a legal or contractual instrument or our Bylaws; or the event covered may cause
significant damage to our financial results, and coverage is economically feasible.
We maintain several insurance policies, including policies against fire, operational risk, engineering risk,
property damage coverage for onshore and offshore assets such as fixed platforms, floating production
systems and offshore drilling units, well-control in drilling and workover activities in Brazil, hull insurance
for tankers and auxiliary vessels, third party liability insurance and transportation insurance. The coverages
of these policies are hired according to the objectives we define, and the limitations imposed by the global
insurance and reinsurance markets. Although some policies are issued in Brazil, most of our policies are
reinsured abroad with reinsurers rated A- or higher by Standard & Poor’s or A3 and/or higher by Moody’s
and/or B++ or higher by A.M. Best.
Our policies are subject to deductibles, limits, exclusions and limitations, and there is no assurance that such
coverage will adequately protect us against liability from all possible consequences and damages
associated with our activities. Thus, it is not possible to assure that insurance coverage will exist for all
damages resulting from possible incidents or accidents, which may negatively affect our results.
We do not maintain insurance coverage to safeguard our assets in case of war or sabotage. We also do not
maintain coverage for business interruption, except for some specific assets in Brazil. In addition, our third-
party liability policies do not cover government fines or punitive damages.
We do not currently maintain insurance coverage for cyber related incidents given the cost and limitations
on obtaining adequate coverage in the insurance and reinsurance markets for a company of our size. We will
continue to evaluate our options for obtaining such insurance coverage.
Annual Report and Form 20-F 2024 I 57
Risks
The maximum deductible amount of our national property damage policies is US$200 million, and their
indemnity limits can reach US$2 billion for refineries and US$2.35 billion for platforms, depending on the
replacement value of our assets.
Our general third-party liability policy with respect to our onshore and offshore activities in Brazil, including
losses due to sudden pollution, such as oil spills, has a maximum indemnity limit of US$250 million with an
associated deductible of US$10 million. We also maintain marine insurance with additional protection and
indemnity against third parties related to our domestic offshore operations with an indemnity limit of
US$50 million up to US$500 million, depending on the type of vessel. For activities in Brazil, in the event of
an explosion or similar event on one of our non-fixed offshore platforms, these policies may provide third-
party combined liability coverage of up to US$750 million. In addition, although we do not insure most of
our pipelines against property damage, we have insurance against damages or losses to third parties arising
from specific incidents, such as unexpected infiltration and oil pollution.
Furthermore, we receive surveys from the insurance market that evaluate the operational risks of our
facilities and provide recommendations. Currently, we directly hire a consultancy company to conduct this
inspection program, and these surveys are shared with the insurance market.
In general, the risk ratings of our assets are at or above the market average. In 2024, we had surveys in 19
onshore and offshore units. Based on these surveys, last year we heeded around 125 recommendations that
contribute to the improvement of safety and risk management associated with the operation of our
facilities.
Outside Brazil, we maintain different levels of third-party liability insurance, as a result of a variety of
factors, including country risk assessments, whether we have onshore and offshore operations, or legal
requirements imposed by a particular country in which we operate. We maintain separate well-control
insurance policies in our international operations to cover liabilities arising from the uncontrolled eruption
of oil, gas, water or drilling fluid. In addition, such policies cover claims of environmental damage caused by
wellbore explosion and similar events as well as related clean-up costs with coverage limits of up to US$350
million and US$1 billion, depending on the country.
Annual Report and Form 20-F 2024 I 58
Risks
Cybersecurity Framework and Risk Management
In today’s technologically advanced world, data has become increasingly valuable, making information
security crucial for the success of any organization. Moreover, with the rise in global attacks on industrial
systems, particularly critical infrastructure, it has become imperative to prevent damage to business,
operations, reputation, and human lives. Over the years, we have developed a comprehensive set of
processes, policies and controls to mitigate Information and cybersecurity risks, drawing on global
frameworks and best practices that provide comprehensive protection for our business.
Laws and Regulations
With regards to privacy, we comply with Brazilian Law No. 13,709/2018 – General Personal Data
Protection Law (LGPD), and are subject to penalties in cases of disclosure or misuse of personal data.
We view the legislation on the protection of personal data as an opportunity to evolve our system to
greater maturity, adding continuous improvements to our privacy processes. To achieve excellence,
the process is conducted through a governance model, and the adoption of technical and
administrative measures to respond to legal requirements, mitigate data breach risks and guarantee
the data rights of our workforce and stakeholders as data subjects.
Governance
Management Structure
We have a dedicated Information Security executive management structure (SI), which operates
independently from the Information Technology (IT) department. This structure is responsible for
overseeing information security initiatives, establishing strategies and guidelines aligned with business
objectives, recommending investments to mitigate cyber risks, and providing adequate digital protection
for critical assets. Both the SI and IT report to the Chief Corporate Affairs Officer.
The Chief Information Security Officer, Samara Braz, leads the information security efforts and holds
multiple qualifications in IT and Information Security, including the following:
_ Certified in the Governance of Enterprise IT (CGEIT) from Information Systems Audit and Control
Association (“ISACA”);
_ Certified in Risk and Information Systems Control (CRISC) from ISACA;
We are subject to various Brazilian regulations regarding information security. Notably, Decree No.
9.637/2018 establishes the National Information Security Policy and Decree No. 11.856/2023
establishes the National Cybersecurity Policy and the National Cybersecurity Committee, while
Normative Instruction 1/2020 GSI/PR (Institutional Security Office) guides the structure for
managing information security, including the establishment of the Information Security Committee
(the “CSI”). Additionally, we comply with other general rules such as Brazilian Law No. 12.527/2011
(Access to Information Law), which governs public access to information.
Annual Report and Form 20-F 2024 I 59
Risks
_ Certified Data Privacy Solutions Engineer (CDPSE) from ISACA;
_ Certified Information Security Manager (CISM) from ISACA;
_ Certified Information Systems Auditor (CISA) from ISACA and
_ Certified Chief Information Security Officer (CCISO) from International Council of E-Commerce
Consultants (EC-Council).
Additionally, we have an Information Security Committee (CSI) composed of members appointed by our
executive board. The CSI advises on information security matters, aligning them with the National
Information Security Policy and our business objectives, with strategic issues discussed quarterly.
The Security Information Management team holds regular meetings to address operational and strategic
concerns, in addition to routine interactions. Monthly discussions are held to monitor key security
indicators, management processes and project management.
Role of the Board of Directors, Executive Board and Committees
Our senior management receives periodic reports on risks from Petrobras’ corporate risk matrix based on
their assessed severity. These reports include strategic risks and risks of very high and high severity –
including those related to cybersecurity and information security. They follow a standardized model with
an annual timeline for specific risk management actions, detailing managed risks and main response
actions. Senior management also monitors the evolution of the risk matrix and the deadlines for response
plans.
Strategic risks are those business risks that, due to their relevance to meeting our strategic objectives, are
monitored by the Executive Board and Board of Directors, which schedule quarterly presentations. Recently,
cybersecurity risks have been classified as strategic due to their relevance, interconnectedness and impact
on the business.
The Board of Directors approves the company’s risk profile and oversees the company’s risk management
with advice from the Audit Committee.
The CSI evaluates and monitors the Information Security Management System, cybersecurity and
information security risks, and the execution of risk treatment plans and guidelines.
The CISO manages information security initiatives, establishes strategies aligned with business objectives
and regulation, and recommends investments to mitigate risks and protect critical assets.
Annual Report and Form 20-F 2024 I 60
Risks
Cybersecurity Strategy and Risk Management
Our layered defense approach integrates policies, processes, training, and cybersecurity technology to
protect and monitor our environment.
Our cybersecurity measures are primarily based on the National Institute of Standards and Technology
(“NIST”) Cybersecurity Framework. We use NIST best practices to assess our security maturity.
Cyber Defense
Our incident response plan encompasses preparation, detection, response, and recovery from cybersecurity
incidents, ensuring legal compliance and minimizing reputational damage.
A 24/7 Computer Security Incident Response Team (CSIRT) manages and coordinates responses to
cybersecurity events. Significant incidents that could affect investors’ decisions will be promptly reported
to the market as required by the SEC.
We are members of FIRST (Forum of Incident Response and Security Teams), a prominent global forum for
cybersecurity teams across various sectors and countries, focusing on prevention and improving global
information security.
We collaborate with global cybersecurity teams, sharing threat intelligence and best practices, and engage
in workshops, conferences, and partnerships to enhance security, privacy, and technological capabilities.
To reinforce our security measures, we:
_
engage independent companies for periodic vulnerability identification and penetration testing.
_
conduct regular information security reviews based on the NIST Cybersecurity Framework by third-
party auditors.
We have been enhancing our operational cybersecurity maturity by implementing a robust strategy to
safeguard industrial automation and control systems. This includes adopting advanced monitoring tools,
strengthening defense in-depth measures, conducting regular vulnerability assessments, simulating
industrial cybersecurity incidents and monitoring key performance indicators. These efforts aim to leverage
the resilience of critical operations by mitigating cyber risks in an increasingly connected industrial
environment.
Risk Management and Digital Controls
We regularly assess and manage risks related to cybersecurity in both corporate and industrial automation
and control system environments.
These risks are incorporated into our corporate risk matrix and monitored by senior management.
Our risk management process involves:
_
identifying threats and vulnerabilities.
_
implementing controls and mitigating measures.
_
assessing likelihood and impact using qualitative methodology.
We extend our cybersecurity risk management to third-party service providers by:
_
establishing cybersecurity requirements for business transactions.
_
contractually obligating vendors to maintain strict cybersecurity standards.
Currently, we do not maintain cybersecurity incident insurance due to market conditions, but we regularly
evaluate available options.
Annual Report and Form 20-F 2024 I 61
Risks
Our business strategy, operations, and financial condition have not been materially affected by
cybersecurity threats or previous incidents, but we cannot provide assurance that we will not be materially
affected in the future by such risks and any future material incidents.
In the past three fiscal years:
_
no material information security breaches occurred.
_
expenses from information security incidents were immaterial.
_
no penalties or settlements were incurred.
Digital Continuity Program
To ensure our ability to withstand a cyberattack scenario, we have established a comprehensive Digital
Continuity Plan. This plan aims to guarantee the uninterrupted functioning of critical processes in the event
of a crisis or digital disaster. We have implemented contingency measures for critical digital assets,
documented recovery procedures for these assets, and regularly test the effectiveness of our plans.
In managing serious incidents, we follow the Incident Command System, a corporate crisis handling
methodology. This methodology is also applied in our cybersecurity practices, ensuring a structured and
coordinated response to any significant incident. To further enhance our preparedness, we conduct
cybersecurity tabletop exercises, onboardings, and Tone at the Top trainings to new Board of Directors
members and Executive Officers. These training sessions cover corporate security information rules,
policies, best practices, and expected user behavior.
Training & Awareness
Our Information Security Awareness Plan includes, but is not limited to, the following activities:
_
security awareness education and training for both workforce and secondees.
_
internal “phishing” testing to assess susceptibility to email scams.
_
security training for new hires.
_
annual information security awareness campaigns and periodic cybersecurity newsletters, which
highlight emerging and urgent security threats.
_
specialized training, such as DevSecOps (i.e., development, security and operations) and OT
Cybersecurity (cybersecurity for operational technology), is also provided to specific audiences to
address their unique requirements.
Our Business
Annual Report and Form 20-F 2024 I 63
Our Business
Exploration & Production
Overview
Our oil and natural gas exploration and production activities are the major components of our portfolio and
include offshore and onshore exploration, appraisal, development, production and incorporation of oil and
natural gas reserves, producing oil and natural gas in a safe and profitable way.
Our activities are focused on deepwater and Ultra-deepwater oil reservoirs in Brazil, which accounted for
98% of our total production in 2024. We also have activities in mature fields in shallow waters and onshore,
as well as outside Brazil, as detailed below in this annual report. Brazilian exploration and production assets
represent 88% of our worldwide blocks and fields, 99% of our global oil production and 99.6% of our oil and
natural gas reserves.
Annual Report and Form 20-F 2024 I 64
Our Business
As of December 31, 2024, we had 232 blocks and fields in exploration and production, including 105 owned
by consortia with other oil and gas companies in Brazil and other countries. Of the 232 blocks and fields, 201
are under Concession Agreements, 22 are under Production Sharing Agreements and nine are regulated by
Transfer of Rights Agreements. Additionally, we approved the acquisition of participation in the Deep
Western Orange Basin (the “DWOB”) block in the Republic of South Africa, as described below, under
“Exploration & Production – Overview – International – Africa.”
EXPLORATION & PRODUCTION BLOCKS AND FIELDS (Number of blocks and fields)
Like most major oil and gas companies, we operate in partnerships using E&P consortia in the exploration
of blocks and the production of oil fields in Brazil, mainly in Ultra-deepwaters.
We lead and operate E&P consortia that are responsible for some major projects under development, such
as Mero, Atapu, Búzios and Sépia.
These E&P consortia also comprise some of the biggest production fields in Brazil, such as Búzios, Tupi,
Itapu and Mero.
For the names and interests of partners of each consortium, please refer to the section further below, “Our
Business – Production – Shared reservoirs: deposits between different fields”.
Annual Report and Form 20-F 2024 I 65
Our Business
Annual Report and Form 20-F 2024 I 66
Our Business
Other Basins
We produce oil and gas and hold exploration acreage in 15 other basins in Brazil, such as Espírito Santo.
International
Outside Brazil, we have E&P activities in South America, North America and Africa. We have focused on
opportunities to leverage the deepwater expertise we have developed in Brazil.
SOUTH AMERICA
We conduct exploration and production activities in Argentina, Bolivia and Colombia.
In Argentina, through our subsidiary Petrobras Operaciones S.A., we have a 33.6% interest in the Rio
Neuquén production asset. Our unconventional gas and Condensate production is concentrated in the
Neuquén Basin. In 2024, our production of oil and gas in Argentina, including NGL, was 10.6 mboed.
In addition, in September 2024, we signed a Memorandum of Understanding with YPF Sociedad Anónima,
our partner in Argentina, for joint discussions to explore possible business opportunities, technical and
technological cooperation in the E&P segment in that country. The agreement is non-binding and has a
term of three years.
In Bolivia, we produce gas and Condensate primarily in the San Alberto and San Antonio fields with 35%
interest in each of those service operation contracts, which are operated mainly to supply gas to Brazil and
Bolivia. In 2024, our production of oil and gas in Bolivia, including NGL, was 15.5 mboed. The return on such
contracts is a proportion of the production.
Annual Report and Form 20-F 2024 I 67
Our Business
In Colombia, we operate and hold a 44.44% interest in the GUA-OFF-0 offshore exploration block, which
encompasses the significant Sirius gas discovery. This operation is conducted through our subsidiary,
Petrobras International Braspetro B.V. - Sucursal Colombia (PIB-COL). Our partner, Ecopetrol S.A, holds the
remaining 55.56% interest in this consortium. In June 2024, the Sirius-2 appraisal well confirmed the largest
natural gas discovery ever made in Colombian offshore waters. This milestone discovery was officially
announced to the market in October 2024. By December 2024, Petrobras and Ecopetrol validated the Sirius-
2 well results, revealing gas volumes exceeding 6 trillion cubic feet (Tcf) in place, underscoring the potential
of this find.
COLOMBIA OFFSHORE
Natural gas production is expected to begin three years after obtaining the necessary environmental
licenses and confirmation of the discovery’s commercial viability. The development plan includes an
innovative “subsea to shore” production system, utilizing four wells.
In December 2024, the consortium announced an estimated investment of US$1.2 billion for the exploratory
phase and an additional investment of US$2.9 billion for the production development phase. Petrobras’s
share in these investments, through PIB-COL, is aligned with our Business Plan 2025-29.
This discovery marks a pivotal moment for Petrobras, reinforcing our commitment to energy leadership,
sustainable development, and value creation for both the company and Colombia.
NORTH AMERICA
In the United States, we focus on deepwater fields in the Gulf of Mexico, where we have non-consolidated
production from the 20% participation of Petrobras America Inc. in our joint venture with Murphy
Exploration & Production Company, the MPGOM LLC. The main production fields are Saint Malo, Dalmatian,
Lucius and Chinook. In 2024, our participation represented a production of 7.54 mboed, including NGL.
Annual Report and Form 20-F 2024 I 68
Our Business
AFRICA
In February 2024, we concluded the acquisition of interests in three exploratory blocks in the Democratic
Republic of São Tomé and Príncipe, and in October 2024, we approved the acquisition of participation in the
DWOB block in the Republic of South Africa, whose conclusion is currently subject to the approval of the
local regulatory bodies.
Main Assets
2024
2023
2022
Exploration & Production
Production wells (oil and natural gas)(1)
1,084
1,067
5,003
Floating rigs
28
25
19
Operated platforms in production(2)(3)
56
57
56
(1) Includes the total amount of wells of our equity method investees (42, 42 and 44 wells in 2024, 2023 and 2022, respectively).
(2) Includes only definitive production systems, EWT and EPs units.
(3) Does not include mothballed, non-producing and platforms in fields operated by partners.
Exploration
The oil and gas industry value chain begins in the exploratory phase, with the acquisition of exploratory
blocks either through bid rounds conducted by governments or by purchases from other companies.
We concentrate our efforts in Brazil, where the Brazilian State owns the oil deposits, but companies and
consortia are allowed to extract and explore such oil upon payment in several forms, such as royalties. Forms
of payment differ, depending on the applied regulatory model. Bidding rounds are the main process for the
acquisition of rights over the exploratory blocks.
There are currently three regulatory models in Brazil: Concession Agreements, Transfer of Rights
Agreements and Production Sharing Agreements. The Concession model fully governed the oil and natural
gas exploration and production until 2010, when the Brazilian federal government enacted laws establishing
the Transfer of Rights regime and the Production Sharing regime in the Pre-salt Polygon.
For information on the regulatory models applicable to our exploration and production activities, see “Legal
and Tax” in this annual report.
Annual Report and Form 20-F 2024 I 69
Our Business
Bidding rounds
Over the past few years, we have participated selectively in the bidding rounds carried out by the ANP,
aiming to reorganize our exploratory portfolio and maintain the relationship between our reserves and
our production in order to ensure the sustainability of our future oil and gas production. Our joint
operation with large oil companies in consortia is also aligned with our strategic goal to strengthen
partnerships, with the intent to share risks, combine technical and technological skills and capture
synergies to leverage results.
In 2022, we acquired the exploration and production rights of three exploratory blocks: Água Marinha
and Norte de Brava, both in the Campos basin, and Sudoeste de Sagitário, in the Santos basin. With
respect to the Água Marinha block, we exercised our preemptive right to be the operator with a 30%
interest. The other members of the consortium are TotalEnergies (30% interest), Petronas (20%
interest), and Qatar Petroleum (20% interest). As for the Norte de Brava block, we acquired the rights
to be the operator, with a 100% interest. As for the Sudoeste de Sagitário block, we acquired the rights
to be the operator with 60% interest, with Shell (40% interest).
For the names and interests of partners for the Atapu, Sépia and Brava, please refer to the section “Our
Business – Production – Shared reservoirs: deposits between different fields”.
In December 2023, ANP held public bidding rounds for the 4th Cycle of Permanent Offering of
exploratory blocks under the concession regime. With the participation of 17 companies from six
different countries, 192 blocks were awarded. In consortium with other companies, we won 29 blocks,
all located in the Pelotas Basin. The Pelotas Basin is located in the southern region of Brazil. All
acquired blocks are located in deepwater areas, around 200 km from the coast. We and our partners
signed the concession contracts in August and October 2024.
ANP did not offer bidding rounds in 2024.
Exploration Activities
As of December 31, 2024, we had 73 exploratory blocks, including 11 evaluation plans, and a total of eight
appraisal wells drilled. We serve as the operator in 63 of the exploration partnership blocks.
The table below breaks down our participation in exploration activities in 2024:
Annual Report and Form 20-F 2024 I 70
Our Business
OUR PARTICIPATION IN EXPLORATION ACTIVITIES IN 2024
Net exploratory area
(km2)
Exploratory blocks
(number)
Evaluation plans
(number)
Wells drilled
(number)
2024
2023
2022
2024
2023
2022
2024
2023
2022
2024
2023
2022
Brazil
34,457 27,924
35,198
67
43
65
10
9
13(1)
5
2
5
Other S. America
3,094
3,474
4,284
3
3
3
1
1
1
3
0
2
North America
0
0
0
0
0
0
0
0
0
0
0
0
Africa
7,802
0
0
3
0
0
0
0
0
0
0
0
TOTAL
44,633 31,398 39,482
73
46
68
11
10
14
8
2
7
(1)
These figures include only contracts signed through December 31, 2024 (which excludes the block held in South Africa).
In 2024, our exploratory efforts were concentrated on evaluating opportunities in the Santos Basin and in
the Potiguar Basin, with the following highlights.
SANTOS BASIN
In 2024, we concluded the evaluation test performed in the well drilled in the BM-S-50 block. We started the
drilling of the Tortuga Leste well and Curaçao Extremo Leste well, both included in the Curaçao Evaluation
Plan (ARAM block), and we are planning to conclude the analysis of these wells by the first half of 2025.
In 2024, we also drilled the well 9-BUZ-99D-RJS, located in the western region of the Búzios, 189 kilometers
off the coast of Rio de Janeiro and at a water depth of 1,940 meters. In February 2025, we confirmed the
presence of oil in the field. Tests conducted from a depth of 5,600 meters confirmed the presence of oil
reservoirs through electrical profiles, which will later be characterized through laboratory analyses. This is
a new accumulation in a zone below the main reservoir. The discovery reaffirms the Pre-salt potential of the
Búzios field.
EQUATORIAL MARGIN
In 2024, we concluded the drilling of the Pitu Oeste well (BM-POT-17 block) and Anhangá well (POT-M-
762_R15 block), in the Potiguar Basin, and identified the presence of hydrocarbons on both wells. Such
discoveries are under evaluation, aiming to assess the quality of the reservoirs, the characteristics of the
oil, and the technical-commercial viability of the accumulation.
Annual Report and Form 20-F 2024 I 71
Our Business
Equatorial Margin
The Equatorial Margin, located in the northern and northeastern regions of Brazil, stretches over 2,200
km between the states of Amapá and Rio Grande do Norte. This area is considered a significant
exploratory frontier in deep and Ultra-deepwaters. Five Basins are part of the Equatorial Margin: Foz
do Amazonas, Pará-Maranhão, Barreirinhas, Ceará and Potiguar. We are seeking authorization from
the Brazilian Institute of Environment and Renewable Natural Resources (IBAMA) for a Pre-Operational
Assessment (APO) and an Operating License to drill one exploratory well in the FZA-M-59 block,
located in Ultra-deepwaters off the coast of Amapá, approximately 175 km from the coast and 540 km
from the mouth of the Amazon River, at a water depth of over 2,800 meters.
There are no conservation units, indigenous lands, or proximity to rivers, lakes, floodplains, or reef
systems in the area. To address potential environmental impacts, such as the possible scenario of an
oil spill, we use modern techniques to model oil dispersion in the sea, following IBAMA’s requirements.
The modeling studies for the FZA-M-59 block indicate a low risk of oil reaching the Brazilian coast.
Nevertheless, we have proposed a coastal response structure for offshore and coastal areas, including
monitoring and veterinary care. In case of a spill, the response to local fauna is swift, with rescue
operations within 24 hours. Over 100 professionals are dedicated to animal protection, with fast
vessels equipped for animal stabilization and additional resources like monitoring and rescue aircraft.
We have adjusted flight routes and altitudes to minimize noise impact on indigenous communities,
with flights passing at least 13 km from the nearest indigenous village.
We have acknowledged the response from IBAMA and consider it a significant advancement in the
licensing process for the FZA-M-59 block in Amapá Deep Waters. There remains a request for detailed
information on the Fauna Protection Plan and the new fauna base in Oiapoque. Our technical team is
currently addressing each query to respond to IBAMA.
Annual Report and Form 20-F 2024 I 72
Our Business
OTHER BASINS
In 2024, we concluded the drilling of two wells in the Espírito Santo Basin. In Campos basin, we performed
exploratory activities in the Jubarte field, drilling one well in 2024. By the end of 2024, we started the drilling
of one well in the Norte de Brava block and began the preparation to start in January 2025 the drilling of
one well in the Alto de Cabo Frio Central block. Such operations aim to investigate the oil potential of the
region.
In 2024, we concluded the acquisition of 29 blocks in the Pelotas Basin. We have a 70% interest in 26 of
them (in partnership with Shell), and a 50% interest in three (in partnership with Shell, 30%, and CNOOC,
20%). We also started the seismic acquisition campaign in the Pelotas Basin.
PELOTAS BASIN
OTHER COUNTRIES
Following the 2022 discovery in the Wildcat Well Sirius -1 in Colombia, we are planning more exploratory
activities in this country. We, as operator, in partnership with Ecopetrol, intensified our exploratory
activities in the GUA-OFF-0 block and confirmed the most significant natural gas discovery in the offshore
of Colombia, after the drilling of Sirius-2 well.
In Argentina, we concluded two exploratory wells in 2024 in the Neuquen Basin. We highlight the
opportunity to assess the potential of shale oil in the Vaca Muerta Formation, in the Neuquén Basin, through
the drilling of another well in this region, concluded in January 2025.
In the African continent, we have acquired interests in three exploration blocks in the Democratic Republic
of São Tomé and Príncipe, and approved the acquisition of participation in one block in the Republic of
South Africa, subject to the approval of the local regulatory bodies. The transaction marks the resumption
of exploratory operations in the African continent, with the aim of diversifying our portfolio, and is in line
with our long-term strategy.
Annual Report and Form 20-F 2024 I 73
Our Business
For information on exploration expenditures written off, see Note 26 Exploration and evaluation of oil and
gas reserves of our audited consolidated financial statements.
E&P Strategic Programs Highlights
PROD1000
In 2024, the PROD1000 strategic program, which began in 2019, concluded all the initiatives planned by the
program related to exploration and reservoir development integration, project design standardization,
processes optimization and parallelization, and early engagement with suppliers. As a result, PROD1000 has
brought viable alternatives to potentially reduce the initial production development schedule to first oil.
The program has also delivered one patent, implemented three new digital tools, provided over six technical
specifications for different equipment, and implemented several process improvements in corporate
standards within the E&P.
Despite the conclusion of PROD1000, the gains from the program will continue to be incorporated into our
projects through a routine monitoring process across our project portfolio, in alignment with our Strategic
Plan.
EXP100
After five years, EXP100, the Exploration strategic program, was concluded in 2024, achieving remarkable
results. The program focused on data and AI democratization, leading to the development of 53 digital
solutions that effectively improved the integration and access to technical information.
A major milestone for the program was the advancement in High-Performance Computing (HPC) for the
company, significantly reducing seismic processing time and enhancing computational capacity to improve
geophysical data processing.
Additionally, digital transformation was accelerated through the creation of 47 interactive dashboards,
enabling greater agility and accuracy in analysis and decision-making. Altogether, 107 technological
solutions were developed, substantially improving exploration processes and reducing uncertainties and
costs.
Following the conclusion of the EXP100 program, a new strategic program, starting in 2025, will be
developed to align the company’s updated exploration strategies, reflecting our technological
advancements and priorities to address future challenges and lead the energy transition.
Production
Production Development
After a field is declared commercially viable, the process of production development begins. The
investments made in this phase are mainly focused on designing and contracting production systems, which
includes platforms, subsea systems, drilling, and the completion of wells.
With respect to well construction, in 2024, several initiatives were implemented, such as the application of
new drilling and completion technologies, optimization in the acquisition of reservoir data and the use of
integrated contracts. We are also continuously working to automate operations with a consequent
reduction in exposure to risk. We have reached a plateau in Well Construction Cost using current
technologies, with our performance remaining relatively stable with a maximum variation of 8% relative to
Annual Report and Form 20-F 2024 I 74
Our Business
the five-year average, which is 40% lower than the 2018–2019 baseline. Now, our primary challenge lies in
enhancing well reliability, integrity and availability to ensure sustained production efficiency.
Our average offshore Well Construction Duration (total time for drilling plus completion) had a 10% increase
when compared to 2023, with an average of 98.8 days/well in 2024, and the Well Construction Cost
performance showed an 9% increase when compared to 2023. The troubleshooting associated with the
implementation of new technologies, such as wet disconnect tool and conformable sand screen, and
operational issues, such as BOP failure and geomechanical challenges, are the main reasons associated with
these results. Specifically, in the Santos Basin Pre-salt area, we experienced a 2% increase in average
duration and a 2% increase in average cost compared to 2023.
In relation to Well Connection Cost performance in the Santos Basin Pre-salt area, we had a 13% increase in
average cost when compared to 2023, a level even lower than in the 2021-2022 period.
In the context of subsea systems, our investments in research and development seek to provide tools to
identify failure mechanisms more accurately and swiftly, increasing the reliability of operations. New
inspection technologies have been widely used and contribute to the integrity of subsea systems, especially
those pipelines susceptible to CO2-induced corrosion. Also, the use of digital technologies such as the
Digital Twin for Stress Corrosion Cracking (“SCC-CO2”) and fatigue has been intensified, making a significant
contribution to life extension of pipelines. In 2024, we reduced subsea SCC-CO2 production losses by 48.5%
when compared to the forecast, through inspection campaigns on flexible pipes and engineering for life
extension. We continue to implement initiatives such as expanding the supplier base to develop special
tools and flexible pipes immune to the effect of corrosion.
Wells and subsea systems KPIs are used as inputs for critical analysis of the interventions operational
performance and for the strategic evaluation of business performance.
As it relates to platforms, the All Electric Design was finished in 2022 for the Pre-salt FPSOs, aiming for
higher efficiency and lower GHG emission, representing the new generation of our FPSOs. For these units,
the oil production capacity is 225 mbbl/d and 353.9 mmcf/d of gas. The Sépia 2 and Atapu 2 FPSO bids
incorporate the All Electric Design, and the contracting process was finalized in the first half of 2024.
In the third quarter of 2024, we finished the P-86 basic design for the revitalization of the Marlim Leste and
Marlim Sul fields, which included the first combined cycle of a Petrobras-owned unit, a technology that
combines gas and steam turbines to increase efficiency in energy generation, resulting in lower emissions.
In the fourth quarter of 2024, the FPSO Maria Quitéria started operating in the Integrado Parque das Baleias
(IPB) field with the first combined cycle in a leasing unit of Petrobras.
We invest in technological solutions, which combined with the transition to a low-carbon global economy,
focus on reducing greenhouse gas emissions.
Annual Report and Form 20-F 2024 I 75
Our Business
In the last three years, we have installed eight major systems, mainly in the Santos Basin Pre-salt area. In
2024, we started the FPSO Maria Quitéria, located in Parque das Baleias area, and the FPSO Marechal Duque
de Caxias, located in Mero field. Those eight new systems added 71 new wells (36 production and 35
injection wells) into our production systems. According to our Strategic Plan, we expect to install 10 new
FPSOs in the next five years.
As a result, in 2024, we owned 29 and leased 20 offshore producing platforms. Besides these offshore
platforms, there are two storage and offloading units and five supporting units, totaling 56 active
platforms.
In 2024, our producing platforms had a daily production of 2,162 million barrels of oil and 3,010.5 million
cubic feet of natural gas (discounting the liquefied volume), with the highlight being FPSO Sepetiba, which
reached its maximum production capacity in September 2024. Three of our FPSOs reached their maximum
production capacity in 2023: Guanabara, Almirante Barroso and P-71. We expect that FPSO Marechal Duque
de Caxias will achieve its oil production capacity in 2025.
Annual Report and Form 20-F 2024 I 76
Our Business
SYSTEMS INSTALLED IN THE PREVIOUS FIVE YEARS
Start
up
(year)
Basin
Field/Area
Production
unit
Crude oil
nominal
capacity
(bbl/d)
Gas
nominal
capacity
(mmcf/d)
Water
depth
(meters)
Fiscal regime
Main
production
source
Type
2024
Santos
Mero
Duque de
Caxias
180,000
423.8
2,070
Production Sharing
Pre-salt
FPSO
Campos
Jubarte
Maria
Quitéria
100,000
176.6
1,385
Concession
Pre-Salt
FPSO
2023
Santos
Mero
Sepetiba
180,000
423.8
2,000
Production Sharing
Pre-salt
FPSO
Campos
Marlim
Anita
Garibaldi
80,000
247.2
670
Concession
Pre-salt/
Post-salt
FPSO
Campos
Marlim
Ana Nery
70,000
141.3
927
Concession
Post-salt
FPSO
Santos
Búzios
Almirante
Barroso
150,000
211.9
1,900
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
2022
Santos
Itapu
P-71
150,000
211.9
2,010
Transfer of Rights/
Production Sharing
Pre-salt
FPSO
Santos
Mero
Guanabara
180,000
423.8
1,930
Production Sharing
Pre-salt
FPSO
2021
Santos
Sépia
Carioca
180,000
211.9
2,200
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
2020
Santos
Atapu
Petrobras
70
150,000
211.9
2,288
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Annual Report and Form 20-F 2024 I 77
Our Business
MAIN SYSTEMS TO BE INSTALLED IN THE NEXT YEARS
Start up
(Expected
year)
Basin
Field/Area
Production
unit
Crude oil
nominal
capacity
(bbl/d)
Gas nominal
capacity
(mmcf/d)
Water
depth
(meters)
Fiscal regime
Main
production
source
Type
2025
Santos
Búzios 7
Almirante
Tamandaré (1)
225,000
423.8
1,985
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Santos
Búzios 6
Petrobras 78
180,000
254.3
2,030
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Santos
Mero 4
Alexandre de
Gusmão
180,000
423.8
1,890
Production Sharing
Pre-salt
FPSO
2026
Santos
Búzios 8
Petrobras 79
180,000
254.3
1,770
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
2027
Santos
Búzios 9
Petrobras 80
225,000
423.8
2,100
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Santos
Búzios 10
Petrobras 82
225,000
423.8
1,880
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Santos
Búzios 11
Petrobras 83
225,000
423.8
2,045
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
2028
Campos
Raia Manta e
Raia Pintada
FPSO Raia
126,000
565.0
2,750
Concession
Pre-salt
FPSO
2029
Campos
Barracuda e
Caratinga
To be defined
100,000
211.9
950
Concession
Post-salt
and Pre-salt
FPSO
Santos
Atapu 2
Petrobras 84
225,000
353
2,300
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
2030+
Campos
Albacora
To be defined
120,000
211.9
670
Concession
Post-salt
and Pre-salt
FPSO
Campos
Marlim Sul e
Marlim Leste
Petrobras 86
140,000
247.2
1,090
Concession
Post-salt
and Pre-salt
FPSO
Santos
Sépia2
Petrobras 85
225,000
353
2,150
Transfer of Rights/
Production Sharing/
Concession
Pre-salt
FPSO
Santos
SEAP 2
To be defined
120,000
424
2,550
Concession
Post-salt
FPSO
Santos
SEAP 1
To be defined
120,000
353
2,550
Concession
Post-salt
FPSO
(1)
The FPSO Almirante Tamandaré (Búzios 7) started production in February 2025.
Annual Report and Form 20-F 2024 I 78
Our Business
Decommissioning
We are committed to our assets after the end of their productive life. We work to extend the life cycle of our
assets, focusing on increasing the recovery factor and maximizing the value of the E&P portfolio. Once all
possibilities for extending the productive life have been exhausted, we begin the stage of allocating the
asset, through reuse and/or recycling.
Decommissioning of oil and gas exploration and production systems is part of the production cycle of the
oil and gas industry and includes several activities, such as disposal of the platform and the subsea system
and the plug and abandonment of wells.
However, before deciding to decommission, comprehensive studies and analyses are conducted to evaluate
the technical, economic, and operational feasibility of reusing components of production systems, such as
platforms. These assessments consider various factors, including the current condition of the assets,
potential for refurbishment, and the economic viability of repurposing versus decommissioning. By
thoroughly analyzing these aspects, we aim to maximize resource efficiency and minimize waste, ensuring
that any decision made is in the best interest of both the company and the environment.
Once the need for decommissioning has been confirmed, we plan in accordance with the applicable legal
requirements, including environmental regulations, and consider studies and guidelines on the best
practices of the oil and gas industry worldwide. Therefore, we follow strict safety standards and analyze
project alternatives based on multidisciplinary criteria (environmental, technical, security, social and
economic), in the planning process, which allows us to select the decommissioning alternative that
generates less impact. This decommissioning plan is approved by regulatory bodies before it is carried out.
Since 2023, when we concluded the first auctions for the sale of platforms P-32 and P-33, both from Campos
basins, we have been adopting ESG best practices in our decommissioning process. These sales processes
have stipulated several technical criteria and requirements for bidders. The shipyards have required an
operating license that explicitly includes dismantling activities, and an installed capacity for the temporary
storage and handling of materials, with a contingency and emergency plan, in addition to following best
practices in occupational safety.
Thus, the P-32 platform is currently undergoing dismantling at the Rio Grande Shipyard, and in 2024, the
P-33 was hooked out and transferred to the berthing area at the Port of Açu. In the same year, the P-26
platform was also hooked out and directed to the Port of Açu, where it remains berthed while awaiting its
final destination. Additionally, in 2024, the FPSO Capixaba, chartered from SBM, was unmoored and sent by
its shipowner to the MARS Shipyard in Denmark, in the same manner as the FPSO Fluminense, a vessel
owned and operated by Shell in partnership with Petrobras. Both followed a sustainable model and
complied with the Basel Convention.
Throughout the entire recycling process, we monitor the execution of the plans to ensure compliance with
the technical criteria mentioned.
In 2024, continuing the development and expanding the application of the models, we sold and disposed of
40 thousand tons of flexible lines for recycling, with a focus on operational storage efficiency and
sustainability. In addition, we established new criteria for the disposal of 36 thousand tons of ferrous scrap,
with a process focused on emission reduction gains for the steel mills and foundries’ process chain,
requiring disposal in electric furnaces.
In 2024, we successfully executed 33 offshore well abandonments, including well suspensions and
permanent abandonments. In 2024, we introduced the use of a Dynamic Positioning Platform equipped with
a Tethering BOP for shallow water abandonment activities. In 2023, the development of this technology was
recognized with the OTC Distinguished Achievement Award Brasil in 2023. Additionally, for platform wells,
we initiated a platform-free well suspension phase, which aims to reduce decommissioning costs.
Annual Report and Form 20-F 2024 I 79
Our Business
Critical Resources in Exploration & Production
We seek to procure, develop and retain all of the critical resources that are necessary to meet our production
targets. Drilling rigs, special vessels, supply vessels and helicopters are important resources for our
exploration and production operations and are centrally coordinated to assure both technical specifications
and proper lead time. We will continue to evaluate our drilling and special vessel demands and intend to
adjust our fleet size as needed.
DRILLING UNITS IN USE BY EXPLORATION & PRODUCTION AS OF DECEMBER 31, 2024(1)
2024
2023
2022
Leased
Owned
Leased
Owned
Leased
Owned
Brazil
28
0
27
0
20
0
Onshore
0
0
2(2)
0
1(2)
0
Offshore, by water depth (WD)
28
0
25
0
19
0
Jack-up rigs
0
0
0
0
0
0
Floating rigs
28
0
25
0
19
0
500 to 999 meters WD
1
0
1
0
1
0
1,000 to 1,999 meters WD
0
0
0
0
0
0
2,000 to 3,200 meters WD
27
0
24
0
18
0
Outside Brazil
1
0
0
0
0
0
Onshore
0
0
0
0
0
0
Offshore
1
0
0
0
0
0
WORLDWIDE
29
0
27
0
20
0
(1) In operated fields.
(2) Does not consider onshore workover rigs, not used for drilling.
To achieve our production goals, we have also secured a number of specialized vessels (such as Pipe Laying
Support Vessel - PLSVs) to connect wells to production systems. As of December 31, 2024, we had 14 PLSVs
in use. Similarly to the rigs, we intend to adjust our fleet size as needed.
The supply of goods and transport of people is also important to achieve our exploration and production
goals. By sea, we transport materials and chemical products. By air, we transport our most important assets:
people. Both materials and people are transported on a daily basis so that the exploration and production
of oil and gas is orchestrated in the most continuous way possible, maintaining the quality and level of
services.
In 2024, we delivered more than three million tons of materials and transported over one million passengers
to our platforms all over the Brazilian coast. To accomplish these results, we also have a secure number of
supply vessels (such as Platform Supply Vessels or “PSV”) and helicopters. As of December 31, 2024, we had
89 PSVs and 90 helicopters and both our fleets were sufficient to meet our needs.
Annual Report and Form 20-F 2024 I 80
Our Business
Mero Field
LIBRA BLOCK AND MERO FIELD
Mero is a field located in the Santos basin Ultra-deepwaters (water depth 2,100 meters), 180 km from
the coast of Rio de Janeiro State and inside Brazilian Pre-salt province. It is a thick reservoir (oil
columns reaches 420 meters), with high productivity and filled with a large volume of high-quality oil
(29° API). In addition, the associated challenges for project development are also noteworthy,
considering the high gas/oil ratio (415 std m³/std m³) and CO2 content in the associated gas (44%).
The Productions Individualization Agreement (AIP), effective from January 1, 2022, establishes the
interests of each party and the rules of joint execution for the operations to develop and produce oil
and natural gas in the shared reservoir. The interests of each party in the Mero Shared Reservoir were
then updated as follows: Petrobras with 38.60% interest, Shell with 19.30% interest, TotalEnergies with
19.30% interest, CNODC with 9.65% interest, CNOOC Limited with 9.65% interest and PPSA,
representing the Brazilian Government, with 3.50% interest.
PROJECT DEVELOPMENT
The first oil was produced in 2017, during the Early Production System (EPS) campaign, using the
chartered FPSO Pioneiro de Libra (50 thousand bbl/d of oil and 4 million m3/d of gas). The first EPS
operated in the Mero 2 region until July 2021. A second EPS began in December 2021 in the Mero 4
area, with the same FPSO, and the operation is still ongoing.
The definitive production arrangement for the Mero field comprises the already operating FPSOs
Guanabara, Sepetiba and Marechal Duque de Caxias, as well as the upcoming unit FPSO Alexandre de
Gusmão, expected to begin operating in the second half of 2025.
Each FPSO (all chartered units) is expected to process up to 180 thousand bbl/d of oil and 12 million
m3/d of gas. Each FPSO is equipped with gas re-injection systems, where the produced gas (44% CO2),
after self-consumption in the FPSO, is all re-injected into the reservoir to maintain pressure and
improve oil recovery, as well as reducing the release of CO2 into the atmosphere.
In August 2024, we signed a one-year term amendment for the FPSO Guanabara charter contract with
Modec. The agreement, extendable for another year, consists of increasing FPSO Guanabara maximum
production capacity up to 184.5 thousand bbl/d. In the same month, the FPSO Sepetiba achieved its
nominal oil production capacity.
In October 2024, FPSO Marechal Duque de Caxias started operations.
In 2024, the four operating units achieved a cumulative production of 263 million bbl of oil and over 17
billion m³ of associated gas, from which 87% was reinjected into the reservoir, along with nearly 6.5
billion m³ of CO2.
NEW TECHNOLOGIES IN LIBRA
HISEP™
HISEP™ is an innovative subsea separation technology designed to separate gas with high CO2 content
from the reservoir-produced fluid at the seabed. This technology operates under high-pressure
Annual Report and Form 20-F 2024 I 81
Our Business
conditions and utilizes centrifugal pumps for the direct reinjection of the separated gas stream back
into the reservoir. By removing gas with high CO2 content, HISEP™ enables efficient separation and
contributes to emissions reduction, making it a promising system for carbon capture.
The primary objective of HISEP™ is to debottleneck the topside gas processing plant and extend the
oil production plateau, by reducing the gas-oil ratio (“GOR”) of the oil that reaches the FPSO facility.
Additionally, the technology addresses challenges posed by high GOR, CO2 content, and productivity
index in Ultra-deepwater offshore reservoirs, particularly in the Brazilian Pre-salt.
In January 2024, an EPCI contract was signed for the HISEP™ pilot and the project is currently in the
detailed engineering design phase. The contract comprises project design, construction, installation,
and hookup, as well as commissioning and operations for two and a half years up to full commercial
and technological maturity.
The HISEP™ pilot will be connected to the FPSO Marechal Duque de Caxias and four wells (two
production and two injection) in the Mero 3 production area. HISEP™ pilot first oil with low GOR is
expected in the second half of 2028.
CTV
The Cargo Transfer Vessel (CTV) is a state-of-the-art oil offloading technology that achieved
successful qualification in 2023, following an extensive field trials program in the Santos basin. This
innovative concept allows for the direct transfer of oil from the FPSO unit to conventional oil tankers,
ensuring safety levels that are comparable to those of Dynamic Positioning Shuttle Tankers. By
streamlining conventional logistics, the CTV solution offers a more efficient and flexible logistics
strategy for oil export scenarios. As a result, this technology is poised to drive future cost reductions,
decrease greenhouse gas emissions, shorten time to market, and improve Health, Safety, Security, and
Environmental indicators. Following its successful qualification, the CTV has been integrated into the
logistics strategy for offloading operations in the Santos basin for over a year.
PRM
Seismic Permanent Reservoir Monitoring (“PRM”) is a technology that will provide more profound
knowledge about the distribution of fluids in the reservoir via data acquisition. This way, it will also
allow greater efficiency in oil production in the Mero field.
PRM in Mero has unprecedented features in Brazil, considering the water depth, a large application
area (approximately 200 km²), and the high complexity for installation due to many subsea obstacles
(projects infrastructure). It incorporates state-of-the-art 4D seismic monitoring technologies, in which
seismic records obtained on different dates are used to monitor the behavior of reservoirs over time.
According to our Strategic Plan, the system is expected to be installed in two phases. The first phase
in 2025, covering Mero 1 and Mero 2, and a second phase in 2026 to cover the remaining two modules
of the field. It comprises a network of optical fibers with seismic sensors that will be connected to the
FPSO Sepetiba and our offices. It will allow remote and instant access to the data generated by the
monitoring system.
Annual Report and Form 20-F 2024 I 82
Our Business
Production
In 2024, our total production of oil and gas, including NGL, was 2,698 mboed, of which 2,664 mboed were
produced in Brazil, and 33.6 mboed were produced abroad, a 3% decrease compared to 2023. This
production decline was mostly due to production restrictions on Post-salt platforms.
Our production in the Pre-salt layer reached 1,813 mbbl/d in 2024, representing an increase of 0.4% in
relation to our production in 2023. In 2024, the oil production in the Pre-salt layer represented 84.2% of all
oil production in Brazil, compared to 80.9% in 2023.
OIL AND GAS PRODUCTION
2024
2023
2022
2024 vs 2023
Crude oil and natural gas – Brazil (mboed)
2,664
2,748
2,648
-3%
Onshore and Shallow Water (mbbl/d)(1)
34
43
73
-21%
Post-salt deep and Ultra-deepwaters (mbbl/d)
305
382
434
-20%
Pre-salt (mbbl/d)
1,813
1,806
1,635
+0.4%
Crude oil (mbbl/d)(2)
2,152
2,231
2,142
-4%
Natural gas (mboed)
512
516
505
-1%
Crude oil and natural gas – Abroad(3) (mboed)
34
35
37
-3%
TOTAL
2,698
2,782
2,684
-3%
(1) Shallow waters production: 0.4 mboed in 2024, 3 mboed in 2023 and 7 mboed in 2022.
(2) Including NGL.
(3) Includes the proportional production of our equity method investees, based on the percentage of our interest in these entities.
Pre-salt oil production increased by 0.4%, reflecting the ramp-up of the FPSOs Sepetiba, Almirante Barroso,
Anita Garibaldi, Marechal Duque de Caxias and Maria Quitéria. The Pre-salt area comprises large
accumulations of light oil of excellent quality and high commercial value. The Post-salt oil production in
deep and Ultra-deepwaters decreased by 20%, due to production restrictions on platforms during the year
and the natural decline of production.
Shallow waters and Onshore oil production decreased by 21%, to 34 mbbl/d, due to divestments,
decommissioning and the natural decline of production.
We produced 85,219 million m3/d of gas in 2024. From that volume, we used 30,255 million m3/d in our
production processes (reinjected, flared, consumed, liquefied) and allocated 54,964 million m3/d for sale.
Annual Report and Form 20-F 2024 I 83
Our Business
ACHIEVEMENT OF 2024 PRODUCTION TARGET
We achieved our production targets for 2024, established in the Strategic Plan 2024-2028+.
PRODUCTION TARGETS FOR 2024 (mmboed)
Production
Performed
Goal
Oil and NGL
2.2
2.2 ± 4%
Oil, NGL and commercial gas
2.4
2.5 ± 4%
Total production Oil and Gas
2.7
2.8 ± 4%
This result demonstrates our commitment to meeting our goals, which have been reached by maintaining
the focus of our activities on deep and Ultra-deepwater assets.
LIFTING COST
In 2024, our Lifting Cost (Brazil), without government participation or leases, was US$6.1 per boe, which
represents an 8.3% increase from the 2023 cost of US$5.6 per boe. Including leases, our Lifting Cost in 2024
was US$8.6 per boe, which represents a 11.8% increase from the 2023 cost of US$7.7 per boe.
Shared reservoirs: deposits between different fields
The participation of consortium members in any fields mentioned refers exclusively to the
participation of such members in the contract related to such field. On certain occasions, some of these
fields are subject to AIPs, also known as unitization agreements, resulting in shared deposits between
different fields. Under AIPs, costs, investments, and production volumes are shared between the
parties thereto.
Below are the most relevant fields subject to AIPs to which we are party. This list is not exhaustive and
other fields not mentioned below may also be subject to AIPs.
TUPI
The AIP of Tupi’s Shared Reservoir, located in the Santos basin, was approved by ANP in March 2019
and has been in effect since April 2019.
The shared reservoir comprises Tupi’s reservoir and is shared between:
_ Tupi concession (Concession Contract/BM-S-11), operated by us with a 65% interest, in partnership
with Shell with a 25% interest and Galp with a 10% interest;
_ Sul de Tupi (Transfer of Rights), where we have 100% of the interest; and
_ Tupi Leste (Non-Contracted Area), which belongs to the Brazilian federal government, represented
by PPSA.
Annual Report and Form 20-F 2024 I 84
Our Business
Tupi’s AIP does not cover the so-called Iracema reservoir, which remains with the same interests of the
BM-S-11 consortium.
The interests of each contract in Tupi’s Shared Reservoir (AIP of Tupi) are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Tupi (Concession Contract / BM-S-11)
92.09
Sul de Tupi (Transfer of Rights)
7.36
Tupi Leste (Non-Contracted Area)
0.55
The interest of each party in Tupi’s Shared Reservoir (AIP of Tupi) are as follows:
Partner
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
67.22
Shell
23.02
Galp
9.21
PPSA(1)
0.55
(1)
Party of Tupi Leste (Non-contracted area) with 0.55%.
MERO
The AIP of the Mero accumulation, located in the Santos basin, was approved by ANP in December 2021
and has been in effect since January 2022.
The Mero Shared Reservoir comprises:
_ Mero (Production Sharing Contract/Libra): operated by us with 40% interest in partnership with Shell
(20% interest), TotalEnergies (20% interest), CNODC (10% interest), CNOOC (10% interest); and
_ Sul de Mero and Norte de Mero (non-contracted areas), which belong to the Brazilian federal
government, represented by PPSA.
The interest of each contract in the Mero Shared Reservoir (AIP of Mero) are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Mero (Production Sharing Contract / Libra)
96.50
Sul de Mero and Norte de Mero
(Non-Contracted Area)
3.50
The interest of each party in the Mero Shared Reservoir (AIP of Mero) are as follows:
Annual Report and Form 20-F 2024 I 85
Our Business
Partner
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
38.60
Shell
19.30
TotalEnergies
19.30
CNODC
9.65
CNOOC
9.65
PPSA(1)
3.50
(1)
PPSA is the manager of the Production Sharing Contract of Mero and party of Sul de Mero and Norte de Mero (Non-Contracted Areas) with
3.50% interest.
ATAPU
The ANP has approved the AIP of Atapu accumulations, located in the Santos basin, and it has been in
effect since in September 2019. The ANP approved an amendment in April 2022, to include the
Production Sharing Contract.
The Atapu Shared Reservoir comprises:
_ Oeste de Atapu (Concession Contract / BM-S-11A), operated by us with a 42.5% interest, in
partnership with Shell, with a 25% interest, TotalEnergies, with a 22.5% interest, and Galp, with a 10%
interest;
_ Atapu ECO (ToR Surplus), operated by us with a 52.5% interest, in partnership with Shell (25%
interest), and TotalEnergies (22.5% interest);
_ Atapu (Transfer of Rights), operated by us, and where we hold 100% of the interest; and
_ Norte de Atapu (Non-Contracted Area), which belongs to the Brazilian federal government,
represented by PPSA.
The interest of each contract in Atapu Shared Reservoir (AIP of Atapu) are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Oeste de Atapu (Concession Contract /
BM-S-11A)
17.03
Atapu (Transfer of Rights)
32.40
Atapu ECO (ToR Surplus)
49.62
Norte de Atapu (Non-Contracted Area)
0.95
The interest of each party in Atapu Shared Reservoir (AIP of Atapu) are as follows:
Annual Report and Form 20-F 2024 I 86
Our Business
Partner
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
65.69
Shell
16.66
TotalEnergies
15.00
Galp
1.70
PPSA (1)
0.95
(1)
PPSA is the manager of the Production Sharing Contract of Atapu ECO and party of Norte de Atapu (non-contracted areas) with 0.95%
interest.
SÉPIA
The AIP of Sépia accumulations, located in the Santos basin, was approved by ANP and has been in
effect since September 2019. An amendment was approved by ANP in April 2022 to include the
Production Sharing Contract.
The Sépia Shared Reservoir comprises:
–
Sépia Leste concession contract (Concession Contract/BM-S-24) operated by us (80% interest), in
partnership with Galp (20% interest); and
–
Sépia ECO (ToR Surplus), operated by us (30% interest), in partnership with TotalEnergies (28%
interest), Petronas (21% interest), and QP Brasil (21% interest); and
–
Sépia (Transfer of Rights Agreement), operated by us (where we hold a 100% interest).
The interest of each contract in the Sépia shared reservoir (AIP of Sépia) are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Sépia Leste (Concession Contract)
12.07
Sépia ECO (ToR Surplus)
60.41
Sépia (Transfer of Rights Agreement)
27.52
The interest of each party in the Sépia shared reservoir (AIP of Sépia) are as follows:
Partner (1)
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
55.30
TotalEnergies
16.91
Petronas
12.69
QP Brasil
12.69
Galp
2.41
(1)
PPSA is the manager of the Production Sharing Contract of Sépia ECO.
Annual Report and Form 20-F 2024 I 87
Our Business
BÚZIOS AND TAMBUATÁ
The Búzios Shared Reservoir comprises:
_ Tambuatá (Concession Contract / BS-500), operated by us with a 100% interest.
_ Búzios (Transfer of Rights), operated by us with a 100% interest.
_ Regarding Búzios ECO (ToR Surplus), in November 2019, we in partnership with CNODC and CNOOC,
obtained the rights to explore the surplus volumes of Búzios field. The Production Sharing Regime in
Búzios became effective in September 2021. In 2022, we transferred 5% of our interest in the ToR
Surplus, to CNOOC. This transaction was effective as of December 1, 2022. Our interest in Búzios ECO
is 85%, the interest of CNOOC is 10% and the interest of CNODC is 5%.
The interest of each contract in the Búzios shared reservoir are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Búzios (Transfer of Rights)
25.95
Búzios ECO (ToR Surplus)
73.41
Tambuatá (Concession Contract / BS-500)
0.64
The interest of each party in the Búzios shared reservoir (AIP of Búzios) are as follows:
Partner (1)
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
88.9891
CNOOC
7.3406
CNODC
3.6703
(1)
PPSA is the manager of the Production Sharing Contract of Búzios ECO.
TARTARUGA MESTIÇA, TARTARUGA VERDE AND ESPADARTE MODULE III
The concession contract BM-C-36 has two producing reservoirs: the Tartaruga Verde reservoir, which
is totally contained within the ring fence limits, and the Tartaruga Mestiça reservoir, which goes
beyond the ring fence limits.
The AIP of the Tartaruga Mestiça Shared Reservoir was signed between us and PPSA and has been in
effect since March 2018. We fully acquired the area of the limits of the concession BM-C-36 in
September 2018 through the block named Sudoeste de Tartaruga Verde (Production Sharing
Contract).
In December 2019, we assigned to Petronas 50% of our interest of Tartaruga Verde Fields (BM-C-36)
and Espadarte Module III. We also established a consortium with Petronas, pursuant to which we carry
out operator activities in aforementioned operations. The Tartaruga Verde Sudoeste Field, under the
Production Sharing Agreement, remained entirely with us.
In January 2021, the ANP approved an amendment to the AIP.
The interest of each contract in the Tartaruga Mestiça Shared Reservoir:
Annual Report and Form 20-F 2024 I 88
Our Business
Contract
Interest (%) of each Contract in the Shared Reservoir
Tartaruga Verde (Concession Contract /
BM-C-36)
82.19
Tartaruga Verde Sudoeste (Production Sharing
Contract)
17.81
The interest of each party in the Tartaruga Mestiça Shared Reservoir:
Partner (1)
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
58.905
Petronas
41.095
(1)
PPSA is the manager of the Production Sharing Contract of Tartaruga Verde Sudoeste
The interest of each party in the Tartaruga Verde and Espadarte Module III reservoirs are:
Partner
Interest (%) of each party in the Reservoir
Petrobras (operator)
50
Petronas
50
SAPINHOÁ
In 2000, we, YPF Brasil Ltda (YPF) and BG E&P Brasil LTDA (BG), entered into an agreement to create
the BM-S-9 consortium, and the BM-S-9 concession contract was signed in September 2000. YPF and
BG interests were later acquired by Repsol and Shell, respectively. We operate Sapinhoá (Concession
Contract / BM-S-09), with a 45% interest, in partnership with Shell (30% interest) and Repsol (25%
interest).
In October 2017, the same consortium acquired the rights to produce in the extended area of Entorno
de Sapinhoá (composed of Sudoeste de Sapinhoá, Noroeste de Sapinhoá, and Nordeste de Sapinhoá).
The Production Sharing Contract related to such area was signed in January 2018.
ANP approved the AIP of Sapinhoá Field shared deposit, located in the Santos basin, which has been in
effect since March 2018, with the following interests of each contract in the Sapinhoá Shared
Reservoir:
Contract
Interest (%) of each Contract in the Shared Reservoir
Sapinhoá (Concession Contract / BM-S-09)
96.30
Entorno de Sapinhoá (Production Sharing
Contract)
3.70
The interest of each party in the Sapinhoá shared reservoir are as follows:
Annual Report and Form 20-F 2024 I 89
Our Business
Partner (1)
Interest (%) of each party in the Shared Reservoir
Petrobras (operator)
45.00
Shell
30.00
Repsol Sinopec
25.00
(1) PPSA is the manager of the Production Sharing Contract of Entorno de Sapinhoá.
In November 2024, the consortium submitted to ANP an amendment to the AIP arising from the
process of reviewing interests of each contract in the Sapinhoá Shared Reservoir. This amendment to
the AIP is still under analysis by ANP.
BRAVA
We entered into an AIP with PPSA to establish the terms and conditions of the Brava shared reservoir,
located in the Campos basin, that has been in force since October 2019. PPSA represented the Brazilian
federal government as the owner of the non-contracted area of Norte de Brava, while we owned the
Voador and Marlim concession contract areas.
In May 2023, ANP approved an amendment to the AIP to include the Production Sharing Contract of
Norte de Brava, and we acquired a 100% interest in the Production Sharing Contract of Norte de Brava.
The interest of each Contract in the Brava shared reservoir are as follows:
Contract
Interest (%) of each Contract in the Shared Reservoir
Marlim (Concession Contract)
64.27
Voador (Concession Contract)
33.40
Norte de Brava (Production Sharing Contract)
2.33
Petrobras has a 100% interest in the Brava Shared Reservoir. PPSA is the manager of the Production
Sharing Contract of Norte de Brava.
ALBACORA PRE-SALT (FORNO)
We entered into an AIP with PPSA to establish the terms and conditions of the Albacora Pre-salt
(Forno) shared reservoir, located in the Campos basin, that has been in force since January 2023. PPSA
represented the Brazilian federal government as the owner of the non-contracted area of Norte de
Brava, while we owned the Albacora concession contract area.
In May 2023, ANP approved an amendment to the AIP to include the Production Sharing Contract of
Norte de Brava, and we acquired a 100% interest in the Production Sharing Contract of Norte de Brava.
The interest of each contract in the Albacora Pre-Salt (Forno) Shared Reservoir are as follows:
Annual Report and Form 20-F 2024 I 90
Our Business
Contract
Interest (%) of each Contract in the Shared Reservoir
Albacora (Concession Contract)
98.33
Norte de Brava (Production Sharing Contract)
1.67
Petrobras has 100% interest in the Albacora Pre-Salt (Forno) Shared Reservoir. PPSA is the manager
of the Production Sharing Contract of Norte de Brava.
Annual Report and Form 20-F 2024 I 91
Our Business
MAIN PRODUCTION FIELDS
Production units
Basin
Field
Main
source
Owned
Capacity
(mbbl/d)
Leased
Capacity
(mbbl/d)
Interest (%) of
each party in
the Shared
Reservoir
API Gravity
Sulfur
content
(% wt)
2024 oil
production
(mbbl/d)
Santos
Búzios
Pre-salt
4
4 units with 150
1
1 unit with 150
Petrobras (89%)
CNOOC (7.3%)
CNODC (3.7%)
28.5 – 28.8
0.30 – 0.33
567
Santos
Tupi
Pre-salt
3
3 units with 150
6
1 unit with 100
1 unit with 120
4 units with 150
Petrobras
(67.22%)
Shell (23.02%)
Petrogal (9.21%)
PPSA (0.55%)
29.6 – 31.4
0.34 – 0.37
554
Santos
Itapu
Pre-salt
1
1 unit with 150
Petrobras (100%)
30.2
0.25
149
Campos
Jubarte
Pre-salt
2
2 units with 180
2
1 unit with 100
1 unit with 110
Petrobras (100%)
17.1 – 30.8
0.29 – 0.56
115
Santos
Mero
Pre-salt
—
—
5
4 units with 180
1 unit with 150
Petrobras (40%)
Shell (20%)
Total (20%)
CNODC (10%)
CNOOC (10%)
29.0 – 30.2
0.30 – 0.31
100
Santos
Atapu
Pre-salt
1
1 unit with 150
—
—
Petrobras
(65.69%)
Shell (16.66%)
TotalEnergies
(15%)
Galp (1.7%)
PPSA (0.95%)
28.3
0.37
97
Campos
Roncador
Post-salt
4
3 units with 180
1 unit with 190
—
—
Petrobras (75%)
Equinor (25%)
17.7 – 28.7
0.32 – 0.63
74
Santos
Sépia
Pre-salt
—
—
1
1 unit with 180
Petrobras (55.3%)
TotalEnergies
(16.91%)
Petronas (12.69%)
QP Brasil (12.69%)
Galp (2.41%)
28.3
0.39
72
Campos
Marlim
Sul
Post-salt
3
1 unit with 140
1 unit with 180
1 unit with 200
—
—
Petrobras (100%)
17.6 – 25.5
0.52 – 0.73
63
Santos
Sapinhoá
Pre-salt
—
—
2
2 units with 150
Petrobras (45%)
Shell (30%)
Repsol Sinopec
(25%)
29.6 – 29.9
0.37
60
Other Pre and Post-salt fields
267
Onshore
34
Shallow waters
0.4
TOTAL
2.152
Annual Report and Form 20-F 2024 I 92
Our Business
2024 PRODUCTION
Búzios field
The Búzios field is a highly productive asset with substantial reserves of light oil, low Lifting Costs, and
reduced emissions. It has demonstrated economic resilience even in a low oil price environment. As of
December 31, 2024, the Búzios field had achieved a total accumulated production of 1,400 million
barrels of oil equivalent (MMboe) under the co-participation agreement. On January 3, 2024 the Búzios
Shared Reservoir achieved a daily operated production record of 782.5 thousand barrels of oil per day
(kbpd), attributed to excellent operational performance. Additionally, Búzios recorded an annual
operated production record of 643.2 kbpd in 2024.
Currently, there are six operational units in Búzios. The fifth unit, FPSO Almirante Barroso, commenced
production in May 2023 and achieved full production in record time, producing 150 mbbl/d td after five
months. The sixth production system, FPSO Almirante Tamandaré, arrived at its location in October
2024 and started production in February 2025. This unit is the first high-capacity platform installed in
Búzios, with a production potential of up to 225 thousand barrels of oil per day and the ability to
process 12 million cubic meters of natural gas per day.
Furthermore, during the period from 2022 to 2024 we signed construction contracts for P-78, P-79, P-
80, P-82, and P-83. The production for the next platforms is projected to commence in different years:
P-78 in 2025, P-79 in 2026 and P-80, P-82 and P-83 in 2027. These platforms are expected to
significantly expand the production capacity of the Búzios field, reinforcing its role as a cornerstone
of our production strategy.
The company has been focusing on optimizing operational efficiency and reducing costs, which is
evident in the improved Lifting Costs and enhanced production rates. The operational performance in
Búzios is expected to further bolster our financial metrics, supporting our commitment to delivering
value to shareholders and maintaining a strong cash generation profile. Additionally, the FPSO
Almirante Tamandaré and the upcoming platforms are equipped with advanced technologies aimed at
reducing greenhouse gas emissions, aligning with our broader sustainability goals.
For more information on the composition of participation in the project and the different partners’
shares in Búzios, see “Our Business – Production – Shared reservoirs: deposits between different
fields.”
Annual Report and Form 20-F 2024 I 93
Our Business
For more information on our production of crude oil, natural gas, Synthetic Oil and Synthetic Gas by
geographic area in 2024, 2023 and 2022, see Exhibit 15.3 to this annual report.
Customers and Competitors
One of our most representative trades in terms of volume and profitability is crude oil. We sell oil through
long-term and spot-market contracts, and in 2024, the crude oil volume committed through long-term
contracts with quantity subject to final agreement on commercial terms was approximately 233 mbbl/d.
Our domestic and overseas portfolio includes approximately 70 clients, such as refiners that process or have
processed Brazilian oils regularly, distributed throughout the Americas, Europe and Asia, including China.
OIL CLIENTS (% vol)
In 2024, we remain one of the most important exporters of low sulfur fuel oil in the world, even with an
increased participation of the high-sulfur grade in our portfolio. Our fuel oil is available in the major hubs in
the market such as Singapore, Arab Gulf, the Mediterranean and Northwest Europe, the west coast of Africa,
Panama, Caribbean and China. Our counterparties list consists of major companies, trading companies and
barging companies. We have sold fuel oil to more than 20 different companies this year.
In the exploration and production industry, we face competition to gain access to new exploratory assets.
In Brazil, the bidding rounds conducted by the ANP are auctions through which the Brazilian federal
government grants the right to explore and produce oil and natural gas.
In 2022, nine operators purchased 59 concessions for exploratory blocks in the 3rd cycle of the Open
Acreage of the Concession Bidding Round. Petrobras did not participate in this cycle.
In 2023, 13 operators purchased 192 concessions for exploratory blocks, in the 4th cycle of the Open
Acreage of Concession Bidding Round. Petrobras is one of these operators, with 29 exploratory blocks. One
operator purchased one block in the 2nd Cycle of the Open Acreage Production Sharing Modality (Petrobras
did not participate in this cycle).
ANP has not offered bidding rounds in 2024.
Annual Report and Form 20-F 2024 I 94
Our Business
Reserves
Preparation of reserves estimates
We apply SEC regulation for estimating and disclosing the oil and natural gas reserve quantities
included in this annual report. In accordance with this regulation, we estimate reserves by considering
average prices calculated as the unweighted arithmetic average of the first-day-of-the-month price
for each month within the 12-month period prior to the end of the reporting period.
We estimate reserves based on forecasts of field production, which depends on an array of technical
information, such as seismic surveys, well logs and tests, rock and fluid samples, and geoscience,
engineering and economic data. All reserve estimates involve some degree of uncertainty. The
uncertainty depends primarily on the amount of reliable geological and engineering data available at
the time of the estimate and the interpretation of that data. Our estimates are thus made using the
most reliable data and technology available at the time of the estimate, in accordance with the best
practices in the oil and gas industry and SEC rules and regulations.
Thus, the reserve estimation process begins with an initial evaluation of our assets by geophysicists,
geologists and engineers. Reserves managers are responsible for the assets reserves estimates in
each business unit in Brazil and the corporate reserves team provide guidance for reserves estimates
in compliance with SEC requirements to the asset teams. General managers are responsible for the
assets reserves of our business units in Brazil and executive officers of companies outside Brazil where
we have interests are responsible for regional reserves estimates in compliance with SEC
requirements. The corporate reserves team is responsible for consolidating our reserves estimates,
standardized measures of discounted net cash flows related to prove oil and gas reserves, and other
information related to prove oil and gas reserves. Our reserves estimates are approved by our
Executive Officers, which then informs our Board of Directors about the approval. The technical person
primarily responsible for overseeing our reserves' preparation is the corporate reserves team
manager, who has 22 years of experience in the oil and gas industry and holds a bachelor's degree in
civil engineering from Federal University of Juiz de Fora, a specialization in Petroleum Engineering
from Petrobras University and a MBA in Oil and Gas Management from Fundação Getúlio Vargas.
D&M conducted a reserves evaluation of 97.2% of our proved crude oil, condensate and natural gas
reserves as of December 31, 2024 in Brazil. The amount of reserves reviewed by D&M corresponds to
96.8% of our total Proved Reserves company-wide on an equivalent barrel basis. For disclosure
describing the qualification of D&M’s technical person primarily responsible for overseeing our
reserves evaluation, see Exhibit 99.1 to this annual report.
For a description of the risks relating to our reserves and our reserve estimates, see “Risks” in this
annual report.
Due to Brazilian regulation, we also estimate our oil and gas reserves pursuant to the ANP and the SPE
definitions. The differences between the reserves estimated according to the ANP/SPE definitions and
those estimated according to SEC regulation are mainly due to different economic assumptions and
the possibility of considering as reserves the volumes expected to be produced beyond the concession
contract expiration date in fields in Brazil according to ANP reserves regulation.
Annual Report and Form 20-F 2024 I 95
Our Business
We discover new areas through exploratory activity. Such areas constitute our fields after the declaration
of commerciality. We then prepare a development plan for each field. As projects achieve adequate
maturity, Proved Reserves may be reported.
Our fields’ Proved Reserves can be later increased with additional drilling, operational optimizations and
improved recovery methods, such as water injection, among other activities.
Our proved oil, condensate and natural gas reserves as of December 31, 2024 were estimated at 11,386
million boe. This estimate includes reserves related to our interest in equity method investees, which
represents 0.1% of our reserves.
PROVED RESERVES (1) (million boe)
(1)
Apparent differences in the sum of the numbers are due to rounding.
Oil and gas reserves quantities change yearly. Quantities included in our previous year’s reserves that are
produced during the year are no longer reserves at year-end. Other factors, such as reservoir performance,
revisions in oil prices, discoveries, extensions, purchases and sales of assets that occurred during the year,
also influence year-end reserves quantities.
Annual Report and Form 20-F 2024 I 96
Our Business
PROVED RESERVES (1) (million boe)
(1) Apparent differences in the sum of the numbers are due to rounding.
(2) The 865 million boe production volume is the net volume withdrawn from our Proved Reserves. It therefore excludes NGL, as we estimate our oil and gas
reserves at a reference point located prior to the gas processing plants, except for the United States of America and Argentina. The production does not include
injected gas volumes, production of EWTs in exploratory blocks and production in Bolivia, since Bolivian reserves are not included in our reserves due to
restrictions determined by Bolivian Constitution.
In 2024, we incorporated 1,330 million boe of Proved Reserves, including the:
_ addition of 883 million boe, due to new projects, mainly in Atapu and Sépia fields, and in other fields
in Santos, Campos and Solimões basins; and
_ addition of 447 million boe, due to the performance of assets, mainly in Búzios, Itapu, Tupi and Sépia
fields, in the Santos basin, and other revisions.
We did not have relevant changes related to the variation in the oil price.
2024 RESERVES INDEXES
Annual Report and Form 20-F 2024 I 97
Our Business
Proved Undeveloped Reserves
As of December 31, 2024, our Proved Undeveloped Reserves were estimated at 5,514 million boe, a net
increase of 6% when compared to 2023 year-end.
In 2024, we incorporated 320 million boe of Proved Undeveloped Reserves, including the:
_ addition of 882 million boe, due to new projects, mainly in Atapu and Sépia fields and in other fields
in Santos, Campos and Solimões basins;
_ addition of 142 million boe, mainly due to the performance in Búzios and Jubarte fields, and other
revisions.
The additions in our Proved Undeveloped Reserves were partially offset by the conversion of 705 million
boe of Proved Undeveloped Reserves to Proved Developed Reserves, mainly as a result of FPSO Duque de
Caxias start-up and FPSO Sepetiba ramp up in Mero field, the ramp up of P-71 platform in Itapu field, in
Santos Basin, and the ramp up of FPSO Anna Nery and FPSO Anita Garibaldi in Marlim field, Campos basin.
CHANGES IN PROVED UNDEVELOPED RESERVES(1) (million boe)
(1) Apparent differences in the sum of the numbers are due to rounding.
As of December 31, 2024, 11.2% (619 million boe) of our Proved Undeveloped Reserves have remained
undeveloped for five years or more, mainly due to the inherent complexity of deep and Ultra-deepwater
development projects in giant fields, particularly in the Santos and Campos basins, in which we are investing
in the required infrastructure.
In 2024, we invested a total of US$14.1 billion in development projects, of which 99.3% was invested in Brazil.
Most of our investments relate to long-term development projects, which are developed in phases due to
the large volumes and extensions involved, the deep and Ultra-deepwater infrastructure and the
production resources complexity. In these cases, the full development of the reserves related to these
investments may exceed five years.
Annual Report and Form 20-F 2024 I 98
Our Business
For further information on our reserves, see the unaudited section “Supplementary Information on Oil and
Gas Exploration & Production” in our audited consolidated financial statements.
Oil and Gas Additional Information
The following tables show (i) the number of gross and net productive oil and natural gas wells and (ii) total
gross and net developed and undeveloped oil and natural gas acreage in which we had interests as of
December 31, 2024. A gross well or acre is a well or acre where we own an interest, while the number of net
wells or acres is the sum of fractional interests in gross wells or acres. We do not have any material acreage
expiring before 2030.
GROSS AND NET PRODUCTIVE WELLS
As of December 31, 2024
Oil
Natural Gas
Gross
Net
Gross
Net
Consolidated subsidiaries
Brazil
759
716
81
76
South America (outside of Brazil)
31
10
170
58
Total consolidated
790
726
251
134
Equity method investees
North America
42
3.28
1
0.06
Total equity method investees
42
3.28
1
0.06
TOTAL GROSS AND NET PRODUCTIVE
WELLS
832
729.28
252
134.06
Annual Report and Form 20-F 2024 I 99
Our Business
GROSS AND NET DEVELOPED AND UNDEVELOPED ACREAGE (in acres)
As of December 31, 2024
Developed acreage
Undeveloped acreage
Gross
Net
Gross
Net
Consolidated
Brazil
3,088,096
2,629,102
838,069
613,121
South America (outside of Brazil)
3,746
1,259
1,230
413
Total consolidated
3,091,842
2,630,361
839,299
613,535
Equity method investees
North America
29,969
2,766
136,800
11,523
Total equity method investees
29,969
2,766
136,800
11,523
TOTAL GROSS AND NET ACREAGE
3,121,811
2,633,127
976,099
625,058
For “net” figures, we used our interest held on December 31, 2024. Gross and net developed and
undeveloped acreage presented in this table does not include exploratory areas.
The following table sets forth the number of net productive and dry exploratory and development wells
drilled in the last three years.
NET PRODUCTIVE AND DRY EXPLORATORY AND DEVELOPMENT WELLS
2024
2023
2022
Net productive exploratory wells drilled
Consolidated subsidiaries
Brazil
2.60
1.80
1.90
South America (outside of Brazil)
1.45
—
0.78
Total consolidated subsidiaries
4.05
1.80
2.68
Equity method investees
North America(1)
—
—
—
Total productive exploratory wells drilled
4.05
1.80
2.68
Net dry exploratory wells drilled
Consolidated subsidiaries
Brazil
2.80
—
0.45
South America (outside of Brazil)
—
—
—
Total consolidated subsidiaries
2.80
—
0.45
Equity method investees
North America(1)
—
—
—
Annual Report and Form 20-F 2024 I 100
Our Business
2024
2023
2022
Total dry exploratory wells drilled
2.80
—
0.45
TOTAL NUMBER OF NET EXPLORATORY WELLS DRILLED
6.85
1.80
3.13
Net productive development wells drilled
Consolidated subsidiaries
Brazil
35.33
30.50
41.66
South America (outside of Brazil)
3.36
3.70
3.02
Total consolidated subsidiaries
38.69
34.20
44.68
Equity method investees
North America(1)
0.07
0.14
0.08
Total productive development wells drilled
38.76
34.34
44.76
Net dry development wells drilled
Consolidated subsidiaries
Brazil
—
—
—
South America (outside of Brazil)
—
—
—
Total consolidated subsidiaries
—
—
—
Equity method investees
North America(1)
—
—
—
Total dry development wells drilled
—
—
—
TOTAL NUMBER OF NET DEVELOPMENT WELLS DRILLED
38.76
34.34
44.76
(1)
Due to the joint venture formed by Petrobras America Inc. and Murphy Exploration & Production Company, information regarding Proved Reserves,
acreage and wells in the United States are reported in the “equity method investees” section. For “net” figures, we used the interest held as of December
31, 2024.
The following table summarizes the number of wells in the process of being drilled as of December 31, 2024.
NUMBER OF WELLS BEING DRILLED AS OF DECEMBER 31, 2024
Gross
Net
Consolidated Subsidiaries
Brazil
13
8.87
International
South America (outside of Brazil)
2
0
North America
0
0
TOTAL WELLS DRILLING
15
8.87
The following table sets forth our average sales prices and average production costs by geographic area of
production and by product type for the last three years.
Annual Report and Form 20-F 2024 I 101
Our Business
AVERAGE SALES PRICES AND AVERAGE PRODUCTION COSTS (US$)
South America
Total
Brazil
South America
(outside of Brazil)
2024
Average sales prices
Oil and NGL, per barrel
75.05
54.50
75.04
Natural gas, per thousand cubic feet(1)
10.38
3.00
9.88
Synthetic Oil, per barrel
—
—
—
Synthetic Gas, per thousand cubic feet
—
—
—
Average production costs, per barrel – total(2)
6.05
5.25
6.05
2023
Average sales prices
Oil and NGL, per barrel
79.09
50.75
79.07
Natural gas, per thousand cubic feet(1)
11.37
3.46
10.92
Synthetic Oil, per barrel
—
—
—
Synthetic Gas, per thousand cubic feet
—
—
—
Average production costs, per barrel – total(2)
5.59
5.24
5.59
2022
Average sales prices
Oil and NGL, per barrel
95.91
51.38
95.88
Natural gas, per thousand cubic feet(1)
11.54
4.27
11.24
Synthetic Oil, per barrel
87.76
—
87.76
Synthetic Gas, per thousand cubic feet
8.80
—
8.80
Average production costs, per barrel – total(2)
5.78
6.33
5.78
(1)
The volumes of natural gas used in the calculation of this table are the production volumes of natural gas available for sale and are also shown in the
production table above. Natural gas amounts were converted from bbl to cubic feet in accordance with the following scale: one bbl = six cubic feet.
(2)
Lifting costs.
For information about our capitalized exploration costs, see Note 26 to our audited consolidated financial
statements and the unaudited supplementary information on oil and gas exploration and production
contained therein.
Annual Report and Form 20-F 2024 I 102
Our Business
Refining, Transportation & Marketing
We processed 69% of all our oil production, which includes oil and LNG and excludes Natural Gasoline (C5+),
in our refineries. In 2024, we produced 1,783 mbbl/d of oil products, from the processing of Brazilian oil (91%
of feedstock) and imported oil (9% of feedstock). We traded these oil products both in Brazil and abroad.
Furthermore, we operate in the petrochemical sector with interests in companies and in the fertilizer sector
with interests and plants in Brazil.
Overview
We own and operate 10 refineries in Brazil, with a total net crude distillation capacity of 1,813 mbbl/d. This
represents 83% of all refining capacity in Brazil, according to the 2024 statistical yearbook published by the
ANP. Most of our refineries are located near our crude oil pipelines, storage facilities, refined product
pipelines, and major petrochemical facilities, easing access to crude oil supplies and end-users.
We also operate a large and complex infrastructure of pipelines and terminals, and a shipping fleet to
transport oil products and crude oil to Brazilian and global markets. We operate 36 of our own terminals
through our wholly-owned subsidiary Petrobras Transporte S.A. (“Transpetro”), and we have contracts for
the use of some of the storage capacity of 17 third-party terminals, while Transpetro operates nine other
third-party terminals.
Annual Report and Form 20-F 2024 I 103
Our Business
Annual Report and Form 20-F 2024 I 104
Our Business
In 2019, we signed two agreements with CADE related to the divestment of some of our refining assets in
Brazil (REMAN, LUBNOR, RNEST, RLAM, REGAP, REPAR and REFAP) and a shale industrialization unit (SIX).
In 2024, following the strategic direction presented in the Strategic Plan 2024-2028+ in force at that time,
CADE agreed to sign an amendment through which new obligations were set regarding the activities carried
out by us in the supply of oil and oil products to third parties in Brazil, replacing the previous commitment
of divesting the refining and shale industrialization assets.
For more information on our agreement with CADE regarding our divestments in refining assets, see “Risks
– Risk Factors – 6.b) The competitive environment of the Brazilian oil and gas market may intensify the
requirements for our performance levels to remain in line with the best companies in the sector. The need to
adapt to a competitive and complex environment may compromise our ability to implement our current
Strategic Plan or any subsequent plans adopted” and “Mergers and Acquisitions”.
Main Assets
2024
2023
2022
Transport and storage
Pipelines (km)
7,768
7,768
7,768
Own
6,928
6,928
6,928
Third parties(1)
840
840
840
Vessel fleet (owned and chartered)
110
109
110
Own
25
26
26
Chartered
85
83
84
Terminals
62
65
65
Own
36(2)
37(2)
38
Third parties(3)
26
28
27
Refining
Refineries
10
10
11
Brazil
10
10
11
Abroad
—
—
—
Nominal installed capacity (mbbl/d)
1,813
1,813
1,851
Brazil
1,813
1,813
1,851
Abroad
—
—
—
(1)
Third party pipelines that have existing Transpetro transport contracts.
(2)
The number of terminals in 2023 considered the Ilha Redonda and Ilha Comprida terminals as two different terminals. In 2024,
we considered them as a single terminal, as they both make up a single integrated storage and handling system.
(3)
Third party terminals that have existing contracts for the use of the storage service, including nine terminals operated by
Transpetro.
Annual Report and Form 20-F 2024 I 105
Our Business
RefTOP - World Class Refining program
Aiming to be among the best oil refining companies in the world, since 2021 we have had a strategic
program, known as RefTOP, which consists of a set of initiatives to improve reliability, sustainability
and operational and energy efficiency. In 2023, following the revision of our refining portfolio strategy,
RefTOP was expanded to all refineries. In 2025, RefTOP is expected to make another important move,
shifting its energy performance metric from Energy Intensity Index (EII) to Solomon’s Energy
Sustainability Index (ESI), which measures the energy efficiency of the direct (scope 1) and indirect
(scope 2) sources required for operation (EII is a scope 1, or consumption-based only metric). This
move demonstrates our commitment to managing carbon emissions and minimizing its carbon
footprint, recognizing the impact of low-carbon energy sources at a broader level, and thus
considering Brazilian well stablished renewable electricity matrix, that achieved 93% of renewable
generation in 2023 (International Energy Agency, 2024).
In 2024, the crude utilization factor in our refineries reached 93%. We have been consistently
promoting the integration of maintenance, inspection, engineering, and operation systems, allowing
for more accurate diagnoses, less time for decision-making and failures reduction.
We keep implementing new projects and OPEX opportunities to increase energy efficiency and
sustainability, leading to a consistent reduction in GHG emissions intensity, flaring emissions, and
natural gas consumption. The GHG emissions intensity has fallen from 36.8 kgCO2e/CWT in 2023 to
36.2 kgCO2e/CWT in 2024, considering all refineries.
New investments on RefTOP are expected to reach US$826 million in all refineries from 2024 to 2029.
Refining
We serve our oil products clients in Brazil through a coordinated combination of oil processing, importing
and exporting that according to our commercial strategy seeks to optimize our margins, considering
different opportunity costs of domestic and imported oil, oil products in the different markets, as well as
the costs of related transport, storage and processing.
In 2024, we processed 1,706 mbbl/d of oil in our 10 refineries. The following graphs show the processed
feedstock and the performance of our refineries.
Annual Report and Form 20-F 2024 I 106
Our Business
PROCESSED FEEDSTOCK (mbbl/d)
Over the past 15 years, we have made substantial investments in our existing refineries to increase our
capacity to economically process heavier Brazilian crude oil, improve the quality of our oil products to meet
stricter regulatory standards, modernize our refineries, and reduce the environmental impact of our
refining operations.
One such investment is the implementation of a new diesel hydrotreatment unit at the Paulínia Refinery
(“REPLAN”), currently in the process of construction and assembling equipment and installations.
With this project, REPLAN is expected to be able to produce 100% ultra-low sulfur diesel (the “ULSD” or the
“S-10”) and increase the production of jet fuel, aiming to meet the specification and quantities demanded
by the future market, in an economic way, with operational safety and lower impacts to the environment.
The new diesel hydrotreatment unit is expected to have a production capacity of 63 mbbl/d of S-10 and is
scheduled to start operation in 2025, in line with the Strategic Plan.
The following table sets out the performance of our refineries.
In 2024, the processed
feedstock
remained
at the same level as in
2023.
Annual Report and Form 20-F 2024 I 107
Our Business
PERFORMANCE OF REFINERIES
Crude
distillation
capacity
(mbbl/d)
Nelson
Complexity
Index
Average throughput(1)
(mbbl/d)
Operational availability
(%)
Total Utilization rate(2)
(%)
Refinery
2024
2024
2024
2023
2022
2024
2023
2022
2024
2023
2022
LUBNOR
8
3.5
8
9
8
98.4
97.7
97.6
97.5
107.8 106.7
RECAP
57
6.8
53
56
58
94.8
97.6
97.0
93.0
98.8 102.9
REDUC
239
15.4
212
221
205
96.0
91.5
96.0
89.8
93.7
86.8
REFAP
201
6.0
167
143
155
93.7
94.2
92.9
87.5
74.7
82.0
REGAP
157
7.9
149
146
146
97.6
97.6
97.3
97.4
95.1
94.7
REMAN
—
—
—
—
28(3)
—
—
98.0
—
—
67.3
REPAR
208
7.8
193
201
157
97.6
97.8
97.0
93.4
98.2
77.9
REPLAN
434
6.9
394
398
376
97.9
97.8
97.5
91.9
92.5
87.3
REVAP
252
8.6
235
235
227
95.8
96.5
96.9
93.9
93.7
91.6
RLAM
—
—
—
—
—
—
—
—
—
—
—
RPBC
170
10.2
169
155
173
95.5
95.3
96.9
99.9
92.0 102.7
AIG
(Former RPCC)
—
—
—
11
24
—
—
—
0
68.7
63.7
RNEST
88
7.6
81
74
61
95.4
93
84.9
97.7
95.1
83.0
Average crude oil
throughput
—
—
1,661
1,649
1,619
—
—
—
—
—
—
Average NGL
throughput
—
—
45
47
43
—
—
—
—
—
—
Average
throughput
—
—
1,706
1,696
1,662
—
—
—
—
—
—
Crude Distillation
capacity
1,813
—
—
—
—
—
—
—
—
—
—
(1)
Includes oil and NGL processing (fresh feedstock).
(2)
Total utilization rate includes the entire load in the distillation units, consisting of oil, C5 + and reprocessing (of oil and other products).
(3)
Average until November 2022.
Annual Report and Form 20-F 2024 I 108
Our Business
MAIN PRODUCTS, MARKETS AND STORAGE CAPACITY OF OUR REFINERIES
Storage capacity
(mbbl)
Refinery
Main products
Main markets in Brazil
Crude
oil
Oil
products
LUBNOR
Asphalt (47%); Fuel Oil (35%);
Lubricants (12%); Diesel (6%)
Lubricant Oil – sold to distributors and marketed
nationwide; Asphalts – states in Northern and
Northeastern Brazil and Minas Gerais
0.3
0.4
RECAP
Diesel (42%); Gasoline (30%); LPG
(9%)
Part of the São Paulo metro region and
petrochemical plants
0.6
1.7
REDUC
Diesel (23%); Gasoline (17%); Fuel
Oil (18%); LPG (9%); Jet Fuel (8%);
Naphtha (10%)
Rio de Janeiro, São Paulo, Espírito Santo, Minas
Gerais, Bahia, Ceará, Paraná, Rio Grande do Sul
5.9
11.0
REFAP
Diesel (49%); Gasoline (28%);
Naphtha (4%); LPG (8%)
Rio Grande do Sul, part of Santa Catarina and
Paraná, in addition to other states by means of
coastal shipping
3.1
5.7
REGAP
Diesel (44%); Gasoline (25%); Jet
Fuel (7%); LPG (7%)
Currently supplies the state of Minas Gerais and,
occasionally, the state of Espírito Santo. It can
also expand its reach to the Rio de Janeiro
market
2.0
5.4
REPAR
Diesel (43%); Gasoline (30%); LPG
(8%)
Paraná, Santa Catarina, Southern São Paulo and
Mato Grosso do Sul
3.3
5.8
REPLAN
Diesel (44%); Gasoline (24%); LPG
(6%); Jet Fuel (3%); Fuel Oil (10%)
Countryside of the state of São Paulo, Mato
Grosso, Mato Grosso do Sul, Rondônia and Acre,
Southern Minas Gerais and the so-called
“Triângulo Mineiro”, Goiás, Brasília, and
Tocantins
5.6
11.4
REVAP
Diesel (27%)); Gasoline (23%);
Naphtha (8%); Jet Fuel (15%);
Fuel Oil (13%)
Paraíba Valley, the northern coast of the state of
São Paulo, southern Minas Gerais, the São Paulo
metro region, Midwestern Brazil and Southern
Rio de Janeiro. It supplies 80% of the demand for
jet fuel in the São Paulo state market and 100%
of the Guarulhos International Airport
4.8
10.5
RPBC
Diesel (48%); Gasoline (28%); Fuel
Oil (11%); LPG (4%)
Most products are intended for São Paulo’s
capital. A portion is also shipped to Santos and
to the Northern, Northeastern, and Southern
Brazilian regions
2.6
7.1
RNEST
Diesel (60%); Naphtha (13%);
Coke (10%); Fuel Oil (13%)
North and Northeast of Brazil
—(1)
5.6
(1)
Crude oil is supplied directly to RNEST’s tank farms of 4.2 mbbl, with no external crude oil storage.
Annual Report and Form 20-F 2024 I 109
Our Business
With respect to oil products, we produced 1,783 mbbl/d of oil products in 2024, as shown in the following
graphic:
OIL PRODUCTS PRODUCTION (mbbl/d)
In 2024, compared to 2023, there was an increase in the production of gasoline (4.2%), jet fuel (3.6%) and
asphalt (4.4%), due to the domestic demand growth and supported by high results in refineries availability,
reliability and performance. In 2024, we achieved the annual record in Diesel S-10 production, increased by
5.1% from 2023.
Annual Report and Form 20-F 2024 I 110
Our Business
Ongoing undertakings
BOAVENTURA
Following our current strategy, the Boaventura Cluster, previously known as GASLUB, located in
Itaboraí, state of Rio de Janeiro, is being remodeled. New solutions are being evaluated, such as a new
refining area, a natural gas process plant and a thermoelectric power plant. This scope considers
integration with REDUC refinery and consists of a catalytic hydrocracking, hydrotreating and
hydroisodewaxing plant to produce Group II base lube oils which comprise a new generation of lube
oils with higher viscosity indexes, improved oxidation stability and better overall performance
compared to Group I base oils. The units are expected to be able to produce high-quality fuels as well,
and additional investments included in our Strategic Plan, along integration with REDUC, are expected
to increase S-10 production by 76 mbbl/d. For this scope, construction is expected to be contracted
by the end of the first quarter of 2025. Furthermore, a study was initiated to evaluate the
implementation of a dedicated plant to process renewable feedstocks (vegetable oils and animal fat)
and to produce advanced fuels such as BioQAV (also known as SAF or Biojet fuel) and/or Hydrotreated
Vegetable Oil (the “HVO”) applying the Hydroprocessed Esters and Fatty Acids technology and also
petrochemical products.
For the natural gas processing plant, a new construction, management and commissioning contract
was signed in March 2023, whose construction and commissioning milestones were achieved and plant
1 entered commercial operations in November 2024. Plant 2 is expected to begin commercial
operations in the second half of 2025.
The gas-fired thermoelectric plant is still under study, and its conceptual design has been completed.
The plant obtained the environmental preliminary license in November 2024 and further planning
steps are in progress.
RNEST
RNEST (Refinery Abreu e Lima) started its operations in 2014 with the first set of units (Train I), making
it the newest and most modern of our refineries. The refinery is located in the Northeast region of
Brazil, and this location defines the plant as our main hub in the North-Northeast of the country.
RNEST is the main project for capacity expansion, with an expected increase in ultra-low sulfur diesel
(ULSD or S-10) production capacity of 94 mbbl/d. This increase in oil products output capacity further
strengthens our competitive advantage in the optimized use of our refining system. The main projects
for expanding capacity and improving the quality of oil products at RNEST include the revamp of Train
1, implementation of Train 2, and the SNOX’ project completion. The SNOX project is expected to
enable the processing of heavier crude oils, leading to a potential reduction in feedstock costs and
thereby to an improvement in margin.
The SNOX project was completed in December 2024, and the revamp of Train 1 is under construction,
while the Train 2 of RNEST is currently in the tender process, and it is scheduled to start operation by
2028.
Other ULSD Projects
With respect to the expansion of production capacity of ULSD, in addition to the new hydrotreatment
unit at the REPLAN, with an additional production capacity of 63 mbbl/d of ULSD, we also have another
investment at REVAP, which has focused on modifications to an existing diesel hydrotreating unit (U-
272D) in order to improve the S-10 production in 41 mbbl/d, meeting market specifications and
environmental requirements. This project is expected to start in 2026.
Annual Report and Form 20-F 2024 I 111
Our Business
Logistics
Oil and oil products logistics connect the oil production systems to refineries and markets seeking to
maximize the value of oil refining operations and the commercialization of oil and oil products in Brazil and
abroad through an integrated system of logistics planning, sales, and operations and assets, as depicted
below.
We directly manage some assets of this system, while we contract others with our wholly owned subsidiary
Transpetro.
Transpetro is a logistics company that performs operations for storing and handling oil and oil products,
ethanol, gas, and biofuels for the supply of Brazilian industries, thermoelectric plants and oil refineries,
including import and export activities.
The terminals and pipelines operation is an important link in our supply chain. The oil is transported from
the production fields to Transpetro terminals by pipeline or ship. From there, it is transported to refineries
or for export. After refining, the oil products are drained through pipelines to the terminals to be delivered
to fuel distribution companies, which supply the Brazilian and global markets. This operation covers a 7,768
km pipeline network and 45 terminals, of which 24 are marine and 21 are onshore (including the operation
of Transbel, a fully-owned subsidiary of Transpetro, established due to the obligation of auctioning public
port areas). Transpetro operates terminals owned by Petrobras and third parties, with a total nominal
storage capacity of 10.73 million m3. In 2024, Transpetro handled 651 million m3 of oil, oil products and
biofuels, totaling 6,143 operations with tankers and oil barges.
Annual Report and Form 20-F 2024 I 112
Our Business
We move oil and oil products, whether by cabotage or long-haul navigation, in response to the demands of
our customers. The fleet operated by Transpetro comprises 33 vessels (26 of which Transpetro owns and
seven of which we contract through the subsidiary Transpetro International BV), and this operating fleet
has an average age of ten years. The transport capacity of this fleet is 3.2 million deadweight tons. In 2024,
this fleet handled around 46.6 million m3 of oil and oil products, about 23% of the cargo handled by
Petrobras by sea.
In addition, we operate 78 ships chartered directly by Petrobras from third parties. This operation has the
capacity to transport 5.5 million deadweight tons and, in 2024, handled 177.0 million m3.
THROUGHPUT OF TERMINALS AND PIPELINES (million m3)
We are constantly looking for excellence in the integrity of our assets and operational efficiency.
The operational efficiency of Transpetro’s fleet, represented by the Operational Availability Index (which
calculates the proportion of time the vessel was operationally ready, excluding the time spent in dry dock),
was 99.2% in 2024 as compared to 99% in 2023. The increase in this index in 2024 ensured Transpetro’s best
result in the last seven years.
Fuel theft in onshore pipelines
The engagement between Petrobras and Transpetro in 2024 remains a determining factor for considerable
advancement in combating fuel theft actions in our pipeline network, also known as illegal tapping. This
partnership resulted in actions that ensured our commitment to life, the environment, and operational
safety.
We have continued strengthening our relationship with Brazil’s public security forces, tightening ties with
neighboring communities in our pipeline networks, expanding awareness and social projects, and investing
in the improvement of technological tools, aimed at greater effectiveness in preventing illegal tapping.
These actions enabled, over the last year, a reduction of 11% in the number of cases compared to the
previous year, dropping from 28 occurrences in 2023 to 25 occurrences in 2024. We also eliminated the
number of occurrences in urban areas, minimizing risks to the surrounding population.
Annual Report and Form 20-F 2024 I 113
Our Business
Finally, the achievements denoted by the results confirm the reduction of risk associated with illegal
tapping.
OWN TERMINALS
Location
Terminal
Type
Nominal capacity (m³)
Alagoas
Maceió(1)
Marine
58,265
Amazonas
Coari
Marine
86,147
Ceará
Mucuripe
Marine
N/A (2)
Espírito Santo
Barra do Riacho
Vitória
Marine
Marine
107,834
10,710
Distrito Federal
Brasília
Onshore
72,308
Goiás
Senador Canedo
Onshore
127,778
Maranhão
São Luís
Marine
78,897
Minas Gerais
Uberaba
Uberlândia
Onshore
Onshore
54,812
45,812
Pará
Belém
Marine
48,186
Pernambuco
Suape
Marine
108,562
Paraná
Paranaguá
Marine
204,567
Rio de Janeiro
Ilha d’ Água
Angra dos Reis
Campos Elíseos
Ilha Redonda & Ilha Comprida(3)
Japeri
Volta Redonda
Cabiúnas
Marine
Marine
Onshore
Marine
Onshore
Onshore
Onshore
179,173
1,011,487
547,284
75,484
37,650
25,502
483,134
Rio Grande do Sul
Niterói
Rio Grande
Osório
Marine
Marine
Marine
21,189
101,422
842,393
Santa Catarina
Biguaçu
Itajaí
Guaramirim
São Francisco do Sul
Onshore
Onshore
Onshore
Marine
36,214
56,482
18,644
473,166
São Paulo
Santos
São Sebastião
Barueri
Cubatão
Guararema
Guarulhos
Paulínia
Ribeirão Preto
São Caetano do Sul
Marine
Marine
Onshore
Onshore
Onshore
Onshore
Onshore
Onshore
Onshore
388,873
2,057,493
206,462
161,100
1,026,934
164,181
274,608
50,886
227,308
TOTAL
36
–
9,470,947
(1)
The Maceió terminal was leased until February 2025, when the contract ended.
(2)
The terminal only pumps product. There is no product tank on this site.
(3)
The Ilha Redonda and Ilha Comprida terminals make up a single integrated storage and handling system.
Annual Report and Form 20-F 2024 I 114
Our Business
Marketing
Annual Report and Form 20-F 2024 I 115
Our Business
SALES VOLUMES OF OIL PRODUCTS TO BRAZILIAN MARKET, PER PRODUCT AND TOTAL IN THE YEAR
(mbbl/d)
Diesel
Diesel is a medium petroleum distillate used as fuel in vehicles with compression-ignites internal
combustion engines (diesel cycle engines). It is used mostly for cargo and passenger’s road transport
(80%) and in the agriculture sector (10%). All diesel sold to end users in Brazil must be blended with
biodiesel. In March 2024, the mandatory level of biodiesel in the fuel increased from 12% to 14%, as
decided by the National Energy Policy Council (CNPE).
In 2024, S-10 diesel sales represented 64.4% of our diesel sales, surpassing the 62% achieved in 2023.
The decrease in diesel oil sales in 2024 was mainly associated with the increase in the mandatory blend
of biodiesel, and the increase in imports by other agents to Brazil, especially those from Russia. The
record share of S-10 Diesel as it relates to total diesel sales reflects the commercial and operational
actions that we have implemented in order to meet the Brazilian domestic demand for the product
with lower sulfur content, replacing the S-500 Diesel.
Annual Report and Form 20-F 2024 I 116
Our Business
Gasoline
Gasoline is a light petroleum distillate used in vehicles with spark-ignition internal combustion
engines (Otto Cycle engines). Refineries in Brazil produce a distillate called “gasoline A,” which must
be blended with 27% of anhydrous ethanol (current mandate) by distributors and then sold to end
users as “gasoline C” at gas stations. Its main competitors are hydrated ethanol (sold directly by
producers to distributors, who resell it in gas stations) and CNG - Compressed Natural Gas (sold by
gas distributors directly to gas stations). In 2024, the “gasoline A” sold by us represented 39% the
total Brazilian Otto-Cycle market.
Gasoline sales in 2024 decreased mainly due to the loss of market share to hydrous ethanol in flex-
fuel vehicles. This was driven by the full federal re-taxation throughout 2023 and the increase in fuel
taxes in 2024, which made the hydrous ethanol a more attractive option for consumers.
LPG
The LPG is a light distillate composed by propane and butane. It is used as fuel for heating appliances
such as cooking equipment, rural heating and water boilers, among others. In Brazil, around 70% of
LPG is sold in bottled cylinders of up to 13 kg by distributors and primarily used for residential cooking
and its demand is directly driven by population growth and real income growth. On the other hand,
consumption is inversely correlated with local temperatures and the efficiency rate of cooking
equipment. The remaining 30% of LPG demand comes mainly from industrial and services sectors,
whose demand is driven by economic growth.
The rise in LPG sales in 2024 was mainly associated with the increase in the Brazilian population’s
income, a reduction in unemployment, and social programs that facilitate access for the low-income
population to LPG for cooking.
Naphtha
Naphtha is a light petroleum distillate that is mainly used as raw material for the Petrochemical
sector. This product is sold to three existing petrochemical plants in Brazil, which produce commodity
chemicals such as ethylene, propylene, butadiene and aromatics (benzene, toluene, xylenes).
The 2.9% rise in our naphtha sales in 2024 was mainly associated with the increase in demand from
Braskem’s São Paulo petrochemical complex.
Annual Report and Form 20-F 2024 I 117
Our Business
Besides oil and oil products, we also trade natural gas, nitrogen fertilizers, renewables and other products.
BRAZILIAN SALES VOLUMES AND EXPORTS (mbbl/d)
2024
2023
2022
Total oil products
1,719
1,744
1,753
Natural gas
206
226
305
Crude oil
147
181
202
Ethanol, nitrogen fertilizers, renewables and other products
7
4
3
Total Brazilian market
2,079
2,155
2,263
Exports(1)
798
806
714
TOTAL BRAZILIAN MARKET AND EXPORTS
2,877
2,961
2,977
(1)
Mainly includes crude oil and oil products.
Jet Fuel
Jet-fuel is a medium petroleum distillate used as aviation fuel in aircrafts powered by gas-turbine
engines.
It is used by all commercial aviation companies (passengers and cargo transportation). Jet-fuel
demand is strongly correlated with GDP growth, as it directly affects the demand for travel – business
and leisure.
The main factor behind the rise of sales in 2024 was the increase in economic activity in Brazil, that
stimulates both passenger flights and cargo movement.
Fuel Oil
Fuel oil is a residual fraction of the petroleum distillation. It is used in industrial (mostly non-ferrous
metallurgy companies) and electricity generation sectors (thermoelectric plants). The demand for
fuel oil for industrial consumption depends mostly on GDP growth and on the natural gas availability
and competitiveness (its main competing product).
The fuel oil thermoelectric plants participate marginally in the country’s energy supply, entering into
operation only when the water level in reservoirs is very low. In 2024, industrial use of fuel oil
represented around 95% of demand, while the use in power generation represented only 5%. In 2024,
the main factor for the sales shrinkage was the drop in demand caused by the migration of oil fuel
consumption to natural gas by consumers in the North of Brazil.
Annual Report and Form 20-F 2024 I 118
Our Business
Oil products prices
Crude oil is a commodity, the value of which depends on its quality, mainly based on its API Gravity
and sulfur content. Traditionally, lighter crude oils have greater added value than heavier ones,
given that they can generate higher value products. Lower sulfur content crudes tend to have
more market value compared to higher sulfur ones with similar yields. Over the past few years,
however, heavy crudes have shown a strong market value due to the possibility of high margin
production when these crudes are processed in refineries with more complex hardware. Different
refineries assign different values to the same crude oil, depending on their conversion capacity
and the value of the products they intend to produce to supply their specific markets. Refineries
can process a variety of crude oils, which brings flexibility to process different grades.
Crude oils are globally traded and their prices are usually referenced in international quotations,
such as WTI, Brent or Dubai. Depending on factors such as quality, supply, demand, size lot,
trading conditions and logistics costs to make a crude oil cargo available at a certain delivery
point, a premium or a discount can be negotiated between buyer and seller.
Refined oil products are commodities and their prices in different regions of the global market
are driven by the local balance between supply and demand, crude oil prices and crack spread.
Crack spread refers to the overall pricing difference between a barrel of crude and the oil products
refined from it. It is an industry-specific type of gross processing margin. “Crack” is a term used
in the oil industry that represents the ability of a crude to produce different products such as
gases like propane and butane; light distillates like naphtha and gasoline; middle distillates like
kerosene, gas oils and diesel fuels; and heavy distillates like heavy fuel oil and asphalt. Typically,
a crack is defined in terms of one specific product versus one specific crude. For example, the
diesel crack on Brent indicates how much the price of the individual product is contributing to
refining profitability.
The price of a barrel of crude oil and the various prices of the products refined from it are not
always in perfect synchronization. Depending on seasonality and global inventories, among other
factors, the supply and demand for any particular oil product may result in pricing changes that
can impact the profit margins on a barrel of crude oil for the refiner.
As oil products are traded globally and can be transported between markets, prices around the
world tend to fluctuate subject to local conditions.
Currently, as a result of the ongoing military conflict between Russia and Ukraine and the conflict
in the Middle East, benchmark prices for oil, oil products, natural gas and LNG remain extremely
volatile. We cannot predict the extent to which these conflicts will impact our business. These
events also affect oil flows and related markets. An example is the change in exports of oil
supplied by Russia being diverted to China and India, limiting the demand from these markets for
other suppliers.
Our current positioning on pricing in Brazil takes into account domestic market conditions and
seeks to align the price of oil products with international prices while avoiding the immediate
transfer of volatility of international quotations and the exchange rate caused by conjunctural
issues.
Since 2022, we have followed our Guideline for Price Formation in the Domestic Market
(“Guideline”), approved by our Board of Directors, in line with its objective of continuously
improving our governance. The Guideline reiterates the Executive Board’s competence in
executing pricing policies, preserving and prioritizing our financial results and seeking to
maximize its value creation. Furthermore, the Guideline incorporates an additional layer of
Annual Report and Form 20-F 2024 I 119
Our Business
supervision over execution of the pricing policies by the Board of Directors and the Fiscal Council,
based on the Executive Board’s quarterly report, formalizing an already existing practice.
DIESEL AND GASOLINE
We have a commercial strategy in place since 2023 to define our diesel and gasoline prices,
replacing the former pricing policy. The commercial strategy considers market references such
as: (a) the customer’s alternative cost, as a value to be prioritized in pricing, and (b) our marginal
value. The customer’s alternative cost refers to the cost of the main supply alternatives, whether
the same or substitute products, and the marginal value is based on the opportunity cost given
the various alternatives for the company, among them, production, imports and exports of the
product and/or the oils used in refining. The commercial strategy is premised on competitive
prices per sales hub, in balance with the national and international markets, taking into account
the best alternative accessible to customers. This strategy allows us to compete more efficiently,
taking into account our market share, optimize our refining assets, and to obtain profitability on
a sustainable basis.
Price readjustments are expected to continue to be made without a defined periodicity, avoiding
the transfer to domestic prices of the cyclical volatility of international prices and of the exchange
rate to domestic prices.
The commercial strategy is aligned with the Guideline approved by the Board of Directors on July
27, 2022.
During 2024, we announced adjustments to selling prices at refineries, resulting in a price
increase of 7.1% for gasoline, when comparing prices in place on December 31, 2024 with those
effective as of December 31, 2023. And there was no price adjustment for diesel in 2024.
LPG
LPG prices in the Brazilian market are defined taking into account the balance with the
international prices and the level of market share, in the residential and industrial/commercial
LPG segments. According to our pricing policy, price adjustments are made without defined
periodicity, according to market conditions and analysis of internal and external environments.
During 2024, we announced adjustments to selling prices at refineries, resulting in price increases
of 9.8% for LPG, when comparing prices in place on December 31, 2024 with those effective as of
December 31, 2023.
Imports, Exports, and International Sales
Our import and export of crude and oil products are driven by economic factors involving our domestic
refining, the Brazilian demand levels and international prices. Most of the crude oil we produce in Brazil is
classified as medium API Gravity. We import some light crude oil to balance the slate for our refineries, and
export mainly medium crude oil from our production in Brazil. In addition, we continue to import oil products
in order to balance any shortfall between production from our Brazilian refineries and the market demand
for each product.
In 2024, net exports increased by 14 mbbl/d, reaching 499 mbbl/d. This increase resulted mainly from lower
imports of oil products in 2024, mainly gasoline, due to increased production with higher utilization of
refineries in the year 2024.
Annual Report and Form 20-F 2024 I 120
Our Business
EXPORTS AND IMPORTS OF CRUDE OIL AND OIL PRODUCTS (mbbl/d)
2024
2023
2022
Exports
Crude oil
602
594
513
Fuel oil
150
161
181
Other oil products
46
51
20
Total exports
798
806
714
Imports
Crude oil
151
156
164
Diesel
60
63
118
Gasoline
11
39
25
Other oil products
77
63
86
Total imports
299
321
393
Our crude oil, oil products and LNG trading activities aim to meet our internal demands or potential
businesses opportunities identified by our commercial teams, seeking to optimize the buying and selling
operations in the Brazilian and global markets, as well as offshore operations.
The international trading teams are based in the major global commercial hubs of oil and oil products, such
as Houston, Singapore, Buenos Aires and Rotterdam and are comprised of crude oil, oil products and
biofuels traders, LNG, shipping and support operators.
For more information on our oil and oil products clients, see “Exploration & Production – Customers and
Competitors” and “Refining, Transportation & Marketing – Customers and Competitors” in this annual
report.
Annual Report and Form 20-F 2024 I 121
Our Business
Distribution
We sell our oil products to several distribution companies in Brazil.
A 10-year trademark license agreement is in place and grants Vibra a non-exclusive, paid, temporary license
on certain trademarks we own, including but not limited to “Petrobras,” “Petrobras Podium,” “Petrobras
Premmia,” “De Olho no Combustível,” “BR Aviation” and “Petrobras Grid.” The contract expires in June 2029
and must comply with the established debranding obligations.
Under the terms of this agreement, the license is granted exclusively to the service station and aviation
segments, for which Vibra shall exclusively use the brands licensed by us. Meanwhile, during the term of the
trademark license agreement, we undertake to refrain from operating in the service stations sector across
the Brazilian territory. The definition of a “service station” under this agreement is any facility where oil and
gas products and services and/or services related to any other energy sources (renewable or otherwise)
intended to power automotive vehicles and watercrafts are offered to the Business-to-Consumer (or B2C)
public, including convenience stores. In January 2024, we notified Vibra that we have no interest in
extending the trademark license agreement under the current terms. The parties have been evaluating the
need for modifications to the license. We expect this decision will permit us to evaluate new brand
management strategies and business opportunities.
We also participate in the retail sector in other South American countries, as follows:
_ Colombia: our operations through Petrobras Colombia Combustibles S.A. (PECOCO) include 121
service stations and a lubricant plant with a production capacity of 54,000 m3/year. PECOCO was in
Petrobras divestment portfolio until March 2025 when our Executive Board approved the
termination of the divestment project, in line with the current strategic drivers, which consider
portfolio diversification both profitable and sustainable for the company;
_ Chile: following the sale of our distribution operations in Chile, which was concluded in January 2017,
we entered into a brand licensing agreement in that country, for the initial term of eight years. To
operate our acquired assets in Chile, Southern Cross created Esmax, a company that operates as our
licensee in the fuel distribution segment. In July 2024, after the sale of Esmax from Southern Cross
to Aramco, Petrobras and Esmax reached an agreement to extend the contract term until December
31, 2025. This extension aims to facilitate a comprehensive rebranding of Petrobras’ trademarks to
Aramco; and
_ Paraguay: following the sale of our distribution operations in Paraguay, which was concluded in
2019, we entered into a brand licensing agreement in Paraguay for the exclusive use of our brands,
for the initial term of five years. The parties have approved an extension of the contract term
through 2026.
For more information of the divestment process, see “Mergers and Acquisitions” in this annual report.
Annual Report and Form 20-F 2024 I 122
Our Business
Customers and Competitors
We interact with 485 clients in Brazil, in regard to liquid and solid products, seven of which account for 66%
of the total volume sold.
LIQUID AND SOLID OIL PRODUCTS CLIENTS (% vol)
The sale of oil products to distribution companies is done mainly by contracts executed in accordance with
ANP regulations.
We offer a virtual commercial platform, called Canal Cliente to Brazilian market companies. The platform
works 24 hours a day, seven days a week. Through this online platform, clients can place orders for products,
schedule withdrawals and track the entire business process up to the payment phase.
According to information provided by the ANP, we have a dominant participation in the Brazilian market for
refining. We own and operate 10 refineries in Brazil.
With respect to the trading of oil products in the Brazilian market, we face competition from importers,
formulators, other domestic producers and petrochemical plants.
In 2024, our participation in diesel markets decreased compared to the previous year, mainly due to the
increase in the mandatory blend of biodiesel, and the increase in imports by other agents to Brazil,
especially those from Russia.
Our share in the gasoline market also declined driven by changes in taxes. In 2022, the Brazilian federal
government eliminated federal taxes on gasoline and ethanol, which impacted gasoline C prices more than
hydrated ethanol prices due to the higher tax burden on gasoline C. This altered the price relationship
between the two substitute products, leading to increased gasoline C consumption in flex-fuel vehicles. In
2023, the federal government reinstated federal tax rates on gasoline and ethanol in two phases, with
states also raising the ICMS tax on gasoline C in February 2023 and 2024. This change affected the price
dynamics at the pumps, resulting in a resurgence of hydrated ethanol consumption over gasoline C.
Consequently, Petrobras’ gasoline A sales, which initially grew, declined in 2024.
Annual Report and Form 20-F 2024 I 123
Our Business
Other Activities
Petrochemicals
We engage in the Petrochemical sector through the following companies:
OUR SHAREHOLDING IN PETROCHEMICAL COMPANIES IN BRAZIL AND THEIR MAIN PRODUCTS
Company/Main products
Location
Nominal capacity
(mmt/y)
Our
shareholding
Other shareholding
Braskem(1)
Basic Chemicals
Brazil
9.73
36.15 %
Novonor (38.32%);
PVC
Brazil
0.71
Others (25.53%)
Ethene
Mexico
1.05
Polyethylene
Brazil
3.20
Mexico
1.05
Polypropylene
Brazil
1.85
USA
2.02
Germany
0.63
METANOR S.A./COPENOR S.A.(2)
Formaldehyde
Brazil
0.09
34.54%
Dexxos Participações
(45.47%);
Hexamine
0.01
Others (19.99%)
Fábrica Carioca de Catalisadores S.A.
Catalysts
Brazil
0.04
50.00%
Ketjen (3) (50.00%)
Additives
0.01
PETROCOQUE S.A.
Calcined petroleum coke
Brazil
0.55
50.00%
Universal
Empreendimentos e
Participações Ltda
(50.00%)
(1)
Capacities obtained at Investor Toolkit in Braskem´s Investor Relations site.
(2)
Copernor S.A. is a subsidiary of Metanor S.A.
(3)
Ketjen Brazil Holdings Ltda, subsidiary of the former shareholder Albemarle Brazil Holdings Ltda
In 2023, we received a letter regarding the non-binding proposal for the acquisition of Novonor S.A.’s
interest in Braskem. The information was forwarded to us due to the fact that we are Braskem’s second
largest shareholder and a party to the shareholders’ agreement, which contains Tag Along and ROFR
provisions. During the second semester of 2023 and the beginning of 2024, we conducted the due diligence
process, but the interested company and Novonor didn't reach an agreement for the potential transaction.
We remain vigilant and prepared for any potential corporate movements concerning Novonor's stake in
Braskem.
Annual Report and Form 20-F 2024 I 124
Our Business
Fertilizers
We have three fertilizer plants in Brazil, one located in the state of Bahia (FAFEN-BA), one in the state of
Sergipe (FAFEN-SE), and one through our subsidiary located in Paraná, Araucaria Nitrogenados S.A. (ANSA),
that has been mothballed since January 2020. Their main products are ammonia and urea. Together these
plants have an installed capacity of 1.852 million t/year of urea, 1.406 million t/y of ammonia, 319,000 t/y
of ammonium sulfate and 800,000 t/y of Automotive Liquid Reducing Agent (ARLA-32).
We also have an unfinished Nitrogen Fertilizer Unit (UFN-III) in Mato Grosso do Sul. The construction of
UFN-III began in September 2011, but was halted in December 2014, with about 81% of the physical
construction completed. In October 2024, we decided to resume the implementation of the UFN-III, with
operations expected to commence in 2028.
Since 2020, after being mothballed in 2019, our plants located in Bahia and Sergipe have been leased to
Proquigel Química S.A. (the “Proquigel Química”), a company of the Unigel Group for an initial term of 10
years, which may be extended for an additional 10 years.
In December 2023, we signed a contract with Proquigel Química for custom industrialization (tolling) for the
production of nitrogen fertilizers in plants located in the states of Sergipe and Bahia. However, as the
conditions for its effectiveness were not met within the established period, the tolling agreement did not
enter into effect.
Following the strategic guidelines of the Strategic Plan 2024-2028+ in force at that time, in which
investment in fertilizer production has once again become part of our portfolio, reaffirmed in the Business
Plan 2025-29, in June 2024, we approved the resumption of operating activities of ANSA and the starting
of all procedures required for the reopening of the plant. The plant is expected to start operating again in
the second half of 2025.
In 2024, we signed a Memorandum of Understanding and a Master Agreement with Yara Brasil Fertilizantes
S.A. (the “Yara”), to study and structure potential commercial partnerships in the fertilizer segment,
production of industrial products and decarbonization of production. As a result of these understandings,
in November 2024 we signed two temporary agreements with Yara. The first agreement is a contract
between Petrobras, Yara, and ANSA for the production of ARLA 32 at ANSA using urea supplied by Yara.
Yara will be responsible for the commercialization of fertilizers.
The second agreement is a technical cooperation agreement between Petrobras and Yara for the
development of joint studies of fertilizers and industrial products, as well as energy transition efforts linked
to decarbonization projects and the production of renewable and low-carbon fertilizers.
We thus reinforce our commitment to leading the transformation and driving a sustainable, fair and safe
energy transition.
For more information on our new vision and strategies, see “Strategic Plan 2050 and Business Plan 2025-
2029” in this annual report.
Annual Report and Form 20-F 2024 I 125
Our Business
Gas & Low Carbon Energies
Overview
We process gas produced in our oil fields in our UPGNs that have the capacity to treat 97 million m3/d of
natural gas in Brazil. We market this natural gas, along with gas imported from Bolivia and LNG acquired in
the global market, to several consumers and to the thermoelectric plants.
We also operate in the power generation through thermal power plants fired by natural gas and diesel oil
and in the commercialization of electric energy.
The Gas & Low Carbon Energies segment strategy is to act in a competitive and integrated manner in the
operation and commercialization of gas and energy, optimize the portfolio and increase the insertion on
renewable sources.
Main Assets
2024
2023
2022
Natural gas
Gas pipelines in Brazil (km)
2,643
2,643
2,643
Processing Units (1)
13
13
15
Brazil (1)
10
10
12
Bolivia
3
3
3
Processing capacity (million m3/d)
142
138
143(2)
Brazil
97
94
99
Bolivia(3)
45
45
45
Regasification terminals
2
3(4)
3(2)
Regasification capacity (million m3/d)
40
47
47
Power
Number of thermal power plants(4) (5)
13
14
14
Installed capacity (thousand MWh)
4.9
5.3
5.3
(1)
In 2023, UPGN RPBC authorization was canceled by ANP due to its continued inactivity for two years.
(2)
The terminal (TR-BA) was leased to Excelerate Energy Comercializadora de Gás Natural Ltda until December 31, 2023.
(3)
2023 and 2022 numbers revised to consider current capacity measurement methodology.
(4)
PECEM's operation contract was valid until December 31, 2023, when it terminated. On January 1, 2024, the equipment that
comprised the Pecém LNG Regasification Terminal was transferred to the ownership of Companhia de Desenvolvimento
Industrial e Portuário do Pecém S.A.
(5)
Piratininga Power Plant had its lease agreement terminated on April 27, 2024.
(6)
Number of thermal power plants under Petrobras management, not including minority shareholdings.
Annual Report and Form 20-F 2024 I 126
Our Business
Annual Report and Form 20-F 2024 I 127
Our Business
Natural Gas
Our natural gas operations are comprised of, among other things, gas processing, transportation, and LNG
regasification.
Processing of Natural Gas
Natural gas from our Exploration & Production segment needs to be processed in processing units, to be
transformed into marketable products. These products serve as fuel and raw material for different uses,
such as transportation, industrial and residential uses, as well as in the fertilizer industry and thermoelectric
power generation.
Our UPGNs are located in the states of Amazonas, Ceará, Bahia, Espírito Santo, Rio de Janeiro and São Paulo
in Brazil as well as in Bolivia, where we have the capacity to process natural gas in its gaseous and condensed
forms.
In November 2024, the UPGN located at the Boaventura Energy Complex (UTGITB) entered commercial
operation, with authorization to produce 10.5 million m3/d of gas. In 2025, the forecast is to expand this
authorization to UPGN’s total processing capacity, which amounts to 21 million m3/d of gas.
PROCESSING CAPACITY AND PRODUCTION OF OUR UPGNS IN BRAZIL
2024
2023
2022
Location
2024
Processing
capacity
Unprocessed
natural gas
Processed
natural
gas
LPG
Unprocessed
natural gas
Processed
natural
gas
LPG
Unprocessed
natural gas
Processed
natural
gas
LPG
(million
m³/d)
(million
m³/d)
(million
m³/d)
(thousand
t/d)
(million
m³/d)
(million
m³/d)
(thousand
t/d)
(million
m³/d)
(million
m³/d)
(thousand
t/d)
UTGCAB (1)
Rio de
Janeiro
24.60
20.06
13.60
0.95
21.39
15.07
0.90
21.06
14.11
0.82
UTGCA
São Paulo
20.00
11.41
10.79
1.01
12.16
11.46
0.99
13.27
12.62
0.97
UTGC
Espírito
Santo
18.10
2.24
2.04
0.27
2.74
2.42
0.34
2.04
1.83
0.24
UTGSUL(2)
Espírito
Santo
2.50
0.05(2)
0.04(2)
–
0.06
0.05
–
0.11
0.09
–
UTGITB (3)
Rio de
Janeiro
10.50
1.67(3)
1.23(3)
0.05(3)
–
–
–
–
–
–
UPGN REDUC
Rio de
Janeiro
2.50
0.95
0.76
0.05
1.11
1.05
0.23
1.12
0.49
0.04
UPGN LUBNOR
Ceará
0.35
–
–
–
–
–
–
–
–
–
UPGN URUCU
Amazonas
12.2
11.44
10.82
0.87
12.15
11.44
0.93
11.79
11.08
0.95
UPGN CATU
Bahia
2
1.75
1.46
–
1.60
1.35
–
1.35
1.12
–
EVF MANATI
Bahia
6
–
–
–
1.67
–
–
2.47
–
–
TOTAL
—
98.75
48.13
39.70
3.16
52.88
42.84
3.39
53.21
41.34
13.86
(1)
The UTGCAB has an operational flexibility that allows for the incorporation of an additional volume of unprocessed natural gas into the gas processed
by the unit, while maintaining the regulated specifications for the final product and increasing the total volume of gas available to the market. This
flexibility has enabled increases in gas available to the market of: 2.45 million m³/d in 2022, 2.27 million m³/d in 2023, and 3.00 million m³/d in 2024, in
addition to the values indicated in this table.
(2)
UTGSUL, with a processing capacity of 2.5 million m³/d of natural gas, was mothballed on September 16, 2024, due to the lack of gas supply. Data refers
to the average values from January to September 2024.
(3)
On September 9, 2024, an authorization was granted for commercial production in module I of UTGITB, with a processing capacity of 10.5 million m³/d
of natural gas. Data refers to the average values from November to December 2024.
Annual Report and Form 20-F 2024 I 128
Our Business
Logistics
We use a pipeline system to transport natural gas from processing plants, regasification terminals and the
border with Bolivia, to the local distributors, free consumers, as well as for the internal consumption of our
units. Brazil has an integrated pipeline system centered around two main interlinked pipeline networks, a
gas pipeline connection with Bolivia and an isolated pipeline in the northern region of Brazil (all together
spanning over 9,190 km).
Annual Report and Form 20-F 2024 I 129
Our Business
OUR SHARE IN GAS TRANSPORTATION COMPANIES IN BRAZIL
Company
Gas pipeline
extension (km)
Our
shareholding
Other shareholders
Transportadora Brasileira Gasoduto Bolívia Brasil
S.A. (TBG)
2,593
51%
BBPP Holdings Ltda. (29%)
YPFB Transporte do Brasil
Holding Ltda. (19.88%)
Corumbá Holding S.À.R.L.
(0.12%)
Transportadora Sulbrasileira de Gás S.A. (TSB)
50
25%
Ipiranga Produtos de
Petróleo S.A. (25%), Repsol
Exploração Brasil (25%) and
Total Gas and Power Brazil
(25%)
TOTAL
2,643
—
—
In addition, outside Brazil we hold an 11% interest in GTB, which is responsible for the Bolivian side of the
Bolivia-Brazil gas pipeline, measuring 557 km.
Annual Report and Form 20-F 2024 I 130
Our Business
Gas from Pre-Salt
To enhance the extraction of natural gas from our production in the Santos basin Pre-salt cluster, we
invested in the construction of integrated subsea pipelines (Route 1 and GASMEX, Route 2 and Route
3), in addition to using part of the existing infrastructure. We have invested in the following flow
routes:
ROUTE 1 AND GASMEX: The 381 km pipeline consists of two stretches: Route 1, which is the stretch
connecting the Tupi Platform to the Mexilhão Platform, with capacity to flow up to 10 million m3/d;
and GASMEX, which is the stretch connecting the Mexilhão platform to the Monteiro Lobato Gas
Treatment Unit (the “UTGCA”), in the city of Caraguatatuba in the state of São Paulo, with capacity to
flow up to 20 million m3/d of gas produced in the Santos basin. GASMEX is 100% owned by Petrobras,
and we own 65% of Route 1, Shell owns 25% and Petrogal owns the remaining 10%.
Annual Report and Form 20-F 2024 I 131
Our Business
ROUTE 2: The 401 km pipeline links the Santos basin Pre-salt cluster to the Cabiúnas Gas Treatment
Unit (the “UTGCAB”) processing asset, in the city of Macaé in the state of Rio de Janeiro. The pipeline
operates with a 20 million m3/d capacity. We own 65% of Route 2 Tupi-NE-Cernambi, Shell owns 25%
and Petrogal owns the remaining 10%. We own 55% of Route 2 Cernambi-TECAB, Shell owns 25%,
Petrogal owns 10%, and Repsol owns the remaining 10%.
ROUTE 3: This 355 km gas pipeline connects the Santos basin Pre-salt cluster to the Itaboraí Gas
Treatment Unit processing asset, in the city of Itaboraí in the state of Rio de Janeiro, with a capacity
of up to 18 million m3/d. 307 km of the pipeline is offshore, and the other 48 km is onshore. The natural
gas processing plant has units with a total processing capacity of 21 million m3/d of natural gas,
increasing the supply of natural gas, LPG, and Natural Gasoline (C5+) to the market. The first module
of the Itaboraí Gas Treatment Unit started operations in September 2024. We own 100% of Route 3.
Recently installed and upcoming units in the Santos basin Pre-salt cluster are expected to be
progressively connected to Route 2 and to Route 3. All projects are expected to be able to flow through
any of the three flow routes when the system is fully implemented.
Marketing and Sales
The total demand of natural gas in 2024 was 47.5 million m3/d.
The volume of our natural gas consumption by industrial, gas-fired electric power generation, system use
gas, commercial and retail customers was 36.6 million m3/d, representing a decrease of approximately 7%
compared to 2023. This decrease is mainly attributable to a reduction in non-thermoelectric demand.
In 2024, the consumption of natural gas by our refineries was 10.9 million m3/d, which was the same level as
in 2023.
Below we present our sources and consumption in 20247F:
Annual Report and Form 20-F 2024 I 132
Our Business
GAS & ENERGY + PROGRAM
In July 2019, we signed an agreement with CADE to increase competition in the natural gas industry in Brazil,
which among other matters included the sale of shareholdings in gas transportation and distribution
companies. Due to a more open market, in 2020 we started the GAS+ Program, an internal set of actions
which aims to increase our competitiveness in the natural gas segment. In 2021, Law No. 14,134, known as
the New Gas Law that set the basis for a profound reform of the Brazilian Gas Market was promulgated. As
a result of the agreement with CADE and the New Gas Law, according to information provided by the ANP,
in 2024 around 16 new players became holders of about 29% of the non-thermoelectric Brazilian natural
gas market.
Given the strategic direction presented in the Strategic Plan 2024-2028+, in force at that time, we formally
requested a review of the agreement signed with CADE. The agreement was signed in July 2024, releasing
Petrobras from divesting TBG.
For more information on our agreement with CADE, see “Risks – Risk Factors – 6.b) The competitive
environment of the Brazilian oil and gas market may intensify the requirements for our performance levels
to remain in line with the best companies in the sector. The need to adapt to a competitive and complex
environment may compromise our ability to implement our current Strategic Plan or any subsequent plans
adopted” and “Mergers and Acquisitions” in this annual report.
In 2023, the GAS+ Program was renamed as Gas & Energy + Program (also called “Gas and power plus
Program” and “G&E+”), reinforcing actions aimed at the gas business and including actions focused on the
energy business.
The G&E+ aims to strengthen our competitive position in the natural gas open market. This program
focuses on offering the best customer relationship experience and developing and delivering products with
commercial conditions adherent to customers’ needs, to achieve the established market share and
profitability goals. It includes initiatives such as the launch of new commercial products, new forms of
customer relationships, and digital tools (such as digital contracts and sales through automated platforms),
as well as actions in the field of regulation and new business models (such as alignment of regulatory
procedures for the review of the Unit Variable Cost (UVC) thermal and LNG market).
Throughout 2024, several G&E+ initiatives were implemented. The development of these initiatives
is monitored periodically, at different levels of management, following the established project
management structure. The main achievements for 2024 are highlighted below:10F
_ recontracting our natural gas portfolio;
_ implementation of the new Customer Relationship Management platform (Evoluir Project);
_ development of appropriate processes and tools for the new market (Commercialization
Planning/Transport Contracting);
_ expansion of sales in the Natural Gas free environment; and
_ implementation of new digital solutions for operational optimization (G&E Competitive Project).
Annual Report and Form 20-F 2024 I 133
Our Business
NATURAL GAS SALES CONTRACTS AND LONG-TERM GAS PURCHASE AND TRANSPORTATION
COMMITMENTS
We sell our gas primarily to local gas distribution companies, free industrial consumers and gas-powered
plants, generally based on standard take-or-pay, long-term supply contracts. Free consumers are
consumers that, if eligible, can freely negotiate their natural gas purchases from multiple suppliers instead
of buying directly from a single distribution company. The price formulas under these contracts are mostly
aligned with Brent oil prices, LNG price markers (Henry Hub and Japan Korea Marker) and the U.S. dollar.
They were negotiated under the new gas law.
In 2024, we offered customers new products with flexible contractual conditions, allowing them to build
their own portfolio:
_ inclusion of Henry Hub, a gas-to-gas indexer, in addition to the Brent indexer;
_ diversified contractual terms, ranging from four to 10 years; and
_ two location options for delivering natural gas: (a) at the hub in which we are responsible for
contracting the entry into the transport system and the customer is responsible for contracting the
exit or (b) at the delivery point (city-gate) in which we are responsible for contracting the entry and
exit of transport.
In addition, we offered customers two different types of mechanisms for the market to reach more
competitive price levels and increase overall natural gas demand:
_ Performance Mechanism (only offered to local gas distribution companies): customers receive a
price reduction up to 11% of the Brent indexer for quantities between 60% and 100% of the
contracted volume.
_ Demand Incentive Mechanism: customers receive a price reduction up to 10% of the Brent indexer
for quantities between 90% and 100% of the contracted volume.
In addition to this diversification and flexibility, our commercial conditions seek to make the competitive
environment and the market opening process more dynamic by enabling, among others, the reduction of
volumes contracted by distributors in the event of migration of volumes from captive customers to the free
environment.
As a result, new contracts and contractual amendments were signed with 15 local distribution companies
and free industrial consumers, totaling 1.6 MM m³/d of additional contracted volume to be delivered in 2025.
The Brazilian natural gas market is becoming increasingly competitive, as new suppliers gain access to local
distribution companies and, more importantly, to industrial customers. This shift is driven by recent
reforms in the legal and regulatory frameworks in Brazil, along with our initiatives that facilitated new
suppliers to access the natural gas market (e.g., new contracts to allow new suppliers access to our natural
gas processing units and gas pipelines).
In this context, some industrial customers exercised the option to buy natural gas directly from suppliers
(including, in some cases, Petrobras), therefore, the volume contracted by Petrobras with local distribution
companies was reduced by 5 MM m³/d in 2025 due to the migration of these industrial customers to the free
natural gas market. In addition, another 1,5 MM m³/d were reduced after some of the distribution companies
exercised a contractual option required by Resolution nº 03/2022 of the National Energy Policy Council
(CNPE).
As of December 31, 2024, Petrobras’ total commitment of natural gas contracts to be delivered in 2025 is
25 MM m³/d, including contracts with distribution companies and other industrial clients signed in previous
years.
Annual Report and Form 20-F 2024 I 134
Our Business
On October 10, 2024, we entered into a settlement agreement with Gás de Alagoas S.A. – ALGÁS to cease
the existing legal disputes initiated in 2022.
1When we started building the GASBOL in 1996, we entered into a Long-term Gas Supply Agreement (“GSA”)
with the Bolivian state-owned company YPFB to purchase certain minimum volumes of natural gas, which
were based on an average delivery-or-pay commitment of 30 mmm3/d, at prices indexed to global fuel oil
prices.
The supply of gas under the GSA began on July 1, 1999. Currently, the contractual balance volumes agreed
upon since December 31, 2023 indicates a potential extension of the term of the contract to February 2028,
if delivery or pay conditions are met, or October 2029, if take-or-pay withdraw volumes are taken into
account. The main commitment adjustments were the Addendum 11, celebrated in 2022, and Addendum
12, celebrated in December 2023, resulting from the negotiation to adjust the GSA to the declining
production of Bolivian natural gas15F.
Regarding transport contracts, we have signed agreements with (i) GTB, which operates the transmission
network in Bolivia, connecting Bolivian gas production to the Brazilian border, and (ii) TBG, TAG, and NTS,
which operate the Brazilian transmission network. The contracts have different durations, some of which
are long-term. Since 2019, the market opening process has started with public auctions for contracting
capacity in TBG's transport network taking into consideration the reduction of Petrobras’ commitments in
that system.
The table below shows the potential effect of the contractual commitments under the above agreements
for the five-year period from 2025 through 2029.
Annual Report and Form 20-F 2024 I 135
Our Business
FUTURE COMMITMENTS UNDER NATURAL GAS SALES CONTRACTS (1)
2025
2026
2027
2028
2029
To non thermoelectric clients
Related parties (mmm3/d) (2) (3)
–
–
–
–
–
Third parties (mmm3/d) (3)
21.22
23.42
22.57
22.11
19.19
To gas-fired power plants
Related parties (mmm3/d) (2) (3)
–
–
–
–
–
Third parties (mmm3/d) (3)
4.85
5.73
5.42
5.42
5.42
Total (mmm3/d) (2) (3)
26.07
29.16
27.99
27.53
24.61
Estimated amounts to be invoiced (US$ million) (3) (4)
4,124.63
4,371.74
4,116.68
4,007.19
3,456.68
Purchase Commitments
Purchase commitments to YPFB
Volume obligation (mmm3/d)
7.46
4.95
4.20
4.20
3.50
Volume obligation (mmcf/d)
263.49
174.87
148.32
148.32
123.51
Brent Crude Oil projection (US$)
83.2
77.00
74.00
71.00
68.00
Estimated payments (US$ million) (5)
630.94
394.77
315.92
298.07
233.15
Transportation Commitments
Ship-or-pay contract with GTB
Volume commitment (mmm3/d)
6.00
6.00
6.00
6.00
6.00
Volume commitment (mmcf/d)
211.89
211.89
211.89
211.89
211.89
Estimated payments (US$ million) (6)
0.40
0.40
0.40
0.40
0.40
Ship-or-pay contract with TBG (7) (8)
Volume commitment (mmm3/d) (9)
35.88
11.60
11.74
11.23
11.20
Volume commitment (mmcf/d)
1,267.02
409.72
414.52
396.41
395.52
Estimated payments (US$ million) (6)
154.76
11.83
13.69
7.23
6.96
Ship-or-pay contract with NTS
Volume commitment (mmm3/d)
171.77
127.84
127.83
127.85
114.40
Volume commitment (mmcf/d)
6,065.97
4,514.60
4,514.35
4,514.91
4,040.00
Estimated payments (US$ million) (6) (10)
1,681.45
1,259.45
1,273.40
1,284.94
1,085.00
Ship-or-pay contract with TAG
Volume commitment (mmm3/d)
73.60
52.00
52.00
52.00
52.00
Volume commitment (mmcf/d)
2,599.23
1,836.19
1,836.19
1,836.19
1,836.19
Estimated payments (US$ million) (6) (11)
1,795.51
1,395.94
1,411.50
1,424.06
1,434.55
(1)
The table considers information such as estimated volumes, estimated withdrawal and Brent Crude Oil price, based on our Strategic Plan 2050 and
Business Plan 2025-29, approved on November 21, 2024 (subsequent events shall be incorporated into the next cycle of strategic planning).
(2)
For purposes of this table, “related parties” include all local gas distribution companies and power generation plants in which we have an equity interest
and “third parties” refer to those in which we do not have equity interest.
(3)
Estimates are based on outside sales and do not include internal consumption or transfers.
(4)
Prices may be adjusted in the future, according to formula defined in contract, and actual amounts may vary.
(5)
Estimated payments are calculated using gas prices expected for each year based on our Brent Crude Oil price forecast. Gas prices may be adjusted in the
future based on contract clauses and amounts of natural gas purchased by us may vary annually.
(6)
Amounts calculated based on current prices defined in natural gas transport contracts.
(7)
The ship-or-pay contract shown with TBG is eliminated in our audited consolidated financial statements, since such contract is considered intercompany
transactions.
(8)
The sum of legacy contracts (TCO and CPAC) was considered with the new entry and exit contracts, object of public calls.
(9)
The volumes may increase as a result of public calls for contracting capacity.
(10) The estimated payments from Petrobras to NTS will be monthly reduced in order to reflect the payments made by other companies to NTS in the gas
transportation contracts signed as result of the agreement of reduction of flexibility signed between Petrobras and NTS in September 2022.
(11) The estimated payments from Petrobras to TAG will be reduced monthly in order to reflect the payments made by other companies to TAG in the gas
transportation contracts signed as result of the agreement of reduction of flexibility signed between Petrobras and TAG in December 2021.
Annual Report and Form 20-F 2024 I 136
Our Business
Power
Brazilian electricity needs are mainly met by hydroelectric power plants and other sources of energy (wind,
solar, coal, nuclear, fuel oil, diesel oil, natural gas used in thermoelectrics, and others). The regulatory
framework of the electric energy market in Brazil comprises two trading environments: the Free Marketing
Environment (ACL) and the Regulated Marketing Environment (ACR).
Hydroelectric power plants output is dependent on the annual level of rainfall. When rainfall is abundant,
Brazilian hydroelectric power plants generate more electricity. As a result, under these circumstances, there
is less demand for power generation by thermoelectric power plants.
We generate and sell electric power from a generator complex consisting of 13 thermoelectric power plants
that we own or lease, operating under the authorization regime as an independent power producer. They
are powered by natural gas or diesel, with a total installed capacity of 4,910 MW. These plants are designed
to be dispatched by the ONS whenever necessary, in order to supplement power from the hydroelectric
power plants and, in more recent years, also from wind and photovoltaic solar power plants.
In 2024, the total electricity generated in Brazil, according to the ONS, was 79,116 GWavg. Our
thermoelectric power plants contributed 751 MWavg (612 MWavg in 2023 and 859 MWavg in 2022). This
increase in total generated electricity was due to a growing demand from the system related to peak load.
In addition, we hold participation in other projects of power generation representing 82 MW in our electricity
generation capacity.
We also have some investments in renewable power generation sources in Brazil. We own a solar power pilot
plant, Alto do Rodrigues Photovoltaic Unit with 1 MW of solar capacity.
SALES AND GENERATION OF ELECTRICITY(1)
2024
2023
2022
Electricity sales (ACL) – average MW(2)
888
1,515
1,099
Electricity sales (ACR) – average MW
1,109
1,655
2,053
Electricity generation – average MW
751
612
859
(1) The generation value in the table above includes only the plants where we manage the operation.
(2) Includes electricity sales from the Gas & Low Carbon Energies segment to other operating segments. Service and other revenues from electricity companies.
Annual Report and Form 20-F 2024 I 137
Our Business
Electricity sales and commitments for future generation capacity
Under Brazil’s power pricing regime, a thermoelectric power plant is only allowed to sell electricity
that is certified by the MME and that corresponds to a fraction of its installed capacity. The
certificate is granted to ensure a constant sale of commercial capacity over the course of years to
each power plant, given its role within Brazil’s system to supplement hydroelectricity power
during periods of unfavorable rainfall. The amount of certified capacity for each power plant is
determined by its expected capacity to generate energy over time.
The total capacity certified by the MME (garantia física) may be sold through long-term contracts
in auctions to power distribution companies (standby availability), and through bilateral
contracts executed with free customers and used to meet the energy needs of our own facilities.
In exchange for selling this certified capacity, the thermoelectric power plants must produce
energy whenever requested by ONS. In addition to a capacity payment, thermoelectric power
plants also receive a reimbursement for variable costs (declared to MME to calculate commercial
certified capacity) incurred whenever they are requested to generate electricity.
In 2024, the commercial capacity certified by MME for all thermoelectric power plants we control
was 3,341 MWavg. Our total generating capacity was 4,910 MWavg. Of the total 4,123 MWavg of
commercial capacity available for sale in 2024, approximately 27% was sold as standby availability
in public auctions in the regulated market (compared to 35% in 2023) and approximately 22% was
committed under bilateral contracts and self-production, i.e. sales to related parties, (compared
to 32% in 2023).7
Under the terms of standby availability contracts, we receive a fixed amount whether or not we
generate any power. Additionally, whenever we have to deliver energy under these contracts, we
receive an additional payment for the energy delivered that is set on the auction date and is
revised monthly or annually, based on inflation-adjusted international fuel price indexes.
The table below shows the evolution of our installed thermoelectric power plants’ capacity, our
purchases in the free market and the associated certificated commercial capacity.
INSTALLED POWER CAPACITY AND UTILIZATION
18F
2024
2023
2022
Installed capacity (MW)
4,910
5,313
5,313
Certified commercial capacity (MWavg)
3,341
3,218
3,206
Purchases in the free market (MWavg)
782
1,447
873
Commercial capacity available (Lastro) (MWavg)
4,123
4,665
4,079
The table below shows the allocation of our sales volume between our customers and our revenues for
each of the past three years:
Annual Report and Form 20-F 2024 I 138
Our Business
ELECTRICITY SOLD
2024
2023
2022
Total sale commitments (MWavg)
1,997
3,170
3,152
Bilateral contracts
581
1,219
771
Internal consumption
307
296
328
Public auctions to distribution companies
1,109
1,655
2,053
Generation volume (MWavg)
751
612
859
Revenues (US$ million)(1)
1,427
1,652
1,870
(1)
Includes electricity sales revenues from the Power segment to other operating segments, service and other revenues from electricity
companies.
Our power assets and their respective locations are listed in the table below.
OUR POWER ASSETS (1)(2) (MW)
Type(3)
Region
Power Plant
Fuel(3)
Installed
Capacity
Shareholding or
PIE
Petrobras
Capacity
Partners
Assets under Petrobras Management
(own, lease or controlled)
1
UTE
Southeast/
Midwest
Ibirité
NG
235
100%
235
-
2
Baixada
Fluminense
NG
530
100%
530
-
3
Seropédica
NG/DO
360
100%
360
-
4
Cubatão
NG
249.9
100%
249.9
-
5
Nova
Piratininga
NG
386
100%
386
-
6
Termorio
NG
989.2
100%
989.2
-
7
Juiz de Fora
NG/ET
87
100%
87
-
8
Três Lagoas
NG
386
100%
386
-
9
Termomacaé
NG
922.6
100%
922.6
-
10
South
Canoas
DO/NG
248.6
100%
248.6
-
11
Northeast
Termobahia
NG
186
100%
186
-
12
Vale do
Açu(4)
NG
110
100%
110
-
13
Termoceará
NG/DO
220
100%
220
-
Petrobras Management
4,910
100%
4,910
14
PV
Northeast
Solar Alto do
Rodrigues
1
100%
1
-
Subtotal Petrobras Management
4,911
4,911
Annual Report and Form 20-F 2024 I 139
Our Business
Type(2)
Region
Power
Plant
Fuel(2)
Installed
Capacity
Shareholding
or PIE
Petrobras
Capacity
Partners
Petrobras Shareholdings
1
UTE
Northeast
Suape II
FO
381
20%
76
Savana SPE
Incorporação Ltda.: 80%;
Petrobras: 20%
2
Termocabo
FO
50
12%
6
Brasympe Energia S.A.:
60% (Petrobras has 20%
of shareholding at
Brasympe); EBRASIL
S.A.: 24%; SZF
Participações Ltda: 14%;
OZ&M Incorporação
Participação Ltda: 2%
Subtotal Petrobras Shareholdings
431
82
TOTAL
5,342
4,993
(1)
Assets as of December 31, 2024.
(2)
The Termocamaçari plant, powered by natural gas and with an installed capacity of 120MW, is leased to Proquigel Química until August 2030. The
Piratininga Power Plant had its lease agreement terminated on April 27, 2024.
(3)
NG—Natural Gas; FO—Fuel Oil; DO—Diesel Oil; ET—Ethanol; PIE—Independent Power Producer; UTE—Thermoelectric Power Plant; PCH—Small
Hydroelectric Plant; PV—Photovoltaic.
(4)
In July 2024, ANEEL authorized the reduction of the installed capacity of UTE Vale do Açu from 323 MW to 110 MW. This decrease occurred due to the
restriction in the gas supply, caused by the cessation of our operations at the Pecém LNG Regasification Terminal, limiting the power plant to operate
below its nominal capacity.
Contracts of our thermoelectric power plant in the ACR and their respective contracted power and contract
expiration date are listed in the table below.
OUR CONTRACTS IN THE REGULATED MARKETING ENVIRONMENT
Region
Power plant
Contracted
power
(MWavg)
Contract expiration date
Southeast /Midwest
Baixada Fluminense
416.4
2033
Cubatão
141.0
98.3
64.2
2024
2025 to 2039
2026 to 2040
Termorio
352.0
2024
Termomacaé
200.0
2025
Contracts of capacity reserve of our thermoelectric power plants and contract length are listed in the table
below.
Annual Report and Form 20-F 2024 I 140
Our Business
OUR CONTRACTS OF CAPACITY RESERVE
Region
Power plant
Contracted
available power
(MWavg)
Contract length
Southeast/Midwest
Termorio
922.35
July 2026 to June 2041
Ibirité
197.87
July 2026 to June 2041
Low Carbon Energies24F
26FIn 2024, our Natural Gas & Low Carbon Energies value proposition is to operate in a competitive and
integrated manner in the operation and commercialization of gas and energy, optimizing the portfolio and
promoting the inclusion of renewable sources as well as to operate in low carbon business, diversifying the
portfolio in a profitable way and promoting our sustainability.
We expect to expand our operations in low carbon business, with focus specially on:
_ Bioproducts: to operate preferentially in partnership with large companies in production and
commercialization of low carbon fuels and products, including the chains of ethanol, biodiesel, and
biogas, aiming to meet market demands while developing actions for adequate access to raw
materials.
_ Low carbon emission hydrogen: to operate in the production of low carbon emission hydrogen and
its derivatives, focusing on the decarbonization of our operations, products, and business
development to meet market demand.
_ Renewable generation: to operate preferentially in partnership with large companies in the sector,
aiming for the decarbonization of our operations, integration of the low carbon solutions portfolio,
and capturing market opportunities in Brazil.
_ CCUS: decarbonization of our operations in an integrated manner with the company’s assets, while
providing services to third parties seeking profitability.
For more information, please refer to section “Strategic Plan 2050 and Business Plan 2025-2029”.
In 2024, we signed 33 non-binding legal instruments in the renewable energy sector, with companies and
governments in Brazil, Denmark, China and Argentina, as we aim to work together with major players to
jointly evaluate opportunities. If these opportunities prove to be viable and attractive for all parties, we can
finalize binding agreements and investments in line with our objectives of promoting energy transition as
well as profitability, mainly with large companies in the energy generation and biofuels segments.
Some of these non-binding legal instruments include Memorandums of Understanding (MoUs) and
Protocols of Intent signed with companies and governments to explore new technologies, business
opportunities and partnerships in decarbonization, low-carbon fuels, hydrogen, carbon capture and storage
(CCUS), renewable energy and energy transition. With these cooperation agreements legal instruments, we
intend to leverage the implementation of an e-methanol plant in Pernambuco, evaluate commercial
opportunities in decarbonization and low-carbon fuel projects in Brazil and study the feasibility of a pilot
project in offshore wind energy in the State of Rio Grande do Norte and Rio de Janeiro.
In addition, we also aim to foster innovation by jointly developing a 7 megawatt (MW) onshore wind turbine
with WEG, a Brazilian global electronics company, the first of this size to be built in Brazil. We expect series
production of this equipment to begin in 2025. We invest US$21 million in the project in 2023 and 2024, and
we expect to apport approximately US$6 million in 2025 and 2026. The agreement covers the development
Annual Report and Form 20-F 2024 I 141
Our Business
of technologies to produce wind turbine components, suitable for Brazilian wind conditions, as well as the
construction and testing of a prototype, with technical and commercial counterparts for us.
27FThe agreements signed are non-binding, and in order to monitor the progress of the studies and
discussions, committees will be formed with representatives from each company. The agreements are
aligned with the strategic elements of Strategic Plan, which aim to prepare us for a more sustainable future,
contributing to the success of the energy transition. Only after the necessary technical analyses have been
completed can potential projects arising from the signed agreements have official cost, time and return
estimates. These estimates will allow the potential project to be assessed by internal approval bodies in the
future, in accordance with our governance and always giving preference to an option merger or acquisition
over the own development of projects.28F
Biofuels29
BioRefino
We have a biorefining program known as the BioRefino 2030, launched in 2020, with the purpose of
transforming our refining processes into a more sustainable industry, in line with a low carbon based
economy. In 2022, our projects for the generation of new, modern and sustainable fuels, such as
renewable diesel and biojet, were expanded and gained an even higher priority starting a new phase of
the BioRefino Program. In 2023, the modifications in infrastructure of RPBC, REDUC and REPLAN
refineries allowed the expansion of the Diesel-R production capabilities. Other projects concerning
coprocessing in hydrotreating units are still waiting for the development of a more demanding
voluntary market, since it was not included in mandates for Hydrotreated Vegetable Oil (HVO) by the
recently approved regulatory framework (also known as “Combustível do Futuro”).
Diesel with a renewable content (Diesel-R) is partially composed of an advanced biofuel, produced
from coprocessing conventional diesel with vegetable oils using our proprietary HBIO™ technology.
The renewable part of resulting fuel (HVO) presents the same structure as conventional diesel fuel
and reduces the emission of greenhouse gases compared to mineral diesel oil. Coprocessed diesel with
a renewable content, as well as pure HVO, are free from contaminants and do not cause any damage
to engines, effectively increasing vehicle life and reducing transportation costs.
Commercialization of Diesel R, our lower carbon intensity product that contains HVO, is focused on
clients who want to meet their voluntary ESG goals.
ONGOING PROJECTS
BioQav (also known as SAF or BioJet fuel) is expected to be used worldwide to reduce the emissions of
greenhouse gases in the aviation sector. This was determined by the International Civil Aviation
Organization (“ICAO”) and will be mandatory in Brazil in 2027. The production process for BioQav,
through hydrogenation, uses the same raw materials required for the production of HVO, which is also
formed as a coproduct of the same process. On top of coprocessing units, two dedicated plants for the
production of SAF and/or HVO are on the way with Hydroprocessed Esters and Fatty Acids (the
“HEFA”) technology.
An additional unit is being studied to produce SAF using ATJ (alcohol-to-jet) technology and ethanol
as raw material, to take advantage of our strategic position in the logistics and commercialization of
ethanol. Possibilities of partnership with other companies well positioned in the ethanol chain and/or
SAF market are also being considered.
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In order to comply with ICAO requirements in terms of avoided CO2 emissions while dedicated units
are not in operation (2027-2029), a coprocessing unit totally dedicated to produce Biojet is being
studied at the REPLAN refinery.
100% RENEWABLE FEEDSTOCK PROCESSING IN A FLUID CATALYTIC CRACKING UNIT (FCC)
We and Riograndense Oil Refinery (“RPR”) have achieved a historic milestone by processing, for the
first time, 100% soybean oil in an industrial refining unit. The technology, developed at the Research,
Development and Innovation Center of Petrobras (the “CENPES”), allows us to convert 100%
renewable feedstock, with innovations in process and catalyst, generating fully renewable products
(petrochemical and fuels). This processing of 100% renewable feedstock in a Fluid Catalytic Cracking
Unit (the “FCC”) is the first of its kind in the world.
The test was made possible by a cooperation agreement signed in May 2023 between the RPR
shareholders companies (Petrobras, Braskem and Ultra), which provided the use of the refinery’s units
for testing technologies developed by CENPES. The investment in the test was made in accordance
with the PD&I clauses of the ANP.
We also operate in the production of biodiesel through our wholly owned subsidiary PBIO, which manages
our activities for the production, logistics and marketing of these products.
In November 2024, our Executive Board approved the discontinuation of the divestment process of the
wholly-owned subsidiary Petrobras Biocombustível S.A. (“PBio”). PBio will remain in our portfolio, in line
with our current strategic guidelines, which takes into account our low-carbon businesses, profitable
portfolio diversification, and ensuring operational continuity. Additionally, in alignment with our Strategic
Plan, we continue evaluating alternatives and business models for PBio, to be develop through partnerships
aimed at enhancing our operations, considering new business opportunities, potential synergies between
our assets, and the maximization of the results of Petrobras and its investees.
PBIO has three biodiesel plants for its own operations. However, the Quixadá biodiesel plant has been
inoperative since November 2016. Our biodiesel production capacity in the other two plants in operation is
8.63 mbbl/d. In 2024, we supplied 1.9% of Brazil’s biodiesel demand, according to the ANP.
CNPE is responsible for setting the mandatory blend of biodiesel in all diesel sold in Brazil. In March 2024,
the mandatory blend increased from 12% to 14%.
Main Assets
2024
2023
2022
Biofuels (1)
Biodiesel production units - PBIO
3
3
3
Biodiesel production capacity (mbbl/d) - PBIO
10.5
10.5
10.5
(1) Includes the capacity of Quixadá biodiesel plant, which has been inoperative since November 2016.
Annual Report and Form 20-F 2024 I 143
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Customers and Competitors3F
Natural gas is marketed to 55 clients, most of which are distributors. The entire demand for natural gas
includes our non-thermoelectric, thermoelectric, refining and fertilizer markets, as well as the consumption
by natural-gas carriers contracted by us for the provision of transportation services.
GAS CLIENTS
34F (% vol)
NON-THERMOELECTRIC
THERMOELECTRIC
MARKET (% vol)
MARKET (% vol)
In the commercialization of natural gas, we act as importers and domestic producers who can directly sell
our product to distributors, free consumers, or thermoelectric plants. In 2024 competition intensified, with
new contracts between producers and clients, as expected due to the regulation which improved the
regulatory framework of the natural gas sector and established guidelines for the open market.
The transportation of natural gas consists of a monopoly of the Brazilian federal government and may be
exercised upon concession or authorization by companies incorporated under Brazilian law, with
headquarters and administration in the country.
In the power segment, we operate in generation and sale. In generation, we compete with third-party
thermoelectric plants, as well as other generators with other energy sources (hydro, wind, solar). In terms
of commercialization, we compete with other energy marketers and operate in the regulated market (power
distributors) and free market (marketers and free consumers/large consumers). We have 140 clients and
suppliers, of which 31 are distributors, 30 are marketing companies, ten are generating companies and 69
are free consumers. All contracts are registered at the Electricity Trading Chamber, a sector agent
responsible for the settlement and accounting of these contracts.
Annual Report and Form 20-F 2024 I 144
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Mergers and Acquisitions
We implement our Mergers and Acquisitions (“M&A”) strategy with the goal of identifying, analyzing and
executing strategic opportunities. This approach aims to enhance market share in segments where we
operate, establish operations in new segments (including those related to the energy transition), and
generate value through integration and synergies.
Our M&A strategy covers acquisitions, partnerships and divestments processes. We consider opportunities
aligned with our Strategic Plan and Business Plan drivers, mainly regarding our long-term sustainability,
profitability, and capital discipline.
The governance for approving an M&A project observes robust governance standards that seek to align
public administration principles with best market practices, comprising the following stages:
_ identification of strategic opportunities and inclusion of the project in our portfolio;
_ non-binding stage;
_ binding stage; and
_ negotiation and signature.
Approval from our Executive Board is required for each project to progress through each of the stages
above. The approval of the Board of Directors is also necessary for binding stage and signatures.
In 2024, we have disclosed, signed and completed the following projects:
_ on April 25, 2024, we entered into a definitive agreement to transfer our entire interest held in the
Cherne and Bagre fields, located in the shallow waters in the Campos basin, state of Rio de Janeiro,
for a total amount of US$10 million. Completion of the sale is contingent upon customary regulatory
approvals.
_ on May 29, 2024, we competed the transfer of our entire interest (30%) held in Brentech Energia S.A.,
for a total amount of US$2 million.
_ on July 1, 2024, we competed the transfer of our entire interest (18.8%) held in UEG Araucária
(UEGA), for a total amount of US$13.5 million.
_ on November 27, 2024, we released a teaser for the transfer of our interest in one field in the
Sergipe-Alagoas Basin.
Annual Report and Form 20-F 2024 I 145
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Agreements with CADE
In 2019 we signed with CADE two important Terms of Cessation Commitments (“TCC”), one for the
refining and another for the gas market.
REFINING MARKET AGREEMENT
The TCC for the Refining Market (the “TCC Refino”) provided, among other commitments, the
mandatory divestment of eight refineries (REPAR, RNEST, REGAP, REFAP, RLAM, REMAN, LUBNOR and
SIX). These commitments were aligned with the guidelines of the Executive Board at that time and
National Energy Policy Council (CNPE) Resolution 09/2019, then in force, which established guidelines
for promoting free competition in refining activities in Brazil.
Petrobras had been complying with the commitments agreed in TCC Refino, including the sale of its
entire equity stakes in three invested companies (SIX, RLAM and REMAN), but faced obstacles during
the execution of the divestment processes which prevented the company from concluding the sale of
the remaining refineries within the scope of the TCC.
According to the Material Fact disclosed on March 29, 2023, upon receipt of Official Letters
166/2023/GM-MME, 257/2023/GM-MME and 261/2023/GM-MME from the Ministry of Mines and
Energy, the company’s Board of Directors understood the need to assess the Ministry’s requests to
review if the investments and divestments processes should be carried out based on the company’s
new Strategic Plan proposed by the newly elected Executive Board.
Subsequently, Resolution CNPE 05/2023 was published, which consolidated the end of the guidelines
related to the divestment of the assets, in addition to Petrobras’ 2024-2028+ Strategic Plan, which
had among its objectives to act in a competitive and safe manner, maximizing capturing value by
adapting and improving the refining park and developing new products aimed at a low carbon market.
Therefore, the terms of the TCC were reviewed to adapt it to the new market reality and regulatory
environment.
The amendment was signed on July 3, 2024, and results from extensive debates between the technical
areas of both Petrobras and CADE culminated in the cessation of the obligation to sell RNEST, REPAR,
REFAP, REGAP and LUBNOR, within the scope of the TCC, and established new commitments,
summarized as follows:
_ new behavioral obligations to provide CADE with mechanisms for monitoring, within a controlled
environment, data related to Petrobras’ commercial activities in the oil products and petroleum (crude
oil) market, in the domestic territory, thus allowing it to verify the non-discriminatory nature of prices
charged by Petrobras;
_ obligation of disclosure, by Petrobras, of general, non-discriminatory commercial guidelines for
deliveries of oil, by sea, to any independent refinery in the Brazilian territory; and
_ the offering of Frame Contracts to any independent refinery, in the Brazilian territory, for deliveries
by sea.
The new obligations also foresee the conclusion of investigations initiated after the signing of the TCC.
Annual Report and Form 20-F 2024 I 146
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The obligations agreed in the Addendum to TCC Refino are valid for three years and can be extended
for the same period, at CADE’s sole discretion.
As a result, the Executive Board of Petrobras removed REPAR, RNEST, REGAP, REFAP and LUBNOR
from the divestment portfolio.
GAS MARKET AGREEMENT
The TCC for the Gas Market (the “TCC Gas”) provided, among other commitments, the mandatory
divestment of its entire equity stake in the companies Nova Transportadora do Sudeste S/A (NTS),
Transportadora Associada de Gás S.A. - TAG, Transportadora Brasileira Gasoduto Bolivia-Brasil S.A -
TBG, as well as its indirect equity stake in Petrobras Gás S.A. - GASPETRO.
Petrobras had been complying with the commitments agreed in TCC Gas, which was only pending the
sale of company TBG, a divestment that faced obstacles during its execution.
According to the Material Fact disclosed on March 29, 2023, upon receipt of Official Letters
166/2023/GM-MME, 257/2023/GM-MME and 261/2023/GM-MME from the Ministry of Mines and
Energy, the company’s Board of Directors understood the need to assess the Ministry’s requests to
review if the investments and divestments processes should be carried out based on the company’s
new Strategic Plan proposed by the newly elected Executive Board.
Since the signing of TCC Gas, significant economic, legal and regulatory changes have occurred in the
domestic natural gas market to justify the need for Petrobras to re-assess the business model of the
projects to be divested in the Natural Gas segment.
The New Gas Law, which came into effect after the TCC was signed, exempts companies that were
already vertically integrated prior to its enactment, which applies to TBG, from the obligation to de-
verticalize, so long as these companies comply with the independence and autonomy requirements to
be regulated by the ANP. Therefore, considering the de-verticalization of TBG is not required to meet
the objectives of TCC Gas, and that its divestment would not be aligned with the 2024-28+ Strategic
Plan, the company negotiated with CADE behavioral obligations that ensure TBG’s commercial
independence thus eliminating any concerns regarding the preservation of competitiveness in the
Brazilian natural gas market.
The amendment was signed on July 3, 2024, and results from extensive debates between the technical
areas of both Petrobras and CADE culminated in the cessation of the obligation to sell TBG, within the
scope of the TCC, and established new commitments, summarized as follows:
_ adoption of additional safeguards for the election process of independent members to TBG’s Board
of Directors.
_ adoption of relevant independence (de facto) of TBG's Commercial Board in relation to Petrobras,
removing any possible influence by Petrobras as its majority shareholder.
The terms agreed in the Amendment to TCC Gas will be valid until ANP issues a certificate of
independence for TBG, or until March 4, 2039 (the deadline established in article 5, paragraph 4, of the
New Gas Law, whichever comes first.
As a result, the Executive Board of Petrobras removed TBG from the divestment portfolio.
Annual Report and Form 20-F 2024 I 147
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External Business Environment
We are subject to external variables that can impact the performance of our business and the way we plan
for the future.
Global Economy
In 2024, the global economy demonstrated resilience despite facing significant challenges such as
geopolitical conflicts, extreme weather events, and disruptions in supply chains. Global GDP growth is
projected to be stable at 3.2%, with advanced economies experiencing a modest growth of 1.7% and
emerging markets growing at a faster pace of 4.2%. Inflation rates have been declining, with global headline
inflation expected to fall from 6.7% in 2023 to 5.7% in 2024.
However, the main risks facing the global economy include elevated geopolitical tensions, particularly if
conflicts in the Middle East intensify, which could disrupt oil supplies and raise global inflation. Rising trade
tensions and protectionism may also disrupt supply chains, increase consumer prices, and negatively
impact growth. Additionally, high public debt levels pose a risk, especially for emerging market economies
and low-income countries already in debt distress. Financial vulnerabilities persist due to high debt levels,
stretched asset valuations, and deteriorating credit quality of some borrowers.
Furthermore, climate-related shocks and extreme weather events could lead to economic disruptions and
inflation spikes. Lastly, there is a risk of financial market volatility and potential turbulence in capital flows
or exchange rates in emerging-market economies. Overall, while the global economy has shown strength, it
continues to navigate through a complex landscape of uncertainties.
GDP GROWTH – IMF ESTIMATES (% YoY)
Annual Report and Form 20-F 2024 I 148
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Global Oil & Gas Market
The average Brent price recorded a slight decline in the first quarter of 2024 compared to the previous
quarter. However, the trend observed throughout the first quarter of 2024 was one of price recovery, which
started the period at its minimum quotation in the quarter, at $77/bbl, and ended the quarter above
$85/bbl.
The movement was influenced by increased geopolitical tensions in the Middle East, where attacks by
Houthi rebels from Yemen affected shipping traffic in the Red Sea while in Europe Russian refineries were
targeted by incursions of Ukrainian drones.
In addition, the decision by OPEC+ to extend its voluntary cuts of 2.2 million barrels per day until the end of
the second quarter of 2024, along with signs of more resilient global demand, also contributed to
supporting prices.
However, the recovery trajectory was limited throughout the first quarter of 2024 by concerns about the
dynamics of the global economy, particularly regarding a slowdown in Chinese economic growth and the
maintenance of high interest rates in the U.S. and the European Union.
Brent price started the second quarter of 2024 upward, following the Israeli attack on the Iranian embassy
in Syria, which heightened fears of an escalation of hostilities in the Middle East. After reaching its peak
during the period, Brent fell back as geopolitical issues cooled down and concerns regarding the Chinese
and U.S. economies and the potential impacts on demand.
In early June, OPEC+ announced an extension of approximately 3.7 million barrels per day in production cuts
until December 2025. However, the surprising decision to gradually reduce a total of 2.2 million barrels per
day in voluntary cuts intensified the decline of Brent. This movement was interrupted after statements
from Saudi Arabia indicated that the supply return policy could be reconsidered.
The end of the second quarter of 2024 was marked by an increase in geopolitical tensions (Israel-Hamas,
Russia-Ukraine, conflicts in the Red Sea), the beginning of the hurricane season in the Atlantic, and signs of
rising demand with the beginning of summer in the Northern Hemisphere, which contributed to the price
recovery trajectory.
Brent declined in the third quarter of 2024, both year-on-year and quarter-on-quarter. Concerns about the
dynamics of the global economy, particularly regarding China, negatively influenced prices.
Brent started in the third quarter of 2024 on a high level due to the passage of Hurricane Beryl in the U.S.
and geopolitical tensions in the Middle East. However, the movement lost momentum in the face of signs
of weakness in Chinese oil demand, resulting in a drop in prices.
In early August, the increase in geopolitical tensions in the Middle East and Eastern Europe, along with the
partial disruption of production in Libya, contributed to a recovery in prices.
Starting in the second half of the third quarter of 2024, demand returned to the forefront, with the
worsening economic situation in China leading the IEA and OPEC to cut their projections for global oil
consumption growth for 2024. The decision by OPEC+ to postpone the gradual return of its supply to
December 2024 and the greater optimism regarding the U.S. economy, following an announcement of an
interest rate cut, were not sufficient to counterbalance the decline.
At the end of the third quarter of 2024, the announcement of economic stimulus measures by the Chinese
government and the escalation of hostilities between Israel and Hezbollah in Lebanon contributed to a
slight recovery in prices.
Brent also declined in the fourth quarter of 2024, closing the year with an average of US$80.8/bbl, a decline
of 2% compared to the US$82.6/bbl average of 2023. In the last quarter, concerns over the economy and
demand continued to influence prices, while geopolitical tensions, although still present, were not sufficient
to support them.
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The last quarter of 2024 started with an upward trend due to fears of a possible attack on Iranian oil and
gas infrastructure by Israeli forces. However, this trend was halted by the progress in negotiation talks
between Israel and Hezbollah, along with the return of Libyan production and worries regarding the
dynamics of the Chinese economy.
In the U.S., Donald Trump’s election raised concerns about the potential effects on the market from an
increase in sanctions on Iran and Venezuela, as well as the impact of his tariff policies and trade disputes on
oil demand.
At the end of the fourth quarter of 2024, expectations for the announcement of economic stimulus
measures by the Chinese government and increasing geopolitical tensions in the Middle East and Eastern
Europe contributed to a slight recovery in prices.
Considering signs of a weakened market, with analysts indicating the possibility of an oversupply in the first
quarter of 2025, OPEC+ postponed the gradual return of its production twice during the period. According
to the latest schedule, this return will begin in March 2025, but at a slower pace than originally planned.
BRENT – DAILY CRUDE OIL PRICE (US$/bbl)
Source: Bloomberg, 2024
The Russia-Ukraine conflict, which has reduced Russian gas exports, has exerted intense pressure on the
LNG market, affecting gas prices not only in Europe, but throughout the world. After reaching record levels
in natural gas prices in Europe and on the LNG spot market in Asia in 2022, prices have been lower since
2023, although they remain at historically high levels. The relief in prices was a result of a sharp reduction
in demand, driven by market response to high prices and milder temperatures in the winter of 2022-2023
and 2023-2024. Despite prices returning to levels more aligned with historical trends, the global LNG
balance remained highly pressured in 2024.
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Brazilian Economy
According to the Brazilian Institute for Geography and Statistics (IBGE), the Brazilian economy grew by 3.4%
in 2024. The rate was more than double the expected growth at the beginning of the year, which was around
1.5%. Most of the growth came from the utilities and information technology industries. Agriculture
declined 3.2%, while industry and services grew 3.3% and 3.7% each. Investments were higher than
anticipated, growing by 7.3%. Exports were on the rise, growing 2.9%, but imports also grew (by 14.7%)
closing the pre-existent trade surplus. This is an effect of the growth of household consumption (+4.8%).
Regarding inflation, 2024 was marked by an acceleration in the pace of price increases at the end of the
year. The main reasons were the rise in consumption coupled with the growth of imports and the
depreciation of the exchange rate. As a result, after ending 2023 with consumer inflation measured by the
IPCA at 4.62%, in 2024 the price expansion of prices was 4.83% (compared to an expectation of 3.9% at the
start of the year), staying above the policy target of 1.50% - 4.50%. The interest rates have already started
to increase, and this is expected to continue through, at least, the first semester of 2025.
Finally, the trajectory of the Brazilian exchange rate registered strong depreciation, taking the Brazilian
currency from an exchange rate of approximately R$/US$4.91 in January 2024 to R$/US$6.09 in December
2024 (monthly averages). The average exchange rate in 2024 was R$/US$5.39, representing a depreciation
of 7.9% compared to the 2023 average of R$/US$5.00.
Brazilian Oil and Gas Market
Despite the recovery, the cumulative effect of the rise in commodity prices, the disruption of supply chains
caused by the COVID-19 pandemic and the global energy crisis exacerbated by the Russian invasion of
Ukraine are still having repercussions on fuel markets.
In 2024, despite the reinstatement of federal and state tax at the beginning of the year and an increase in
ethanol supply, the downward trend in international oil and gasoline prices impacted the Brazilian market
and sustained demand growth on a year-over-year basis. Concerning diesel demand, the National Council
for Energy Policies raised biodiesel mandates to 14% in 2024 and announced a 1% increase each year in
order to reach the 20% mandate in 2030, resulting in diesel demand being roughly stable year-over-year.
Jet fuel demand has been firmly ramping up in a post COVID-19 environment and with Brazilian income and
jobs also rebounding but yet to recover to 2019 levels. Therefore, diesel and jet fuel demand rose 1.0% and
6.8% respectively year over year, However, gasoline demand declined 4.0%, reflecting the competitiveness
of ethanol throughout 2024.
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CONSUMPTION OF SELECTED FUELS IN BRAZIL (mbbl/d)
Source: Petrobras and EPE, 2024
According to the Ministry of Mines and Energy, natural gas demand inter-annual data year-to-date until
September 2024 has increased by 3%, from an average of 61.2 million cmd in 2023 to 63.1 million cmd (does
not include the gas used in the pipeline transport).
Regarding natural gas consumption in power generation, in 2023, until November, Brazil experienced higher
rainfall levels compared to the average of recent years. However, in December 2023 the trend reversed,
leading to drier conditions. Although the reservoirs are not in a situation as critical as they were in some
years of the last decade, natural gas power plants were dispatched in 2024 to meet both energy and capacity
demands. The 3% increase in natural gas demand is due to higher consumption for power generation.
On the other hand, the natural gas demand in the industrial and automotive sectors have decreased mainly
due to substitution for biomass, biogas and ethanol.
Emissions Trading Worldwide
As countries increasingly set net zero targets for carbon emissions to comply with the Paris Agreement,
there is a growing recognition among governments on the need to implement policies that promote the
decarbonization of the economy and reduce greenhouse gas (GHG) emissions. One such policy instrument
is the implementation of a regulated carbon market system based on the cap-and-trade concept. This
system sets a limit (a cap) on GHG emissions that can be emitted by each entity and allows entities to trade
licenses equivalent to one ton of GHG in the market.
There is an increasing global trend towards the adoption of carbon pricing instruments. According to the
International Carbon Action Partnership (ICAP) Emissions Trading Worldwide Status Report, 28 carbon
markets were in operation in 2023, covering 17% of greenhouse gas emissions. By 2024, the number of
operating carbon markets had increased to 36, with coverage extending to 18% of GHG emissions.
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The Current State of Carbon Pricing in Brazil
There have been significant advances in the discussion related to the carbon market based on cap-and-
trade concept in Brazil. Draft Bill No. 182/2024, which regulates the carbon market in Brazil through the
introduction of the Brazilian Greenhouse Gas Emissions Trading System (the “SBCE”), was approved by the
National Congress in November and, later, was signed by the President as Law No. 15,042/2024 in
December.
The law provides that the SBCE will be implemented in phases. The first phase establishes that the
regulation of the national carbon market is scheduled to be issued within a period of 12 months, which can
be extended for another 12 months.
This law is an important step forward for Brazil to achieve the commitments made in the Paris Agreement.
Also, this law is a relevant tool for Brazil to remain competitive in global markets, especially with the entry
into force in 2023 of the carbon customs tax in the European Union, called the Carbon Border Adjustment
Mechanism (CBAM).
Strategic and Business
Plans
Annual Report and Form 20-F 2024 I 154
Strategic and Business
Plans
Strategic Plan 2050 and Business Plan 2025-2029
To reinforce our long-term vision, we have separated our plan this year into two parts: the Strategic Plan
2050, which aims to reflect on the future of the planet and how the company wants to be recognized in 2050;
and the Business Plan 2025-29, with short and medium-term goals, which aim to build the company’s path
to the future based on its strategic positions.
The SP 2050 preserves our vision of being the best diversified and
integrated energy company in value generation, building a more
sustainable world by balancing the focus on oil and gas with
diversification into low-carbon businesses (including petrochemical
products, fertilizers, and biofuels), sustainability, safety, respect for
the environment, and full attention to people.
The Business Plan 2025-29 is also a product of the strategic planning process, unfolded from the SP 2050,
and its main focus is to present the expected results through the selection of the portfolio of projects and
assets and the allocation of CAPEX and OPEX.
According to the International Association of Oil and Gas Producers (IOGP), the industry’s global average
carbon intensity is 17kgCO2/boe. In 2024, the carbon intensity of our operated upstream production
reached 14.8 kgCO2e/boe, lower than the industry average. These conditions make it possible to reconcile
leadership in the Just energy transition with responsible oil and gas exploration in the country, in order to
keep future production levels close to the current ones. Accompanying the transformations in the world,
especially in the energy, digital, social, and environmental segments, we are going through a phase of
changes and new perspectives, aiming to prepare for the energy transition and for a fair, inclusive low-
carbon economy, with changes in energy use patterns, assessing and minimizing social impacts for different
parties including our employees, communities and the entire supply chain.
Our Strategic Plan aims to strengthen and prepare us for the future by initiating a process of integrating
energy sources that are essential toward a fair and sustainable energy transition to a low-carbon business.
We work toward a number of goals such as attention to people, safety and respect for the environment,
perpetuating value for future generations, with a focus on capital discipline and a commitment to keeping
our indebtedness under control.
Annual Report and Form 20-F 2024 I 155
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CAPEX - Capital Expenditure
The CAPEX forecast for the 2025-2029 period totals US$111 billion,
with US$98 billion corresponding to projects under implementation
(“Portfolio under Implementation”) and US$13 billion composed of
projects under assessment (“Portfolio under Evaluation”).
The Portfolio under Evaluation consists of opportunities with a lower degree of maturity and subject to
additional financing studies before the execution begins. The total investment expected for the next five
years is 9% higher than the volume projected in the last Strategic Plan 2024-2028+.
In the five-year period from 2025 to 2029, the company expects to focus its efforts on taking advantage of
these opportunities in the oil and gas market, with a focus on replacing reserves, increasing production with
a lower carbon footprint and expanding the supply of more sustainable and higher quality products in its
portfolio.
CAPEX in the E&P segment represents 69% of the total, followed by RT&M with 18%, G&LCE with 10% and
Corporate with 3%.
Annual Report and Form 20-F 2024 I 156
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CAPEX 2025-2029
Exploration & Production (E&P)
With total investments of US$77.3 billion planned for the five-year period of the Business Plan 2025-29 (5%
higher than in the previous plan), the E&P segment is allocating around 60% to Pre-salt assets,
consolidating a major investment phase in this province and its competitive edge, through better quality oil
production, with lower costs and lower greenhouse gas emissions. At the same time, the company is carrying
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Plans
out major revitalization projects (REVITs), seeking to increase recovery factors in mature fields, especially
in the Campos basin.
These are projects that stand out for their dual resilience (economic and environmental) and high economic
value, making up a portfolio that is viable in scenarios of low oil prices in the long term, with prospective
equilibrium Brent averaging US$28 per barrel and carbon intensity of up to 15 kgCO2e per barrel of oil
equivalent over the five-year period. We also forecast an average Total Cost of Produced Oil, which includes
Lifting Cost, government participation, depreciation and depletion, of US$36.5/boe during this period,
considering government participation according to the average Brent price estimated in the planning
assumption.
PRODUCTION OF OIL, NGL AND NATURAL GAS
We expect that ten new production systems will be implemented by 2029, with state-of-the-art
technologies that allow for greater efficiency and lower emissions, nine of which have already been
contracted. There are also five projects being implemented beyond 2029 and another six projects under
study. We are the operator of all these projects, except for Raia field, which is operated by Equinor.
With our Business Plan 2025-29, we plan to achieve total production of 3.2 million barrels of oil and gas
equivalent per day (boed), including 2.5 million barrels oil per day (bbl/d). To monitor the plan, a margin of
±4% variation is considered in relation to the values forecasted.
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In line with our strategic focus, E&P activities are concentrated on profitable assets. Pre-salt production is
expected to represent 81% of our total production by the end of the five-year period.
To meet the challenges of replenishing reserves, we have increased investments in exploration activities,
totaling a CAPEX of US$7.9 billion in the five-year period (5% higher than the previous plan).
At the same time, the Business Plan 2025-29 also includes projects to increase the availability of gas and a
closer look at mature assets, with the aim of assessing the possibilities for extending the productive life of
the assets and their production systems and, in the last instance, starting decommissioning activities, with
the best sustainability practices in the disposal of assets at the end of their life cycle. The sustainable
disposal of equipment and the abandonment of wells is expected to require expenditure of US$9.9 billion
over the next five years.
Refining, Transportation & Marketing (RT&M)
The Business Plan 2025-29 allocates US$19.6 billion in total investments in the RT&M segment,
representing an increase of 17% compared to the previous plan.
The investments in refining are mainly aimed at increase the capacity of our fleet, expanding the supply of
high-quality products, such as S10 Diesel and lubricants, and low-carbon fuels. These investments also seek
to improve the efficiency of the units by advancing in the decarbonization of operations and increasing
operational availability.
With the projects in the plan’s RT&M portfolio, distillation capacity is expected to increase from 1,813,000
bbl/d to 2,105,000 bbl/d, with emphasis on the RNEST projects, which include the revamp (expansion) of
Train 1 and the completion of Train 2.
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We expect to increase our S10 Diesel production capacity by 290,000 bbl/d in our refining system
considering the projects in the Portfolio under Implementation, and we expect to have our first unit capable
of producing lubricants Group II with a capacity to produce 12,000 bbl/d by 2029. In addition, with projects
in the Portfolio under Evaluation, there is the potential to add 70,000 bbl/d of Diesel S10 production
capacity beyond 2029.
For more information on Lubricants Group II, see “Refining, Transportation & Marketing – Refining” in this
annual report.
Under the BioRefining program, we plan to offer low-carbon products, with lower greenhouse gas (GHG)
emissions, seeking to act as a leader in the energy transition and meeting the growing demand for
renewables. Through the program, we expect to expand our production capacity for R5 Diesel (with 5%
renewable content), via the co-processing route, integrated with the operations of some units in our
refining system.
There are also other projects and studies involving biofuels produced by different technological routes, in
particular dedicated plants for BioQav (also known as SAF or BioJet fuel) and 100% renewable diesel
(Hydrotreated Vegetable Oil or HVO) via the HEFA (Hydroprocessed Esters and Fat Acids) route, as well as
ATJ (Alcohol to Jet) studies, a route for producing SAF by processing ethanol. Biorefining projects are also
being evaluated in partnership with Refinaria Riograndense and Acelen.
The main investments in Marketing and Logistics focus on removing logistical bottlenecks and expanding
operations in strategic markets. Highlights include the initiative to build 16 new cabotage ships and the
implementation of logistics projects to increase our presence in growing markets, such as investments in
the Port of Santos Waterway Terminal and the construction of a new light fuel pipeline to supply the
Midwest.
In addition, there is the resumption of fertilizer activities, with investments totaling US$900 million over the
five-year period in projects such as the resumption of construction of the Nitrogen Fertilizer Unit (UFN-III),
in Três Lagoas (Mato Grosso do Sul), and the reactivation of the Araucária Nitrogenados S.A. (ANSA)
fertilizer plant, in Araucária (Paraná).
In petrochemical activities, studies will be conducted into business opportunities in synergy with refining.
Gas & Low Carbon Energies (G&LCE)
The natural gas and low carbon energies projects are expected to receive total investments of US$11 billion,
maintaining the initiatives outlined in the previous plan. The focus will be on the reliability and availability
of our assets to ensure competitiveness in the operation and commercialization of gas and power, while
also including emissions reduction projects and initiatives to integrate renewable sources.
The Business Plan 2025-29 considers the development of two thermal power plants in the Boaventura
Energy Complex in Itaboraí (Rio de Janeiro), with the implementation of these projects being conditional
upon success in future energy capacity reserve auctions.
Regarding low carbon energies (scope 3), the approved plan considers projects and research, among others,
in the following segments: onshore renewable generation (wind/solar); bioproducts (ethanol, biodiesel, and
biomethane); low-carbon hydrogen; and carbon capture, utilization and storage (CCUS).
Annual Report and Form 20-F 2024 I 160
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ESG - Environmental, Social and Governance
In our Strategic Plan 2050 and Business Plan 2025-29, we reaffirm our ambition of zero fatalities and zero
leakages, in line with our commitment to life and the environment, which are non-negotiable values. We
have integrated ESG elements into a single vision, summarizing our position according to the diagram
below:
This ESG diagram guides planning and stakeholder engagement and is aligned with our strategic elements
and goals. Four key ideas are highlighted: (i) reduce carbon footprint; (ii) protect the environment; (iii) take
care of people; and (iv) act with integrity.
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For each of these key ideas, a set of ESG drivers have been identified to support and guide our actions,
projects, programs, and related commitments.
The goals related to each of the four key ideas of the diagram were consolidated into a single list, aligned
with the concept of integrated ESG:
Annual Report and Form 20-F 2024 I 162
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Plans
The six decarbonization commitments (scopes 1 and 2) proposed in the previous plan are maintained for
the Business Plan 2025-29.
Energy transition
Considering all low-carbon initiatives (scopes 1, 2 and 3), the total investment reaches US$16.3 billion in the
energy transition. In addition to low carbon energy projects, the investment includes projects for
decarbonizing operations and Research & Development (R&D) that involve all business segments.
This amount represents 15% of the total CAPEX for the five-year
period (compared to 11% in the previous plan) and a 42% increase
compared to the previous plan.
In this context, it is important to highlight the focus on profitable projects, prioritizing partnerships to
reduce risk and share learning.
The focus on low-carbon initiatives aims at profitable portfolio diversification, promoting our longevity. In
the case of renewable generation projects, the company will seek to operate preferably in partnership with
large companies in the sector, with the goal of decarbonizing operations, integrating the low-carbon
solutions portfolio, and capturing market opportunities in Brazil. For bioproducts, including the ethanol,
biodiesel and biomethane chains, we will seek to enter into these activities preferably through minority
strategic partnerships or shared control with relevant players in the segment.
Annual Report and Form 20-F 2024 I 163
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Plans
Financing
The Business Plan 2025-29 financeability study resulted in the consolidation of a more efficient capital
structure, with greater flexibility and low leverage in challenging scenarios.
The gross debt limit was revised to US$75 billion in Business Plan 2025-29, with debt converging to US$65
billion, following an analysis of the most appropriate capital structure for the company, which adheres to
minimizing the cost of capital, cash flow risks and efficient cash and liquidity management. The increase in
the debt ceiling considers robust leverage metrics, even in scenarios of low Brent prices, in addition to
providing greater flexibility in relation to the growing relevance of leases in gross debt.
Robust free cash flow allows for solid dividend estimates, projecting US$45-55 billion in ordinary dividends
in the base case, with flexibility for extraordinary payments.
(1) Includes contingent and deferred payments and divestments.
(2) Borrowings, net of amortization.
(3) Total CAPEX.
(4) Includes extraordinary dividends declared on November 21, 2024.
(5) Increases in leasings mainly due to amounts included in operating cash flow and investment cash flow in the previous plan.
Annual Report and Form 20-F 2024 I 164
Strategic and Business
Plans
The main assumptions for financing the Strategic Plan are:
ASSUMPTIONS
2025
2029
Brent (US$/barrel)
83
68
Nominal exchange rate (R$/US$)
5.0
5.1
Diesel Crackspread (US$/barrel)
22
19
Gasolina Crackspread (US$/barrel)
14
12
It should be noted that the Business Plan 2025-29 considers, among the assumptions for financeability: (i)
the generation of cash flow exceeding investments and financial obligations; (ii) minimum cash of US$6
billion; (iii) gross debt reference range of US$55 billion to US$75 billion, with convergence towards the
US$65 billion level; and (iv) and payment of dividends in accordance with the current Shareholder
Remuneration Policy.
In summary, SP 2050 and Business Plan 2025-29 demonstrate our commitment to reconciling oil and gas
exploration and production with leadership in the Just energy transition. We are preparing for the pathways
of this transition with an increase of investments in energy transition and portfolio diversification in a
responsible and profitable way. The SP 2050 outlines the path we expect to follow as a leader in the Just
energy transition, reducing our emissions, maintaining our share in Brazil’s energy supply, and increasing
the role of renewable energies in our portfolio, thereby contributing to the country's energy security. By
mobilizing our resources and our technical capacity, along with partnerships and innovation ecosystems, we
aim to develop solutions that benefit both the company and Brazilian society, generating a multiplier effect
on the economy and the country. We will continue to work with a focus on safety, financial responsibility,
ethics, transparency, and respect for people and the environment, investing in the present to build a
sustainable future, creating jobs, paying taxes, and distributing our gains to society and our shareholders.
Annual Report and Form 20-F 2024 I 165
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Research, Development and Innovation
Investing in technology is fundamental to adding value to our business while building competitive
advantages for our long-term sustainability. Our Research, Development and Innovation Center (CENPES)
is responsible for determining our technological solutions that compose our RD&I project portfolio.
CENPES, one of the largest RD&I centers in the energy sector, aims to develop technologies that are
expected to enable the execution of our Strategic Plan, in addition to being responsible for anticipating
future trends and investing in technological routes. On December 31, 2024, Cenpes had 1,097 employees,
of which 87% were exclusively dedicated to RD&I development.
The definition of which technological solutions to pursue starts at identifying the business areas’ needs and
the deployment of our strategy, complying with the principles of operational efficiency and resource
optimization. To build this portfolio, the potential technological solutions to be developed in RD&I projects
go through a process of valuation and prioritization.
Our main research lines are:
RD&I RESEARCH LINES
Within the topics above, our innovation portfolio includes projects focused on developing technologies for
oil and gas exploration and for energy transition. In 2024, we can highlight:
Annual Report and Form 20-F 2024 I 166
Strategic and Business
Plans
_ Development of technologies that allow investment optimization as well as a reduction in cost and
uncertainty such as: i) new geological model for evaluating the quality of reservoirs in the Pre-Salt
of the Campos and Santos basins; ii) unprecedented evaluation of oil migration in the subsurface
using satellite images, enabling a more comprehensive exploration risk assessment; and iii)
unprecedented use of RAMAN spectroscopy (a method that uses light to detect chemical and
structural information of materials) combined with machine learning techniques, to verify how
organic matter interacts with minerals, porosity and other characteristics in sedimentary rocks.
_ Development and implementation of innovative technologies and practices that contribute to
increased efficiency and operational safety in production development and operation activities.
such as: i) use of Digital Twins for life extension and integrity management of subsea systems; ii)
automation of the calculation of the coating integrity index for offshore platforms, based on the
ALGO 360 project, which uses 360° images of platforms for 3D reconstruction and corrosion
detection in eight classes of structures; and iii) adoption of more efficient inspection techniques
without exposing people to risk, such as using drones for cargo tanks, mini-ROVs for ballast tanks,
and borescopes for sea chests and intakes.
_ Development of new technologies related to energy transition and low-carbon products, such as:
i) the completion of commercial tests for ethanol coprocessing in the RFCC at Capuava Refinery
(RECAP) to produce Renewable Content Refinery Light Hydrocarbons (RLH); ii) the signing of the
contract for the construction of a pilot electrolysis plant at Vale do Açu Power Plant (UTE-VLA), a
strategic milestone for the production of renewable hydrogen through water electrolysis powered
by solar energy; and iii) the start of testing for the 7 MW wind turbine developed in partnership with
WEG, representing a significant step forward in expanding the renewable energy matrix.
Our active portfolio management is carried out efficiently, in order to maximize gains, based on a solid
valuation process, optimizing our resources, accelerating project deliveries, aimed at their fast
implementation and measuring results with innovation indicators that evaluate the success rate of
investments in RD&I.
Mandatory investment in RD&I
Our Bylaws require that at least 0.5% of the paid-in share capital is reserved for research and
development expenses. In addition, the obligation to invest in RD&I is also provisioned in contracts for
the exploration, development and production of oil and/or natural gas signed between the ANP and
oil companies, based on the Petroleum Law (Law No. 9,478/1997) and in the Pre-salt regulatory
framework (Law No. 12,351/2010). The amount of this mandatory investment is determined in
accordance with the contract of each existing legal-regulatory regime. However, investments in the
development and implementation of innovative technologies are not limited to fulfilling this
obligation to invest in RD&I.
For concession contracts, whose production volume involves the payment of a special participation,
the percentage of RD&I mandatory investment is linked to the Gross Revenue of the fields (1%). In
production sharing contracts, the percentage is also levied on the total Gross Revenue (1%). For the
Transfer of Rights contract, the percentage is 0.5% of the value of Gross Revenue from any given
annual production.
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In 2024, we expensed US$789 million in research and development. We are one of the companies, among
the major oil and gas companies, that has invested the most in RD&I over the last few years, according to
Evaluate Energy. We invested US$102 million in RD&I projects related to decarbonization and new energies
solutions. Our patents portfolio covers all our areas of activities. Currently, we have 1,562 patent
applications under review (698 in Brazil and 864 abroad), and 1,270 patent granted (686 in Brazil and 584
abroad), within 48 countries. In 2024, we filed 352 patents: 174 abroad and 178 in Brazil, surpassing, for the
fourth consecutive year, our record for filings in a single year. As we pursue valuable results in research and
development, we are exploring new ways to innovate through disruptive technologies, digital
transformation, and start-up engagement.
Connections for Innovation
Connections for Innovation is our open innovation program, designed to accelerate technological
development and add value to our company. The main objective of the program is to find the best
partners to cooperate and develop, test or commercialize technologies, thus increasing
competitiveness and generating better alignment between our technological initiatives and the
innovation ecosystem. The program has seven different modules, Pre-Commercial Procurement,
Technology Transfer, Startups, Solution Acquisition, Technological Partnerships, Open Lab and
Residents, tailored to support different types of technological partnerships, as well as different
innovation ecosystem actors.
In 2024, the open innovation program surpassed the US$480 million mark in partnerships signed over
the five years of Connections for Innovation. The program has been growing rapidly. In 2024 alone,
more than 300 opportunities were published and over 250 new agreements were signed. This is due
to strategic prioritization, enhanced communication and increased dissemination of the program.
Environment, Social and
Governance
Annual Report and Form 20-F 2024 I 169
Environment, Social and
Governance
Environment
Taking care of people and protecting the environment are two of our ESG goals, and to achieve them, each
year, we maintain a set of initiatives aimed at preventing accidents and preserving life and the environment,
aligned with one of our most important HSE programs, called the "Commitment to Life Program". This
program, comprising projects structured through the critical analysis of HSE management, with reference
to the best market practices, seeks to achieve our ambitions of zero fatalities and zero leaks, strengthening
our actions based on the principles of our HSE Policy:
_ HSE is value
_ Respect for Life
_ Risk-based management
_ Business sustainability
_ Excellence and Transparency in Performance
The main initiatives of the program for 2024 were the following:
Annual Report and Form 20-F 2024 I 170
Environment, Social and
Governance
HSE INVESTMENTS (US$ billion)
Our business development with suppliers also contains environmental requirements according to the best
practices in the industry. Contracted companies must present evidence and certifications related to
compliance with HSE standards and confirm that they comply with all applicable requirements, laws,
regulations and ESG best practices, according to new commitments formalized in 2024.
Since 2019, we have held the “Enterprise Certification for Sustainability Standards” granted by ASCM
(Association for Supply Chain Management). This certification recognizes the implementation of
sustainable practices and efficient management in the supply chain, with an emphasis on integrating
responsible processes throughout the entire value chain. Aligned with these principles, we have been
continuously investing in the development of synchronization solutions for our MRO (Maintenance, Repair,
and Operations) materials supply chain. Such initiatives are applied across all business areas of the
company — Exploration and Production (E&P), Refining, Natural Gas Processing Units, and Thermoelectric
Plants — with the aim of ensuring the requested service levels while reducing cash immobilization and CO2
emissions, thereby contributing to a more sustainable and efficient business model.
Total Recordable Injury Rate
Taking care of people is one of our’ values. Our goal is to operate within the best global safety standards.
One of our top metrics is the Total Recordable Injury Rate (the “TRIR”) below 0.7.
Within an evolutionary and continuous improvement process, Petrobras’ TRIR – which until 2015 was above
2.0 – has, in the last three years, been consolidating close to 0.7. The historical series demonstrates that the
Oil and Gas industry, together with Petrobras, has been reducing these rates in recent decades, having
achieved the best historical result, in the 2020 – 2021 biennium, during the period of the COVID-19
pandemic. With the full resumption of activities in 2022, a return to 2019 levels can be seen, not only at
Petrobras but throughout the industry. We monitor critical process indicators monthly in its critical analysis
meetings, notably its top metrics such as TRIR.
Our HSE investments are directed
towards our operations, reduction
of emissions and waste from
industrial
processes,
management
of
water
and
effluent use, repair of impacted
areas, implementation of new
environmental
technologies,
modernization of our pipelines
and improvement of our capacity
to
prevent
and
respond
to
emergencies.
In
addition,
we
support
several
socioenvironmental projects.
Annual Report and Form 20-F 2024 I 171
Environment, Social and
Governance
In 2024, we achieved a TRIR of 0.67, representing a 16% reduction from 2023 (0.80), also below the 2021-
2023 average (0.71). In accordance with the existing management mechanisms, we have implemented
initiatives to enhance our safety standards. A critical analysis of the TRIR enables us to develop strategic
actions for 2025, focusing on reducing severe incidents, in line with the ambition of ZERO Fatalities.
TOTAL RECORDABLE INJURY RATE – TRIR
Although we develop prevention programs in all of our operating units, unfortunately we recorded four
fatalities involving contractors’ employees in 2024 (compared to two fatalities in 2023). Our procedure is to
investigate all incidents reported in order to identify their causes and take preventative and corrective
actions. These actions are regularly monitored once they are adopted. In case of serious accidents, we send
company-wide alerts to enable other operating units to assess the probability of similar events occurring
in their own operations.
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Environment, Social and
Governance
Environmental impacts
MAIN IMPACTS
In 2024, we expensed US$897 million in environmental projects, compared to US$1,072 million in 2023 and
US$810 million in 2022. These environmental projects continue to primarily include actions directed at
reducing emissions and waste from industrial processes, managing effluents, promoting rational use and
reuse of water, managing risks and impacts on biodiversity, remediating contaminated areas, recovering
degraded areas, implementing new environmental technologies, modernizing pipelines and improving
emergency response capacity and safety of our operations.
For more information on our ESG strategy and goals, see “Strategic Plan 2050 and Business Plan 2025-2029”
in this annual report.
Spills and Environmental Remediation Plans
We are constantly seeking to improve our standards, procedures and oil spills response plans, which are
structured at the local, regional and corporate levels.
In 2024, we substantially reduced the volume of relevant oil and oil product spills, experiencing 12 spills
greater than one barrel, which led our VAZO Indicator to reach a value of 14 m³, which represents a reduction
of 18% compared to the 2023 result 17 m³. The causes of the events were analyzed, and the lessons were
incorporated into our processes. Our 2024 result is expressively lower than the average of the results of our
Peer Group in 2023(1) of 534 m³.
(1) Data on spills consulted in sustainability or similar reports published by companies that make up our peer group (BP, Chevron, Shell, Total, Exxon Mobil and
Equinor).
Annual Report and Form 20-F 2024 I 173
Environment, Social and
Governance
As part of our environmental plans, procedures and efforts, we maintain detailed response and remediation
contingency plans to be implemented in the event of an oil spill or leak from our offshore operations. The
IBAMA audits, approves and authorizes the execution of these programs. In order to respond to these
events, we have dedicated oil spill recovery vessels fully equipped for oil spill control and firefighting.
We also have the structure of environmental defense centers, located in strategic areas to ensure rapid and
coordinated response in case of onshore or offshore oil spills. These centers have additional support and
recovery boats available to fight offshore oil spills and leaks, containment booms, absorbent booms and oil
dispersants, among other resources.
We have approximately 290 trained workers available to respond to oil spills 24 hours a day, seven days a
week, and we can mobilize additional trained workers for shoreline cleanups on short notice from a large
group of trained environmental agents in the country. While these workers are located in Brazil, they are
also available to respond to an offshore oil spill outside of Brazil.
Since 2012, we have been a member of the OSRL, an international organization that brings together over
164 corporations, including major, national and independent oil companies, energy related companies as
well as other companies operating elsewhere in the oil supply chain. OSRL participates in the Global
Response Network, an organization composed of several other companies dedicated to fighting oil spills.
As a member of the OSRL, we have access to all resources available through that network, and also subscribe
to their Subsea Well Intervention Services, which provide swift international deployment of response-ready
capping and containment equipment. The capping equipment is stored and maintained at bases worldwide,
including Brazil.
In 2024, we conducted 16 emergency drills of high complexity, and thousands of drills of low and medium
complexity.
We continue to evaluate and develop initiatives to address HSE concerns and to reduce our exposure to HSE
risks on capital projects and operations.
Air Emissions and Transition to Low Carbon
Our actions related to climate change are supported by three pillars:
1
2
3
Transparency and Carbon
Management
Oil and Gas Competitiveness
Low-carbon Businesses,
Scope 3 and Just
Transition
Governance in information,
processes and decisions
Robustness and Value of the fossil
portfolio in the face of transition
Portfolio Exposure to
Carbon
Our Governance is focused on risk
management of climate change and
energy transition and is structured in
such a way that these issues are
addressed at all levels of the company,
including senior management.
In our understanding, companies will
become more competitive in the long-term
market the more they can produce at low
costs and with lower GHG emissions,
thriving in scenarios of low oil prices, carbon
pricing, and possible oil differentiation
practices based on the GHG emissions
intensity in production.
We acknowledge that the Paris
Agreement’s
goals
require
significant reductions in GHG
emissions
and
changes
in
energy supply. Our scenarios
point to an unequivocal energy
transition, albeit at an uncertain
pace.
Annual Report and Form 20-F 2024 I 174
Environment, Social and
Governance
We strive to ensure that risks and
opportunities of climate change are
adequately captured in our scenarios,
quantified, and considered in our
choices, seeking business sustainability
and value creation for all stakeholders.
The variable compensation of all
company’s
employees
incorporates
performance linked to carbon intensity
commitments
in
our
operations,
promoting employee engagement in
achieving expected results.
We follow the recommendations of
TCFD for climate-related disclosures,
promoting carbon transparency for all
stakeholders.
Our inventory has been published
voluntarily since 2002 and verified
annually by a third party since 2003,
representing our pioneering spirit in
GHG management.
We aim to maintain our operations on a
decreasing emissions trajectory with lower
carbon intensity than other companies,
safeguarding the competitiveness of our oil
in world markets in a scenario of slowdown
and subsequent contraction in demand.
We focus on continuing to supply oil and gas
in a competitive and environmentally
manner, to meet persistent demand for oil
compatible with the goals of the Paris
Agreement.
We believe that balancing a
focus on oil and gas activities
with portfolio diversification
into low-carbon businesses is
the most effective path for a
Just transition.
All our projects must be profitable in our scenario which provides an accelerated energy transition with a
significant reduction in the price of fossil fuels, assuming a value of crude oil of US$45 per barrel in the long
term.
As described in the “Strategic Plan 2050 and Business Plan 2025-2029” section of this report, we outline the
same six commitments related to carbon emissions found in our previous plan.
Our ambitions associated with reducing the carbon footprint include the pursuit of operational emissions
neutrality by 2050, achieving the "Near Zero Methane 2030" ambition aligned with best industry practices,
and achieving an operational emissions net neutral growth by 2030, maintaining 2022 emission levels (a
40% reduction since 2015), while simultaneously considering the increase in production and activities
planned in the Business Plan 2025-29.
We are committed to continuing to improve the GHG emissions efficiency of our E&P activities.
In oil and gas projects, fields naturally mature over time, leading to a progressive increase in water
production and energy demand, as well as a decline in oil production rates. Consequently, as productions
rates decline, there is a natural tendency for the intensity of E&P activities to increase over time. To
minimize this increase, we implement measures to (i) optimize energy use and reduce losses in existing
operations; (ii) incorporate low-carbon technologies into new projects; and (iii) study and implement
disruptive long-term decarbonization solutions. For more information on our ESG commitments and
investments in decarbonization, see the “Strategic Plan 2050 and Business Plan 2025-2029” section of this
report.
Annual Report and Form 20-F 2024 I 175
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Governance
In 2024, our performance in terms of GHG emissions was as follows:
_ Total GHG emissions of 47 million tCO2e, about 2% higher than the previous year, but lower than the
achieved in the years of 2022 to 2015;
_ Carbon intensity in E&P of 14.8 kgCO2e/boe(1), below the 15 kgCO2e/boe commitment to be achieved
by 2025;
_ Carbon intensity in Refining of 36.2 kgCO2e/CWT(2), the lowest historical outcome; and
_ Methane intensity in E&P of 0.20 tCH4/mil tHC, a reduction of 0.02 tCH4/mil tHC compared to 2023.
(1) The kg CO2e / boe indicator considers gross oil and gas production (wellhead) in its denominator.
(2) The kg CO2e/CWT indicator uses the CWT (Complexity Weighted Tone) methodology, developed by Solomon Associates and CONCAWE (Conservation of Clean
Air and Water in Europe – the association of European oil refining and distribution companies and gas) specifically for the European oil refining industry, and was
adopted by the European Emissions Trading System (EU Emissions Trading System, EU ETS) in setting the sector’s GHG reduction targets. The CWT (Complexity
Weighted Tonne) considers both the effect of processed cargo and the complexity of each refinery, allowing for the comparison of GHG emission potential
between refineries with different profiles and sizes.
The drivers for the GHG emissions results in 2024 were the gain of efficiency and loss reduction actions
implemented in the operational segments, which helped mitigate the increase in emissions resulting from
the commissioning of new assets.
Our carbon intensity targets (E&P and Refining) represented a coverage of 84% of emissions from activities
we operated in 2024.
We’ve been expanding our offering of low carbon products. In 2024, we achieved the milestone of 100,000
m3 of sales of Diesel R with renewable content (R5), preventing the emission of approximately 10,000 tons
of CO2. We also recorded a 27% increase in Podium Carbon Neutral Gasoline sales compared to 2023, with
225,000 tons of CO2 neutralized by carbon credits.
In 2024, we entered into an agreement with Gerdau to foster low-carbon business studies, explore
commercial opportunities and a potential partnership aligned with both companies’ diversification and
decarbonization strategies.
We collaborate with climate development initiatives and continue to partner with other companies and the
science, technology and innovation community. We highlight, for instance, our participation in the Oil & Gas
Climate Initiative, our support for the World Bank’s “Zero Routine Flaring by 2030” initiative, which is one of
our sustainability commitments, and our adherence to the Oil & Gas Methane Partnership 2.0 (OGMP) and
the Oil & Gas Decarbonization Charter, an initiative launched in COP28.
In addition, we note that our Climate Change Supplement is available on our website at
www.petrobras.com.br/ir, which details our contributions to reducing the carbon intensity of our energy
supply and how we aim to remain competitive in an evolving context.
Annual Report and Form 20-F 2024 I 176
Environment, Social and
Governance
Social Responsibility
Human Rights
Corporate commitments and initiatives
A commitment to human rights is key to the sustainability of our business. Several documents and
initiatives in the countries where we operate drive our approach to human rights, as follows:
_ Code of Ethical Conduct: addresses issues such as respect for diversity, equal opportunities, fair
labor relations and human rights protection, health and safety assurance for workers and the right
to free association.
_ Ethical Conduct Guide for Suppliers: reinforces that our suppliers must promote dignified and safe
working conditions for their employees and fight against child and slave labor, in addition to
promoting diversity, gender and racial equality as well as the inclusion of people with disabilities.
_ Human Rights Guidelines: direct our actions, as far as respect for human rights is concerned, in all
the activities and regions where we operate and throughout the life cycle of our projects and
operations. Our human rights operations follow the United Nations’ Guiding Principles on Business
and human rights and are structured along four axes: People Management, Community Relations,
Engagement with Supplier and Partner Chain, and Due Diligence in Human Rights. Each axis
describes the processes through which we aim to ensure the incorporation of respect for human
rights in all areas of our business and in our relations with our stakeholders, as well as the
identification of potential risks in terms of human rights violations related to operations, products
or services we provide, in addition to remedying any impacts we cause.
_ Diversity, Equity, and Inclusion Policy: a set of principles and guidelines that support and drive the
decision-making process and guide behaviors in relation to diversity, equity and inclusion.
_ Protective Intelligence and Corporate Security Policy: according to our policy, the protective
intelligence and corporate security actions are carried as per the legislation in force and the respect
of human rights, in compliance with external and internal legal requirements, and with relevant
recommendations and technical standards.
_ Human Resources Policy: states that we must provide employees with a good working environment
that promotes diversity and relationships based on trust and respect, without tolerating any form
of harassment or discrimination.
_ Social Responsibility Policy: seeks to prevent and mitigate negative impacts on our direct activities,
supply chain and partnerships. It is based on our respect for human rights and seeks to fight against
discrimination in all its forms, setting forth standards related to social risk management, community
relations and social investment present in the guidelines related to these subjects.
_ Preventing and Combating Discrimination, Moral Harassment, and Sexual Violence Guideline:
provides the steps for the company to prevent and to combat discrimination, moral harassment, and
sexual violence everywhere it operates throughout the cycle of its projects, operations, and
professional relationships.
_ Technical Cooperation Agreement on Human Rights: we entered into a Technical Cooperation
Agreement on Human Rights with the Ministry of Human Rights and Citizenship. The document is
composed of about twenty actions that reinforce human rights policies not only in the company, but
in the entire Brazilian society.
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_ General Ombudsman’s Office: we provide direct contact channels for registering queries and
complaints, such as Contact Us and an institutional email directed to the social responsibility teams
that serve the business units. Regarding complaints from communities present in the coverage area,
records are made via customer service (SAC) and the General Ombudsman’s Office.
_ Safety, Health and Environmental Policies: to reduce risks to human health and the environment,
our operations have action plans and emergency drills, and our workforce undergoes frequent
training courses. In addition, we sponsor a series of environmental projects aimed at mitigating
carbon emissions, protecting endangered environments and species, and conserving biodiversity.
_ Human Rights Governance: in January 2021, we established the Petrobras Human Rights
Commission, which is responsible for managing, in an integrated, broad and comprehensive manner
across the business, the implementation of the human rights agenda established by the Petrobras
Human Rights Guidelines.
_ Guidelines for Removal and Resettlement of Communities: to manage and mitigate the possible
impact of resettlement processes, we have established a corporate approach that covers all of our
units. In this approach, we define guidelines for the removal and resettlement of individuals or
communities affected by our projects and/or activities.
_ Communication and Relationship Policy: we are committed to establishing relationships with our
stakeholders based on respect, transparency, trust and integrity. We communicate in a transparent,
truthful, timely and consistent manner with our values and strategies.
_ Guideline for Relationship with Indigenous Peoples and Traditional Communities: launched in
2024, it reinforces the respect for the rights of indigenous peoples and traditional communities, in
particular: the right to self-determination; the right to their lands, independent of the status of
official recognition; the right to use and handling of land and natural resources; and the right to
cultural identity, including their different ways of social organization and their principles and cultural
values.
Our commitments to respecting and advocating for human rights are also evident through initiatives, in the
countries where we operate, in favor of gender equity, racial equality, and the protection of early childhood,
for example. We highlight below our commitment to some of the main human rights initiatives, to which we
adhere:
_ United Nations Global Compact
_ Pact for Diversity, Equity and Inclusion of Federal State-Owned Enterprises
_ Companies and LGBTI+ Rights Forum
_ Permanent Committee on Gender, Race, and Other Diversities of the Ministry of Mines and Energy
and Affiliated Entities.
_ Women’s Empowerment Principle
_ National Compact for the Eradication of Slave Labor – InPacto
_ Enterprise Racial Equality Initiative
_ Open Letter Enterprises for Human Rights
_ Gender and Race Pro-Equity Program, of the federal government
_ Corporate Statement Against Sexual Exploitation of Children and Adolescents
_ Early Childhood National Network
_ Brazil without Misogyny Initiative
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_ Zero Feminicide Initiative
Our Human Rights Commission, established in 2021, is responsible for implementing the human rights
agenda set by our Human Rights Guidelines, ensuring that this agenda is broadly and cross-sectionally
integrated into our business in the countries where we operate. The commission is made up of 35 of our
executive management areas, nine general management areas and two subsidiaries (Transpetro and PBIO)
and 110 members, previously appointed by the respective executive manager, and it is divided into three
sub-commissions:
_ Human Rights Training
_ Diversity, Equity and Inclusion
_ Human Rights Due Diligence
We have a Human Rights action plan, reviewed in 2024, with 59 actions to be developed by 2026. Our action
plan is periodically monitored by the Board of Directors’ HSE committee.
Also in 2024, our Human Rights Commission underwent a review of its governing rules and improved the
representation of the company’s areas and subsidiaries that make up the group and their respective
members.
Aimed at strengthening our internal human rights structure, we have a team dedicated to managing the
human rights process within the company, ensuring the incorporation of respect for human rights
throughout the company, including in our relationships with stakeholders, as well as its broad and cross-
sectional integration into the company’s business. It has the following strategic objectives:
_ coordinate Petrobras’ Human Rights Commission
_ guide the development of human rights commitments and requirements in the supply chain
_ coordinate the management of social risk management in the entire lifecycle of projects and
operations
_ manage the implementation of human rights due diligence in operations
_ coordinate strategies for the protection and promotion of the rights of vulnerable groups and
traditional peoples in Petrobras’ practices, processes, and strategic projects
_ strengthen the culture of respect for human rights within the company
_ coordinate strategies relating to the respect for human rights in the fair energy transition
These actions align with our goal of building increasingly better, fairer, more diverse and innovative working
environments and improving our management of the human rights process, ensuring that respect for
human rights is incorporated into all areas and into relations with our stakeholders, as well as its broad and
cross-cutting integration into our business.
In this sense, since May 2024, we have signed thirty technological cooperation terms with diversity clauses,
with public and private universities, trying to reach at least 20% of women, Black people and persons with
disabilities participation in research project teams in STEM (Science, Technology, Engineering and Maths)
areas.
Since 2022, we have carried out training initiatives related to human rights. In 2024, the remote training
Human Rights and Business – A Look at Petrobras, provided training aimed at employees about human
rights and their importance for society and the strategic planning of companies, in addition to addressing
how we have been advancing in actions that aim to respect these rights in the development of all our
activities. This same training has been adapted to service providers and companies in which we hold direct
or indirect shareholdings and will continue to be applied in 2025.
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Also, in 2023, we launched an e-learning course “Preventing and Combating Discrimination, Moral
Harassment and Sexual Violence”. The training provides definitions and reflections on the various types of
violence in the workplace, as well as information about the mechanisms the company has in place to address
cases of discrimination, harassment, and sexual violence. Additionally, the training offers guidance on how
to proceed if a worker experiences or has knowledge of such an occurrence.
In 2024, our entire leadership team was trained in racial equity, with renowned experts speaking with our
managers, from the Board and the Executive Board to entry-level management positions across the
company.
HUMAN RIGHTS DUE DILIGENCE PILOT PROJECT
In 2024, we continued the pilot project of the implementation of human rights integrated due diligence in
Petrobras, a process that is based on the guidelines of the UN Guiding Principles, published in 2011. The
project is being implemented in five operations, as a pilot in partnership with an external specialized
consultancy.
The first phase of the pilot project included the Henrique Lage Refinery (Revap), in São Paulo; the Bacia de
Campos Operations Unit (UO-BC), in Rio de Janeiro; and LUBNOR, in the state of Ceará. The second phase
took place in the Bacia do Espírito Santo Operations Unit (UO-ES), in Espírito Santo, and in the Gas Pipeline
Project Rota 2, in Rio de Janeiro. The pilot project provided learning experiences and essential inputs for
the development of execution standards that will help us in future applications of human rights due
diligence in our operations.
Starting in 2025, the project will be extended to achieve the Strategic Plan goal of carrying out human rights
due diligence in 100% of our own E&P and Refining Operations.
Corporate programs
PETROBRAS PROGRAM AGAINST SEXUAL AND WORK VIOLENCE
In 2024, the Petrobras Program against Sexual Violence incorporated other forms of workplace violence,
and the name was changed to “Petrobras Program against Sexual and Workplace Violence”. Now, the
program centralizes and monitors the implementation of ongoing or planned actions to combat sexual and
workplace violence, in order to provide a diverse, respectful and safe work environment free from any kind
of violence.
CORPORATE MENTORING PROGRAMS FOR WOMEN AND BLACK PEOPLE
In 2024, we continued to successfully implement programs within our workforce in Brazil. We completed the
third edition of the Women’s Leadership Mentoring Program, aimed at empowering more women to step
into leadership roles. This edition provided opportunities for 60 mentor-mentee pairs within our company,
with a particular focus on operational areas. The program seeks to expand and strengthen female
representation across different sectors of our business, fostering a supportive environment where
participants can develop essential skills, exchange knowledge, and build lasting professional networks.
In July 2024, the Petrobras Negritudes Mentoring Program was launched, an initiative aimed at the
development of black leaders, both men and women, currently in leadership positions as well as those
aspiring to such roles in the future. The program involves the participation of 40 pairs of mentors and
mentees, including people with disabilities (PWDs), and aims to accelerate the professional growth of the
mentees by providing meetings with mentors and a customized training pathway.
Annual Report and Form 20-F 2024 I 180
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RACIAL EQUITY PROGRAM
Prepared by a working group composed of Black colleagues representing various corporate departments,
our racial equity program in Brazil aims to promote racial equity, and to build a more diverse, discrimination-
free and welcoming work environment. One of its main goals is already detailed in the Strategic Plan, which
provides for a target of 25% Black people in leadership by 2029.
Human rights in our supply chain
We are committed to ensuring that all our relevant suppliers are properly trained in integrity and/or privacy,
in addition to conducting Human Rights Due Diligence for all relevant suppliers by 2030. To reinforce our
commitment to the topic of human rights, in October 2023, the themes of Human Rights and Personal Data
Protection were incorporated into the Integrity Due Diligence Questionnaire. The information collected on
these topics is being used for preventive measures within our supply chain.
To mitigate the risk of degrading labor in our supply chain, our standard contractual template includes
provisions requiring compliance with the labor regulations established by the current Brazilian legislation.
Non-compliance with this clause grants us the right to terminate the contract with the supplier.
Furthermore, our contracts include provisions prohibiting the use of child labor or labor analogous to
slavery in all activities in connection with the execution of the contract. This requirement is also included in
the Ethical Conduct Guide for Suppliers, which extends this commitment to the subcontractors of our
suppliers.
Additionally, starting in 2024, we began to include the Human Rights Clause in service contracts, as a result
of a collaborative effort by several areas of the company and based on strategic premises, such as
strengthening diversity and preventing risks related to human rights.
Community Relationship
We are committed to maintaining a long-term relationship with communities based on dialogue and
transparency. To achieve this, we seek to understand the dynamics of the communities that neighbor the
sites where we operate and to develop relationship plans that are constantly monitored and assessed.
We foster collaborations to strengthen ties, promote networking, and generate mutual benefits while
respecting the social, environmental, territorial, and cultural rights of communities. We promote
committees, meetings, lectures, visits and investment in social and environmental programs and projects,
which are in alignment with the objectives of our business and contributes to the conservation of the
environment and the improvement of the living conditions of the communities where we operate.
In 2024, our community relationship activities carried out 953 voluntary community interactions, including
meetings with community leaders through community committees, as well as visits and events. In addition,
we resumed face-to-face activities full time and technology allowed for greater interaction with community
members.
We carry out social risk assessments to identify and mitigate potential detrimental impacts to human rights
within communities or within supply chain activities. These assessments are considered in our decision-
making process with respect to investment projects, and lead to recommendations such as the review of
emergency response plans through the lens of community relationships, monitoring of community
incidents and complaints, disclosure of projects and operational activities, and the inclusion of social
responsibility clauses in service agreements. In 2024, 23 new risk assessments were required to support
projects passing through formal planning procedures.
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Governance
Petrobras Socio-Environmental Program and other contributions
We also strengthened our work with communities, civil society organizations, the public sector and
universities through the Petrobras Socio-Environmental Program. The program is aligned with our social
responsibility policy, which has, as one of its guidelines, the development of enduring socio-environmental
initiatives, in alignment with the Sustainable Development Goals of the United Nations’ 2030 Agenda.
These initiatives aim to promote the development of the different regions improve the quality of life for
communities and contribute to the recovery and conservation of nature. This is done by considering the
expectations of stakeholders and the contribution to our business, with a priority focus on the areas where
we operate.
In 2024, we completed the largest public selection of projects under the Petrobras Socio-Environmental
Program, with an estimated investment of US$82.8 million. The selected environmental projects address
solutions to issues such as marine litter prevention, forest restoration and conservation, and the protection
of endangered species. The social projects will focus on strengthening the child and adolescent rights
guarantee system, dignified professional inclusion, income generation through entrepreneurship, efforts
to overcome homelessness, and strengthening associations, cooperatives, and other collective
organizations. All projects also emphasize promoting environmental justice, combating racism, ensuring
racial equity, and addressing prejudice.
In addition to the Petrobras Socio-Environmental Program, in 2024 we contributed to other socio-
environmental initiatives not covered by the program, such as those highlighted below:
_ we signed a partnership with SESI-SENAI - Serviço Nacional de Aprendizagem Industrial to
implement the “Programa Autonomia e Renda Petrobras”. This initiative aims to qualify individuals
in socioeconomic vulnerability and/or unemployment who live in areas surrounding our operations,
expanding employment opportunities in the oil and gas sector. Nearly 20,000 training opportunities
will be offered across various courses, prioritizing underrepresented groups, including women, black
and brown individuals, transgender people, people with disabilities, indigenous peoples, quilombola
communities, and refugees. Through the program, we seek to contribute to the inclusion of local
labor within our supply chain during maintenance turnarounds at operational units and investment
projects outlined in our Strategic Plan. In the second half of 2024, over 1,100 opportunities were
offered in 17 courses across seven states (ES, MG, PE, PR, RJ, RS, and SP) covered by the program.
_ with the goal of expanding our investments in a more diverse portfolio of projects based on nature-
based solutions, we strengthened our partnership with the Banco Nacional de Desenvolvimento
Econômico e Social (BNDES) through the Floresta Viva matchfunding initiative. This initiative aims
to provide joint financial support of US$21.9 million over a seven-year period for reforestation
projects involving native species in Brazil’s biomes, generating social and environmental benefits.
Managed by the Fundo Brasileiro para a Diversidade (FUNBIO), these funds are being allocated to
projects selected through two calls for proposals: "Manguezais do Brasil" and "Corredores de
Biodiversidade," covering the Cerrado and Pantanal biomes. Altogether, the initiative aims to restore
4,200 hectares through the efforts of supported civil society organizations. In 2024, we signed a
memorandum of understanding with BNDES for joint action in the Restaura Amazônia Program,
under which the parties will invest US$18.6 million over the next five years in reforestation projects
involving native species in the Amazon region.
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Governance
_ we established the Petrobras Bioeconomy Fund, to be managed by Régia Capital, a sustainable
investment platform created by JGP Gestão de Recursos Ltda. and BB Asset. For its launch, we
allocated an initial contribution of US$9.3 million, matched by another US$9.3 million from Régia
Capital. The fund aims to support socioenvironmental projects, transforming them into sustainable
businesses capable of preserving the invested capital and generating income for the communities
involved. The project selection process will focus on fostering the bioeconomy through a sustainable
development model, emphasizing nature-based solutions that promote the restoration and
conservation of Brazil’s biomes. The goal is to mitigate climate change and biodiversity loss while
generating socioenvironmental and economic benefits for local communities, respecting their
territorial, cultural, and self-determination rights. This initiative represents another step toward
expanding and diversifying our voluntary socioenvironmental investments, focusing on scalability
through the potential combination of resources with co-investors, thereby increasing benefits for
local communities and the environment.
_ we launched a joint process with BNDES called Sertão + Produtivo, focused on the selection of 10
social projects for acting in all the states of the Brazilian semi-arid region. The two companies will
jointly invest US$18.6 million in the next five years, in projects that contribute to the strengthening
and structuring of associations and cooperatives of family farmers, production of healthy food and
reduction of food insecurity, further to the income generation for socially vulnerable persons.
We are committed to the development of initiatives that contribute to the solution of social and
environmental problems, generating opportunities for acting together with our stakeholders and
customers. Thus, to increase our contribution to society beyond socioenvironmental projects, in 2024, we
allocated US$5.4 million in financial donations, for emergency actions to support people in socially
vulnerable situations, due to or caused by the climate emergency in the state of Rio Grande do Sul. These
donations were made in accordance with our internal regulations.
Annually, we report on our actions related to sustainability and human rights in the Sustainability Report
and in the Human Rights and Corporate Citizenship Supplement. In our Sustainability Report, we correlate
the indicators and actions reported with the GRI indicators, the Sustainable Development Goals and the
Global Compact Principles. We also use the IPIECA Oil and Gas Industry Guide for Voluntary Reporting as a
complementary
reporting
methodology.
These
reports
are
available
on
our
website
at
www.petrobras.com.br/ir.
Annual Report and Form 20-F 2024 I 183
Environment, Social and
Governance
Corporate Governance
Good corporate governance and compliance practices are a pillar of support for our business. In recent
years, we have made significant advances in our corporate governance and in our integrity, compliance and
internal controls systems. We have also adopted rigorous ethics and integrity standards through initiatives
that reinforce our purpose, values, and commitment to continuous improvement and alignment with good
market practices.
Our corporate governance model has a set of rules and procedures that seek to ensure that our decisions
are aligned with good governance:
OUR MAIN GOVERNANCE PRACTICES
Criteria for selection of members of the Board of Directors and the Executive Officers are set out in our
Bylaws and comply with the conditions imposed by art. 147 of the Brazilian Corporation Law, as well as those
provided for in Law No. 13,303/16, in Decree No. 8,945/16 and our Policy for nomination of Senior
Management Members. Our Bylaws provide that, for appointment to such positions, we will consider both
material and formal conflicts set forth in Law No. 13,303/16.
Law 13,303/16, among other requirements, requires that our Board of Directors be formed by at least 25%
of independent members. Our Bylaws extended the requirement to 40%; however, this provision can be
amended.
Our Board of Directors nominates the chief governance and compliance officer. The majority of the board
must approve the dismissal of such officer, with the vote of a majority of the directors elected by minority
shareholders. As provided for in our Bylaws and in Law No. 13,303/16, the chief governance and compliance
officer is guaranteed, in the exercise of his duties, the possibility of reporting directly to the Board of
Directors.
In addition to the requirements of the Bylaws and current legislation, in accordance with the guidelines of
our Policy for nomination of Senior Management Members, we seek to achieve diversity in the composition
of the Board of Directors and complementarity of experiences and qualifications. The Executive Officers
consists of members with exclusive dedication, and requires at least 10 years of leadership experience,
preferably in the business or in a related area.
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Environment, Social and
Governance
Our nominations process includes the verification of additional integrity criteria, provided for in our Bylaws
and detailed in our Policy for nomination of Senior Management Members, through the Integrity
Background Check (the “BCI”). The BCI is an important decision-making support tool, that respects the
privacy and data access laws that are in force in each country.
As we are a partially state-owned company, the Brazilian federal government can guide our activities, with
the purpose of contributing to the public interest that justified our creation, aiming to guarantee the supply
of oil products throughout the national territory. However, this contribution to the public interest must be
compatible with our corporate purpose and with market conditions and cannot jeopardize our profitability
and financial sustainability.
Thus, if providing for the public interest calls for conditions different from those of any other private sector
company operating in the same market, as explained in our Bylaws, the obligations or responsibilities that
we assume must be defined in rules or regulations and outlined in a specific document, such as a contract
or agreement, widely publicized and with disclosure in such instruments of detailed costs and revenues,
including in the accounting plan. Then, the Brazilian federal government will compensate us, each fiscal
year, for the difference between market conditions and the operating result or economic return of the
assumed obligation.
Transactions with the Brazilian federal government that require our Board of Directors’ approval and occur
outside the normal course of business must have been previously reviewed by the minority committee,
statutory audit committee and approved by two-thirds of the board. The minority committee is formed by
two members of our Board of Directors appointed by minority common shareholders and preferred
shareholders, as well as one independent member, according to our Bylaws. For more information on the
functioning and composition of the statutory audit committee, see “Management and Employees –
Management – Statutory Board Committees” in this annual report.
Regarding our decision-making process, our Bylaws define the board advisory committees that review all
matters submitted to the Board of Directors prior to a decision. Additionally, in order to ensure
transparency in our most relevant decisions, we use a shared authorization model, where at least two people
must come to a decision (the four-eyes principle).
We are part of the special Level 2 corporate governance listing segment of the B3, which demands
compliance with differentiated governance regulation and the improvement of the quality of the
information we provide. This voluntary move to Level 2 of the B3 reinforces our advances in corporate
governance and ratifies our commitment to the continued improvement of processes and to our alignment
with good market practices.
Possible initiatives related to changes for governance improvements require formality and transparency of
process. In most cases, a shareholders’ meeting is required if the proposed change is to a governance rule
provided for in our Bylaws or stems from a legislative amendment if relates to a Law 13,303/16 provision.
For more information on our Whistleblower Channel, Code of Ethical Conduct and Ethical Conduct Guide for
Suppliers, see “Compliance and Internal Controls – Compliance” and “Compliance and Internal Controls –
Ombudsman and Internal Investigations” in this annual report.
Annual Report and Form 20-F 2024 I 185
Environment, Social and
Governance
Corporate Governance Structure
Our corporate governance structure currently consists of a general shareholders’ meeting, our Fiscal
Council, Board of Directors and its committees, audits, general ombudsman office, Executive Officers and
its committees.
GOVERNANCE STRUCTURE
Our Code of Best Practices gathers our main governance policies and aims to improve and strengthen our
governance mechanisms, guiding the performance of our directors, executive officers, managers,
employees and collaborators.
Annual Report and Form 20-F 2024 I 186
Environment, Social and
Governance
Major Recognition
We are members of the Brazilian Institute of Corporate Governance (the “IBGC”), which ratifies our
commitment to the continuous improvement of our processes and internal controls, in alignment with good
corporate governance practices in the market, with the objectives and values defined in our Strategic Plan,
as well as with national and international legislation.
We received, for six years in a row, the certification in the Governance Indicator of the Secretariat for
Coordination and Governance of State-Owned Companies (the “IG-Sest”), achieving their best level, Level
1, which shows our high degree of excellence in corporate governance. There was no evaluation in 2023 and
2024 because IG-Sest is undergoing restructuring and reevaluation of the issues to be evaluated, therefore,
Petrobras continues with the Level 1 obtained in 2022. This certification, besides acknowledging our
advances in recent years, is an opportunity to assess our processes at a new level of quality and reaffirm
our commitment to the continuous improvement of our corporate governance.
In 2024, we reached 96% adherence to the Brazilian Code of Corporate Governance (CBGC). According to the
latest survey released by the IBGC, the degree of adherence of companies in the market averaged 67% in
2024, an increase of 1.7% compared to the previous year (65.3%).
Furthermore, we secured first place among the 19 federal partially state-owned companies assessed in the
IESGo 2024, the new index developed by the Federal Court of Accounts (TCU) to evaluate social,
environmental, and governance practices of federal public organizations. Besides social and environmental
sustainability, the indicator analyzes other ESG-related topics such as governance, leadership, strategy,
people management, budget management, environmental sustainability, and it is aligned with the United
Nations Sustainable Development Goals (SDGs).
Additionally, for the eighth consecutive year, in 2024 we won the National Association of Finance,
Administration, and Accounting Executives (Anefac) award, granted to the Brazilian companies with the
best quality and transparency in their financial statements. The classification is made based on a rigorous
technical analysis of the financial statements published by companies based in Brazil that operate in the
commercial, industrial, and service sectors. Criteria such as transparency, clarity and consistency of
information, adherence to accounting standards, among others, are evaluated.
We believe that the results we have achieved prove the recognition of the market and regulatory and control
entities regarding the improvement of our culture of integrity and of our governance mechanisms. We
believe that a high degree of integrity reinforces our reputation among our stakeholders and, consequently,
within society as a whole.
Shareholders’ Meeting
The shareholders’ meetings must take place on an ordinary or extraordinary basis. An ordinary
shareholders’ meeting must take place once a year in order to: (i) examine the administrators' account,
examine, discuss and vote on the financial statements; (ii) decide on the allocation of net income for the
year and the distribution of dividends; (iii) elect the members of the Fiscal Council; and (iv) if applicable,
elect the members of the Board of Directors. In addition to the matters provided for by law, an extraordinary
shareholders’ meeting must take place if called to decide on matters of our best interest, as defined in our
Bylaws.
For more detailed information on our shareholders’ meetings, see “Shareholder Information” in this annual
report.
Annual Report and Form 20-F 2024 I 187
Environment, Social and
Governance
Comparison of our Corporate Governance Practices with NYSE
Corporate Governance Requirements Applicable to U.S. Companies
Under the rules of the NYSE, foreign private issuers are subject to a more limited set of corporate
governance requirements than U.S. domestic issuers. As a foreign private issuer, we must comply with four
principal NYSE corporate governance rules: (i) we must satisfy the requirements of Rule 10A-3 under the
Exchange Act; (ii) our Chief Executive Officer must promptly notify the NYSE in writing after any executive
officer becomes aware of any material non-compliance with the applicable NYSE corporate governance
rules; (iii) we must provide the NYSE with annual and interim written affirmations as required under the
NYSE corporate governance rules; and (iv) we must provide a brief description of any significant differences
between our corporate governance practices and those followed by U.S. companies under NYSE listing
standards.
The table below briefly describes the significant differences between our corporate governance practices
and the NYSE corporate governance rules.
Section
New York Stock Exchange Corporate
Governance Rules for U.S. Domestic
Issuers
Our Practices
Director Independence
303A.01
Listed companies must have a
majority of independent directors.
“Controlled companies” are not
required to comply with this
requirement.
We are a controlled company because more than a
majority of our voting capital (at least 50% plus one
share) is controlled by the Brazilian federal government.
As a controlled company, we would not be required to
comply with the majority of independent directors
requirement if it were a U.S. domestic issuer. According
to our Bylaws, we are required to have at least 40% of
independent directors.
303A.03
The non-management directors of
each listed company must meet at
regularly scheduled executive
sessions without management.
Except for our CEO (who is also a director), all of our
directors are non-management directors. The regulation
of our Board of Directors provides that if a particular
matter may represent a conflict of interests, the CEO
must recuse himself from the meeting, which will
continue without his presence. Additionally, the board’s
regulation also establishes a regular executive session
for our Board of Directors matters without management.
Nominating/Corporate governance committee
303A.04
Listed companies must have a
nominating/ corporate governance
committee composed entirely of
independent directors, with a written
charter that covers certain minimum
specified duties. “Controlled
companies” are not required to
comply with this requirement.
We have a statutory committee that verifies the
compliance of the appointment of members of our Fiscal
Council, our Executive Officers, and our Board of
Directors and the external members of the committees
that advise our Board of Directors. Our people
committee has a written charter that requires the
majority of its members to be independent.
Our Board of Directors develops, evaluates and approves
corporate governance principles. As a controlled
company, we would not be required to comply with the
nominating/corporate governance committee
requirement if we were a U.S. domestic issuer.
Annual Report and Form 20-F 2024 I 188
Environment, Social and
Governance
Section
New York Stock Exchange Corporate
Governance Rules for U.S. Domestic
Issuers
Our Practices
Compensation committee
303A.05
Listed companies must have a
compensation committee composed
entirely of independent directors, with
a written charter that covers certain
minimum specified duties. “Controlled
companies” are not required to
comply with this requirement.
We have a committee that advises our Board of Directors
with respect to compensation and management
succession. Our people committee has a written charter
that requires the majority of its members to be
independent.
As a controlled company, we are not required to comply
with the compensation committee requirement.
Audit committee
303A.06
303A.07
Generally, listed companies must have
an audit committee with a minimum of
three independent directors that
satisfy the independence
requirements of Rule 10A-3 under the
Exchange Act, with a written charter
that covers certain minimum specified
duties. However, pursuant to
Exchange Act Rule 10A-3(c)(3), a
foreign private issuer is not required
to have an audit committee
equivalent to or comparable with a
U.S. audit committee if the foreign
private issuer has a body established
and selected pursuant to home
country legal or listing provisions
expressly requiring or permitting such
a body, and if the body meets the
requirements that (i) it be separate
from the full board, (ii) its members
not be elected by management, (iii) no
executive officer be a member of the
body, and (iv) home country legal or
listing provisions set forth standards
for the independence of the members
of the body.
Our audit committee is a statutory advisory committee
to our Board of Directors and satisfies the exemption set
forth in Rule 10A-3(c)(3) under the Exchange Act. See
“Management and Employees – Statutory Board
Committees” for a description of our audit committee.
Our audit committee has a written charter that sets forth
its responsibilities that include, among other things: (i)
assess the independent auditor's qualifications and
independence, and the performance of the independent
audit functions, (ii) assuring legal and regulatory
compliance, including with respect to internal controls,
compliance procedures and ethics, and (iii) monitoring
our financial position, especially as to risks, internal
auditing work and financial disclosure; (iv) carry out prior
analysis of transactions with related parties that meet
the criteria established in the Related Party Transactions
Policy, approved by our Board of Directors. In addition,
one of the audit committee members is an external
accounting and auditing expert, who brings valuable
expertise and experience to the committee's work.
Equity Compensation Plans
303A.08
Shareholders must have the
opportunity to vote for compensation
plans through shares and material
reviews, with limited exceptions as set
forth by the NYSE’s rules.
Under Brazilian Corporate Law, shareholder approval is
required for the adoption and revision of any equity
compensation plans. We do not currently have any equity
compensation plans.
Corporate Governance Guidelines
Annual Report and Form 20-F 2024 I 189
Environment, Social and
Governance
Section
New York Stock Exchange Corporate
Governance Rules for U.S. Domestic
Issuers
Our Practices
303A.09
Listed companies must adopt and
disclose corporate governance
guidelines.
We have a set of Corporate Governance Guidelines
(Diretrizes de Governança Corporativa) that address
general ombudsman qualification standards,
responsibilities, composition, appraisals and access to
information by the management. The guidelines do not
reflect the independence requirements set forth in
Sections 303A.01 and 303A.02 of the NYSE rules. Certain
portions of the guidelines, including the responsibilities
and compensation sections, are not discussed with the
same level of detail set forth in the commentaries to the
NYSE rules. The guidelines are available on our website
at www.petrobras.com.br/ir.
We also have a Corporate Governance Policy, approved
by our Board of Directors, which establishes our
governance principles and guidelines. This policy applies
to our company and our affiliates, pursuant to Article 16
of our Bylaws.
Code of Ethics for Directors, Officers and Employees
303A.10
Listed companies must adopt and
disclose a code of business conduct
and ethics for directors, officers and
employees, and promptly disclose any
waivers of the code for directors or
executive officers.
We have a Code of Ethical Conduct (Código de Conduta
Ética), applicable to the members of the Board of
Directors and its advisory committees, members of the
Fiscal Council, members of the Executive Board,
employees, interns, service providers and anyone acting
on our behalf (collaborators), including its subsidiaries in
Brazil and abroad, and a Code of Best Practices (Código
de Boas Práticas) applicable to our directors, executive
officers, senior management, employees and
collaborators. No waivers of the provisions of the Code of
Ethical Conduct or the Code of Best Practices are
permitted. These documents are available on our website
at www.petrobras.com.br/ir.
Certification Requirements
303A.12
Each listed company CEO must certify
to the NYSE each year that he or she is
not aware of any violation by us of
NYSE corporate governance listing
standards.
Our CEO will promptly notify the NYSE in writing if any
executive officer becomes aware of any material
noncompliance with any applicable provisions of the
NYSE corporate governance rules.
Operating and Financial
Review and Prospects
Annual Report and Form 20-F 2024 I 191
Operating and Financial Review and
Prospects
Consolidated Financial Performance
We achieved a net income of US$7,528 million, cash provided by operating activities of US$37,984 million,
a Free Cash Flow (a non-GAAP measure defined in Liquidity and Capital Resources – Free Cash Flow) of
US$23,318 million and an Adjusted EBITDA (a non-GAAP measure defined in Liquidity and Capital Resources
– Adjusted EBITDA and Net Debt/Adjusted EBITDA ratio) of US$40,399 million.
Net income attributable to shareholders was US$7,528 million in 2024, a 69.7% decrease compared to
US$24,884 million in 2023, mainly due to the exchange rate variation of debts between Petrobras and its
overseas subsidiaries, an accounting effect that does not have an impact on our cash position. The exchange
rate variation in these transactions is reflected in the net income of the holding company in Brazil.
Fluctuations in our financial condition and results of operations are driven by a combination of factors,
including:
_ the volume of crude oil, oil products and natural gas we produce and sell;
_ changes in international prices of crude oil and oil products (denominated in U.S. dollars);
_ changes in the domestic prices of oil products (denominated in reais);
_ fluctuations in the real vs. U.S. dollar exchange rates and other currencies, as disclosed in Note
33.4.1(c) to our audited consolidated financial statements;
_ the demand for oil products in Brazil;
_ the recoverable amounts of assets for impairment testing purposes; and
_ the amount of production taxes from our operations that we are required to pay.
Annual Report and Form 20-F 2024 I 192
Operating and Financial Review and
Prospects
CONSOLIDATED STATEMENT OF INCOME INFORMATION (US$ million)
As reported
Jan-Dec
Variation
2024
2023
▲
▲ (%)
Sales revenues
91,416
102,409
(10,993)
(10.7)
Cost of sales
(45,444)
(48,435)
2,991
6.2
Gross profit
45,972
53,974
(8,002)
(14.8)
Selling expenses
(4,874)
(5,038)
164
3.3
General and administrative expenses
(1,845)
(1,594)
(251)
(15.7)
Exploration costs
(913)
(982)
69
7.0
Research and development expenses
(789)
(726)
(63)
(8.7)
Other taxes
(1,251)
(890)
(361)
(40.6)
Impairment of assets, net
(1,531)
(2,680)
1,149
42.9
Other income and expenses, net
(7,893)
(4,031)
(3,862)
(95.8)
Operating Income
26,876
38,033
(11,157)
(29.3)
Net finance expense
(15,107)
(2,333)
(12,774)
(547.5)
Results of equity-accounted investments
(627)
(304)
(323)
(106.3)
Net income before income taxes
11,142
35,396
(24,254)
(68.5)
Income taxes
(3,537)
(10,401)
6,864
66.0
Net income for the year
7,605
24,995
(17,390)
(69.6)
Exchange rate and variation impacts
As we are a Brazilian company and most of our operations are carried out in Brazil, we prepare our
financial statements primarily in reais, which is our functional currency and that of all of our
Brazilian subsidiaries. We also have entities that operate outside Brazil the functional currency of
which is the U.S. dollar. We have selected the U.S. dollar as our presentation currency in this annual
report to facilitate the comparison with other oil and gas companies. We have used criteria set
forth in IAS 21 – “The effects of changes in foreign exchange rates” to translate the consolidated
financial statements from reais into U.S. dollars. Based on IAS 21, we have translated (i) all assets
and liabilities into U.S. dollars at the exchange rate as of the date of the statement of financial
position; (ii) all accounts in the statements of income, other comprehensive income and cash flows
using the average exchange rates prevailing during the relevant period and (iii) equity items at
the exchange rates prevailing at the respective transactions dates.
For more information regarding our functional and presentation currency, see “About Us” and
Note 2.2 to our consolidated financial statements.
Annual Report and Form 20-F 2024 I 193
Operating and Financial Review and
Prospects
EXCHANGE AND INFLATION RATES
2024
2023
2022
Year-end exchange rate (reais/US$)
6.19
4.84
5.22
Appreciation (depreciation) during the year(1)
(27.9%)
7.3%
6.5%
Average exchange rate for the year (reais/US$)
5.39
5.00
5.16
Appreciation (depreciation) during the year(2)
(7.9%)
3.1%
4.3%
IPCA
4.83%
4.62%
5.79%
(1) Based on year-end exchange rate.
(2) Based on average exchange rate for the year.
From January 1, 2025 to April 2, 2025, the real appreciated 8.1% against the U.S. dollar.
Most of our export revenues are denominated in U.S. dollars and our domestic sales are also
indirectly linked to the U.S. dollar due to our current policy to generally seek to maintain parity
with international product price. Therefore, the depreciation of the real is generally favorable to
our operating income as the positive impact in revenues is higher than the negative impact on
operating costs, the majority of which are denominated in Brazilian reais.
On the other hand, the depreciation of the real against the U.S. dollar results in a loss due to the
exchange rate variation of our finance debt.
Exchange rate fluctuations may affect the results of variables such as the following:
_ Margins: The relative pace at which our total revenues and expenses in reais increase or decrease
as a result of exchange rate fluctuations, and its impact on our margins, is affected by our pricing
policy in Brazil. Absent changes in the international prices of crude oil, oil products and natural
gas, when the real appreciates against the U.S. dollar, and we do not adjust our prices in Brazil,
our margins increase. On the other hand, absent changes in the international prices of crude oil,
oil products and natural gas, when the real depreciates against the U.S. dollar and we do not
adjust our prices in Brazil, our margins decline. For further information on our prices and our
pricing policies, see “Sales Volumes and Prices” in this section.
_ Debt service: The depreciation of the real against the U.S. dollar also increases our debt service
expenses in reais, as the amount of reais necessary to pay principal and interest on foreign
currency debt increases with the depreciation of the real. As our debt denominated in other
currencies increases, the negative impact of a depreciation of the real on our results and net
income when expressed in reais also increases, thereby reducing earnings available for
distribution.
_ Retained earnings available for distribution: Exchange rate variation also affects the amount of
retained earnings available for distribution by us when expressed in U.S. dollars. Amounts
reported as available for distribution in our statutory accounting records are calculated in reais
and prepared in accordance with IFRS Accounting Standards. They may increase or decrease
when expressed in U.S. dollars as the real appreciates or depreciates against the U.S. dollar.
We designated hedging relationships to account for the effects of the existing hedge between a
foreign exchange gain or loss from portions of our long-term debt obligations (denominated in
U.S. dollars) and foreign exchange gain or loss of our highly probable U.S. dollar denominated
future export revenues, so that gains or losses associated with the hedged transaction (the highly
Annual Report and Form 20-F 2024 I 194
Operating and Financial Review and
Prospects
probable future exports) and the hedging instrument (debt obligations) are recognized in the
statement of income in the same periods.
For more information about our cash flow hedge, see Notes 4.8 and 33.4.1(a) to our audited
consolidated financial statements.
For information about our related foreign exchange exposure related, see “Liquidity and Capital
Resources – Exposure to interest rate and exchange rate risk” in this section.
For more information about our foreign exchange exposure related to assets and liabilities, see
Note 33.4.1(c) to our audited consolidated financial statements.
Sales Revenues
In 2024, sales revenues decreased by 10.7% compared to 2023, reaching US$91,416 million, due to
decreased sales volume and lower average prices for oil products, following the devaluation of international
prices, and decreased natural gas revenue.
Sales volumes and prices
As a vertically integrated company, we process most of our crude oil production in our refineries
and sell the refined oil products primarily in the Brazilian market. Therefore, the price of oil
products in Brazil has a significant impact on our financial results. International oil product prices
vary over time as the result of many factors, including the price of crude oil. We take into account
domestic market conditions and seek to align the price of oil products with international prices
while avoiding the immediate transfer of volatility of international quotations and the exchange
rate. The average price of Brent Crude Oil, as reported by Bloomberg, was US$80.8 per barrel in
2024, US$83 per barrel in 2023 and US$101 per barrel in 2022. As of December 31, 2024, the Brent
Crude Oil price was US$74.6 per barrel.
Consolidated sales revenues were US$91,416 million in 2024 as compared to US$102,409 million
in 2023, primarily due to:
_ a US$1,141 million decrease in domestic market crude oil revenues, composed of a US$1,016
million decrease which relates to a decrease in sales volumes, and a US$125 million decrease
which relates to a decrease in average crude oil prices in domestic market following the
depreciation of average Brent crude prices; and
_ a US$7,497 million decrease in domestic market oil products revenues, of which US$6,770 million
relates to a decrease in average domestic basic oil products prices following the reduction in
average international prices for diesel and gasoline, and US$727 million relates to a decrease in
sales volumes.
Annual Report and Form 20-F 2024 I 195
Operating and Financial Review and
Prospects
For the year ended December 31
2024
2023
2022
Volume (mbbl,
except as
otherwise
noted)
Net
Average
Price
(US$)(1)
Sales
Revenues
(US$
million)
Volume
(mbbl,
except as
otherwise
noted)
Net
Average
Price
(US$)(1)
Sales
Revenues
(US$
million)
Volume
(mbbl,
except as
otherwise
noted)
Net
Average
Price
(US$)(1)
Sales
Revenues
(US$
million)
Diesel
265,302
103.74
27,522
272,276
118.48
32,260
275,572
145.69
40,149
Automotive
gasoline
146,903
86.40
12,692
152,509
93.82
14,309
148,647
108.81
16,175
Fuel oil
(including
bunker fuel)
10,123
96.41
976
11,949
96.91
1,158
12,239
115.29
1,411
Naphtha
25,612
72.97
1,869
24,997
73.49
1,837
26,692
89.76
2,396
Liquefied
petroleum gas
78,327
40.42
3,166
75,151
46.65
3,506
77,149
66.38
5,121
Jet fuel
40,248
112.25
4,518
37,911
132.28
5,015
35,879
151.15
5,423
Other oil
products
62,733
68.11
4,273
61,607
71.87
4,428
63,717
86.88
5,536
Subtotal oil
products
629,248
87.43
55,016
636,400
98.23
62,513
639,895
119.10
76,211
Natural gas
(boe)
75,344
62.47
4,707
82,536
68.24
5,632
111,270
68.96
7,673
Oil
53,822
80.52
4,334
66,175
82.74
5,475
73,771
104.63
7,719
Ethanol,
nitrogen
products,
renewables and
other non-oil
products
2,476
90.06
223
1,564
60.10
94
1,085
260.83
283
Electricity,
services and
others
—
—
1,995
—
—
2,576
—
—
2,406
Total Brazilian
market
760,890
—
66,275
786,675
—
76,290
826,021
—
94,292
Exports
292,232
82.99
24,251
294,291
84.99
25,012
260,734
105.46
27,497
International
sales
13,561
65.63
890
16,455
67.27
1,107
20,511
130.91
2,685
Total global
market
305,793
0.00
25,141
310,746
—
26,119
281,244
—
30,182
CONSOLIDATED
SALES
REVENUES
1,066,683
0.00
91,416
1,097,421
—
102,409
1,107,265
—
124,474
(1) Net average price calculated by dividing sales revenues by the volume for the year.
Cost of Sales
In 2024, the cost of sales decreased 6.2%, reaching US$45,444 million, mainly due to lower costs with:
_ raw material and products for resale, materials and third-party services;
_ depreciation, depletion and amortization; and
_ production taxes.
Annual Report and Form 20-F 2024 I 196
Operating and Financial Review and
Prospects
General and Administrative Expenses
General and administrative expenses were US$1,845 million in 2024, an increase of 15.7% compared to
US$1,594 million in 2023, mainly reflecting higher employee expenses, resulting from salary increases,
actuarial expenses, and larger expenditure on third-party services, particularly data processing services,
largely related to digital transformation initiatives.
Impairment of assets, net
We recognized impairment in the amount of US$1,531 million in 2024, a US$1,149 million decrease
compared to an impairment loss of US$2,680 million in 2023.
This decrease was mainly in oil and gas producing properties in Brazil (a US$1,129 million impairment in
2024 compared to a US$2,217 million impairment in 2023), primarily due to the revision of abandonment
and area recovery expenses, as well as reduced forecasts in operational efficiency and increased investment
and operational costs, negatively impacting the field's production curves.
There were also impairment losses on the 2nd Train of RNEST amounting to US$421 million, due to
increased investment estimates associated with the Business Plan 2025-29.
Other Taxes
Other taxes were US$1,251 million in 2024, a 40.6% increase (US$361 million) compared to US$890 million
in 2023, mainly due to enrollment to the tax settlement program, which allowed the settlement of
significant legal disputes related to discussions on the incidence of taxes on remittances abroad involving
chartering of vessels or platforms and their respective service contracts. In addition, the 2023 comparative
base was affected by a 9.2% extraordinary reduction in the taxation on exports of crude oil between March
and June 2023, pursuant to Provisional Measure No. 1,163/2023.
Other income and expenses, net
Other income and expenses, net was an expense of US$7,893 million in 2024, a US$3,862 million change
compared to an income of US$4,031 million in 2023, mainly due to:
_ effects of the intermediate remeasurement on the health care plan for retired employees due to the
2023 labor agreement (a US$1,000 million expense); and
_ lower results on disposal/write-offs of assets (a US$228 million income in 2024 compared to a
US$1,295 million income in 2023).
Net Finance Expense
Net finance expense was US$15,107 million in 2024, a 547.5% increase when compared to US$2,333 million
in 2023, mainly due to a foreign exchange loss of US$11,104 million in 2024, as compared to a US$580 million
loss in 2023, reflecting a 27.9% depreciation of the real/US$ exchange rate in 2024 compared to a 7.3%
appreciation in 2023.
Annual Report and Form 20-F 2024 I 197
Operating and Financial Review and
Prospects
Results in equity-accounted investments
We had a loss in equity-accounted investments of US$627 million in 2024, compared to a loss of US$304
million in 2023. This increase was mainly due to losses with Braskem reflecting lower financial results, due
to the depreciation of the Brazilian real in 2024.
Income Taxes
Income tax was an expense of US$3,537 million in 2024, compared to an expense of US$10,401 million in
2023, mainly due to lower Operating Income.
For information regarding discussion of earlier years, please refer to our previous Annual Report and Form
20-F. Our SEC filings are available to the public on the SEC’s website at www.sec.gov and on our website at
www.petrobras.com.br/ir.
Annual Report and Form 20-F 2024 I 198
Operating and Financial Review and
Prospects
Financial Performance by Business Segment
SELECTED FINANCIAL DATA BY REPORTABLE OPERATING SEGMENTS AND FOR CORPORATE AND OTHER
BUSINESS
For the year ended December 31
2024
(US$ million)
2023
(US$ million)
▲ 24-23
(%)
Exploration and Production
Third parties(1)(2)
308
767
(59.8)
Intersegment
60,208
66,113
(8.9)
Sales revenues(2)
60,516
66,880
(9.5)
Cost of sales
(24,823)
(27,239)
8.9
Impairment (losses) reversals, net
(1,244)
(2,105)
40.9
Net income (loss) attributable to our shareholders
18,593
22,453
(17.2)
Refining, Transportation and Marketing
Third parties(1)(2)
84,246
93,464
(9.9)
Intersegment
1,035
1,404
(26.3)
Sales revenues(2)
85,281
94,868
(10.1)
Cost of sales
(78,836)
(85,699)
8.0
Impairment (losses) reversals, net
(300)
(524)
42.7
Net income (loss) attributable to our shareholders
1,324
3,036
(56.4)
Gas and Low Carbon Energies
Third parties(1)(2)
6,549
7,824
(16.3)
Intersegment
2,969
3,285
(9.6)
Sales revenues(2)
9,518
11,109
(14.3)
Cost of sales
(5,031)
(5,685)
11.5
Impairment (losses) reversals, net
-
(81)
100.0
Net income (loss) attributable to our shareholders
682
1,286
(47.0)
Corporate and other Businesses
Third parties(1)(2)
313
354
(11.6)
Intersegment
6
11
(45.5)
Sales revenues(2)
319
365
(12.6)
Net income (loss) attributable to our shareholders
(12,625)
(1,723)
(632.7)
(1) Not all of our segments have significant third-party revenues. For example, our Exploration and Production segment accounts for a large part of our economic
activity and capital expenditures but has little third-party revenues.
(2) Revenues from commercialization of oil to third parties are classified in accordance with the points of sale, which could be either the Exploration and
Production or Refining, Transportation and Marketing segments.
Annual Report and Form 20-F 2024 I 199
Operating and Financial Review and
Prospects
Exploration and Production
Net income attributable to our shareholders in our E&P segment was US$18,593 million in 2024 compared
to US$22,453 million in 2023, primarily due to:
_ reduction in sales revenue due to lower Brent prices and decreased production;
_ higher tax expenses resulting from the adherence to the tax transaction related to taxes on
remittances abroad involving chartering of vessels or platforms and their respective service
contract;
_ lower gains from assets sales; and
_ abandonment and dismantling of areas.
Refining, Transportation and Marketing
Net income attributable to our shareholders in our RTM segment was US$1,324 million in 2024 compared
to US$3,036 million in 2023, primarily due to:
_ lower sales revenues (a decrease of US$9,587 million) mainly in the domestic market due to lower
average prices of oil products, particularly for diesel, gasoline, and jet fuel, largely following the
depreciation of international prices, and lower sales volume of oil products, mainly diesel, due to the
increase in the mandatory blending content of biodiesel in type B diesel fuel and the increase in
imports by third parties originating mainly from Russia, and gasoline, reflecting the recovery of
market share of hydrated ethanol over gasoline C in flex-fuel vehicles. The price effects also had a
negative impact on fuel oil and petroleum export revenue in 2024;
_ lower costs of sales due to the decrease in the average Brent, which impacts the price used to
purchase oil from our E&P segment as well as oil and oil products from third parties, and lower sales
volume;
_ lower sales expenses mainly due to the decrease in volumes sales; and
_ lower impairment losses.
Gas and Low Carbon Energies
In 2024, the net income attributable to our shareholders in our Gas and Low Carbon Energies segment was
US$682 million, a decrease of US$604 million compared to 2023, mainly due to lower volumes and sales
prices of natural gas, impacted by the opening of the market and actions by Petrobras to maintain
competitiveness. The terminations of energy contracts, both from energy auctions (ACR) and direct energy
sales (ACL), also contributed to lower operating profit.
For information regarding discussion of earlier years, please refer to our previous Annual Report and Form
20-F. Our SEC filings are available to the public on the SEC’s website at www.sec.gov and on our website at
www.petrobras.com.br/ir.
Annual Report and Form 20-F 2024 I 200
Operating and Financial Review and
Prospects
Liquidity and Capital Resources
We closely monitor liquidity levels in order to effectively meet cash needs from our business operations and
financial obligations. We have a conservative approach to the management of our liquidity, which consists
mainly of (i) cash and cash equivalents (cash in hand, deposits held at call with banks, money market mutual
funds and other short-term highly liquid investments with maturities of three months or less), and
(ii) investments in financial assets (treasury bills).
Management believes that our current working capital is sufficient for the company's present requirements.
In the event that the company presents a negative net working capital, management believes it does not
compromise the company's liquidity since the company maintains revolving credit facilities contracted as a
liquidity reserve to be used in adverse scenarios (see Note 30.5 to our audited consolidated financial
statements).
Additionally, the company regularly assesses market conditions and may enter into transactions to
repurchase its own securities or those of its subsidiaries, through a variety of means, including tender
offers, make whole exercises and open market repurchases, since they are in line with the company's liability
management strategy, in order to improve its debt repayment profile and cost of debt.
Adjusted Cash and Cash Equivalents is a non-GAAP measure that comprises cash and cash equivalents,
government bonds and time deposits from highly rated financial institutions abroad with maturities of
more than three months from the end of the period, considering the expected realization of those financial
investments in the short-term. This measure is not defined under the IFRS Accounting Standards and
should not be considered in isolation or as a substitute for cash and cash equivalents computed in
accordance with IFRS Accounting Standards. It may not be comparable to the adjusted cash and cash
equivalents of other companies; however, management believes that it is an appropriate supplemental
measure to assess our liquidity and supports leverage management.
Annual Report and Form 20-F 2024 I 201
Operating and Financial Review and
Prospects
LIQUIDITY AND CAPITAL RESOURCES
US$ million
2024
2023
Cash and cash equivalents at the beginning of the period
12,727
7,996
Net cash provided by operating activities
37,984
43,212
Acquisition of PP&E and intangibles assets
(14,644)
(12,114)
Acquisition of equity interests
(22)
(24)
Proceeds from disposal of assets – Divestment
863
3,606
Financial compensation from co-participation agreements
397
391
Dividends received
146
88
Divestment (Investment) in marketable securities
(109)
98
Net cash (used in) provided by investing activities
(13,369)
(7,955)
(=) Net cash provided by operating and investing activities
24,615
35,257
Net change in finance debt
(6,325)
(3,961)
Proceeds from financing
2,129
2,210
Repayments
(8,454)
(6,171)
Repayment of lease liability
(7,895)
(6,286)
Dividends paid to our shareholders
(18,327)
(19,670)
Share repurchase program
(380)
(735)
Dividends paid to non-controlling interest
(77)
(49)
Changes in non-controlling interest
(84)
1
Net cash used in financing activities
(33,088)
(30,700)
Effect of exchange rate changes on cash and cash equivalents
(983)
174
Cash and cash equivalents at the end of the period
3,271
12,727
Government bonds and time deposits with maturities of more than three months and
post-fixed Bank Deposit Certificates with daily liquidity at the end of the period
4,800
5,175
Adjusted Cash and Cash Equivalents at the end of the period
8,071
17,902
Annual Report and Form 20-F 2024 I 202
Operating and Financial Review and
Prospects
Free Cash Flow
Free Cash Flow is a non-GAAP measure representing Net cash provided by operating activities
minus Acquisition of PP&E, intangible assets and equity interest (“Free Cash Flow”). We use it as
a supplemental measure to assess our liquidity and to support liability management. In addition,
this measure is the basis for the distribution of dividends according to our shareholder
remuneration policy.
Free Cash Flow is a non-GAAP measure and may not be comparable to the calculation of liquidity
measures presented by other companies, and it should neither be considered in isolation nor as a
substitute for any measures calculated in accordance with IFRS Accounting Standards. This
metric must be considered together with other measures and indicators for a better
understanding of our financial condition.
RECONCILIATION OF FREE CASH FLOW
US$ million
R$ million(1)
2024
2023
2024
2023
Net cash provided by operating activities
37,984
43,212
204,037
215,696
(-) Acquisition of PP&E and intangible assets
(14,644)
(12,114)
(79,856)
(60,315)
(-) Acquisition of equity interests
(22)
(24)
(127)
(120)
FREE CASH FLOW
23,318
31,074
124,054
155,261
(1) According to our shareholder remuneration policy, proposed dividends to shareholders are calculated based on the Free Cash Flow measured
in Brazilian reais whose numbers are derived from our annual financial statements filed with the CVM.
The principal uses of funds in the year ended December 31, 2024 were for dividend payments and share
repurchase program amounting to US$18,784 million, debt service obligations, including pre-payment of
debts in the international banking market, interest on finance debt, repurchase of securities in the
international capital market and lease payments totaling US$16,349 million and acquisition of PP&E and
intangibles assets in the amount of US$14,644 million. These funds were mainly provided by cash from
operating activities of US$37,984 million, proceeds from divestments of US$863 million, proceeds from
financing of US$2,129 million, and financial compensation from co-participation agreements of US$397
million.
Annual Report and Form 20-F 2024 I 203
Operating and Financial Review and
Prospects
Source of Funds
In 2024, our financing strategy was mainly based in managing our existing financial liabilities, aiming to
extend short-term debt maturities and improving our capital structure, preserving our solvency and
liquidity.
Cash Flows from Operating Activities
Net cash provided by operating activities was US$37,984 million in 2024, a decrease of 12% from US$43,212
million in 2023, mainly due to lower margins on oil products (especially diesel and gasoline), as well as lower
prices and volumes. Additionally, higher costs of sold oil and payments related to the tax settlement
program contributed to the decrease.
Disposal of Assets
In 2024, we received cash inflow from the sale of assets amounting to US$863 million, relating to
installments of sales occurred in previous years, mainly of Carmópolis field (US$296 million), Pampo and
Enchova fields (US$92 million) and Baúna field (US$86 million). For more information, see Note 29 to our
audited consolidated financial statements.
From January 1, 2025 through February 28, 2025, we received US$277 million from the sale of several fields,
mainly an earnout from the sale of Albacora Leste field (US$174 million) and an installment from the sale
of Baúna field (US$88 million).
For additional information on divestments, see “Mergers and Acquisitions” in this annual report.
Debt
Our proceeds from financing are comprised of local and global notes issued in the capital markets and funds
raised from banking markets (in Brazil and abroad).
Additionally, our total debt includes lease liabilities. Our Gross Debt (which represents the sum of current
and non-current finance debt and lease liabilities) totaled US$60,311 million, and the Net Debt (a non-GAAP
measure representing Gross Debt minus Adjusted Cash and Cash Equivalents), totaled US$52,240 million.
We can use our revolving credit lines in case of liquidity needs at any time until their maturity dates, and
they will be considered as part of our Gross Debt and Net Debt only once drawn down.
For reconciliation of Net Debt and Gross Debt, see “Liquidity and Capital Resources – Sources of Funds –
Finance Debt – Adjusted EBITDA and Net Debt/Adjusted EBITDA ratio” in this annual report.
Annual Report and Form 20-F 2024 I 204
Operating and Financial Review and
Prospects
Finance Debt
DEBT PROFILE
In 2024, proceeds from financing amounted to US$2,129 million, reflecting notably the issuance of Global
Notes in the international capital markets in the amount of US$978 million, maturing in 2035 and proceeds
in the domestic banking market, in the amount of US$1,122.
We currently issue notes in the international capital markets through our wholly-owned finance subsidiary
PGF. We fully and unconditionally guarantee such notes issued by PGF.
Information on weighted average interest rate and weighted average maturity of our finance debt is
presented below:
2024
2023
2022
Weighted average interest rate (%)
6.8
6.4
6.5
Weighted average maturity (in years)
12.52
11.38
12.07
Leverage (%)(1)
39
30
39
(1)
Leverage is a non-GAAP measure defined as (Gross Debt – Adjusted cash and cash equivalents) / (Market Capitalization + Gross Debt – Adjusted cash and
cash equivalents) as of December 31 of the respective year.
For additional information on Finance Debt amortization, see “Liquidity and Capital Resources – Use of
Funds – Debt Service Obligations” in this annual report.
FINANCE DEBT PROFILE PER CATEGORY AS OF DECEMBER 31, 2024 (%)
Annual Report and Form 20-F 2024 I 205
Operating and Financial Review and
Prospects
DEBT PROFILE PER CURRENCY AS OF DECEMBER 31, 2024 (%)
As of December 31, 2024, our finance debt amounted to US$23,162 million, as compared to US$28,801
million as of December 31, 2023. This decrease was primarily due to repayment of finance debt, including
early payment of US$2,762 million. See Note 30 to our audited consolidated financial statements for a
breakdown of our finance debt, a roll-forward schedule of our finance debt by source and other information.
For more information about our securities, including our bonds, see Exhibit 2.4 to this annual report.
Annual Report and Form 20-F 2024 I 206
Operating and Financial Review and
Prospects
Rating
In 2024, Moody’s upgraded Petrobras’ rating outlook from stable to positive while reaffirming its
credit rating at “Ba1.” The agency also maintained our stand-alone rating at “Ba1.” S&P reaffirmed our
credit rating at “BB” with a stable outlook and kept our stand-alone rating at “BB+,” one notch below
investment grade. Fitch maintained our credit rating at “BB” with a stable outlook and upheld our
stand-alone rating at “BBB,” the second level in the investment-grade scale.
As of April 2, 2025, there were no changes to our stand-alone credit profile rating or global rating.
GLOBAL RATING
2025(1)
2024(2)
2023(2)
Standard & Poor’s
BB
BB
BB
Moody’s
Ba1
Ba1
Ba1
Fitch
BB
BB
BB
(1) As of April 2, 2025.
(2) As of December 31.
STAND ALONE RATING
2025(1)
2024(2)
2023(2)
Standard & Poor’s
BB+
BB+
BB+
Moody’s
Ba1
Ba1
Ba1
Fitch
BBB
BBB
BBB
(1) As of April 2, 2025.
(2) As of December 31.
Annual Report and Form 20-F 2024 I 207
Operating and Financial Review and
Prospects
Exposure to interest rate and exchange rate risk
The table below provides a summary of information regarding our exposure to interest rate and
exchange rate risk in our finance debt for 2024 and 2023, including short-term and long-term
debt.
TOTAL FINANCE DEBT(1)
2024 (%)
2023 (%)
Real - denominated
Fixed rate
8.1
9.5
Floating rate
14.7
10.6
Sub-total
22.8
20.1
U.S. dollar - denominated
Fixed rate
47.2
41.9
Floating rate
23.7
29.4
Sub-total
70.9
71.3
Other currencies
Fixed rate
6.3
8.6
Sub-total
6.3
8.6
Total
100.0
100.0
Floating rate debt
Real-denominated
14.7
10.6
Foreign currency-denominated
23.7
29.4
Fixed rate debt
Real-denominated
8.1
9.5
Foreign currency denominated
53.5
50.5
Total
100.0
100.0
U.S. dollars
70.9
71.3
Euro
2.3
3.3
GBP
4.0
5.3
Brazilian reais
22.8
20.1
Total
100.0
100.0
(1)
Short term and long term.
We aim to practice integrated risk management in every decision-making process. Thus, we do
not focus solely on the individual risks of our operations or business units, but, rather, we take a
broader view of our consolidated activities, capturing possible natural hedges where and when
available. With respect to the management of financial risks, including market risks, we
preferentially use more structural actions through the management of our equity and
indebtedness levels, instead of using financial derivative instruments.
Market risk management focuses on the uncertainties inherent in meeting our objectives and
aims at establishing action plans towards a balanced combination of risk, return and liquidity.
Acceptable limits for market risks depend on the conditions of the business environment, such as
price levels, rates and volatility of risk factors, political, macroeconomic and other uncertainties
Annual Report and Form 20-F 2024 I 208
Operating and Financial Review and
Prospects
that significantly influence our economic and financial performance. We define the limits for
market risks when elaborating each new strategic plan we adopt, considering our strategic
objectives, goals, expected value and the liquidity of financial resources required for the
implementation of that strategic plan. The use of financial instruments, such as derivatives, may
be necessary to meet our needs.
Our foreign currency floating rate debt is mainly subject to fluctuations in SOFR. Our floating rate
debt denominated in reais is subject to fluctuations in the Brazilian interbank offering rate (or
“DI”) and Brazilian long-term interest rate as fixed by the CMN.
We generally do not use derivative instruments to manage our exposure to interest rate
fluctuation, but we may utilize these financial instruments in the future.
The exchange rate risk to which we are exposed has greater impact on the balance sheet and
derives mainly from the presence of non-real denominated obligations in our debt portfolio. With
respect to the management of foreign exchange risks, we take a broader view of our consolidated
activities, capturing possible natural hedges whenever they are available, benefiting from the
correlation between our income and expenses. In the short term, the management of our foreign
exchange risk involves allocating our cash investments between the real and other foreign
currencies. Our strategy, reevaluated annually in the revision of our Business Plan, may also
involve the use of financial instruments, such as derivatives, to hedge certain liabilities,
minimizing foreign exchange rate risk exposure, especially when we are exposed to a foreign
currency in which no cash inflows are expected, for example, the Pound Sterling.
We have designated cash flow hedging relationships to reflect the economic essence of the
structural hedge mechanism between U.S. dollar-denominated debt and future sales revenues.
See “Consolidated Financial Performance – Exchange Rate and Variation Impacts” in this section
and Notes 4.8 and 33.4.1(a) to our audited consolidated financial statements for further
information about our cash flow hedge.
See Note 33.4 to our audited consolidated financial statements for more information about our
interest rate and exchange rate risks, including a sensitivity analysis demonstrating the potential
impact of an adverse change in the underlying variables as of December 31, 2024.
For further information regarding expected maturity schedule and currency, the principal and
interest cash flows, related average interest rates of our debt obligations, credit risk and liquidity
risk, see Notes 30, 33.5 and 33.6 to our audited consolidated financial statements.
LEASE LIABILITIES
We are the lessee in agreements primarily including oil and gas producing units, drilling rigs and other
exploration and production equipment, vessels and support vessels, helicopters, land and buildings. As of
December 31, 2024, the amount of lease liabilities totaled US$37,149 million.
Annual Report and Form 20-F 2024 I 209
Operating and Financial Review and
Prospects
ADJUSTED EBITDA AND NET DEBT/ADJUSTED EBITDA RATIO
The Net Debt/Adjusted EBITDA ratio is non-GAAP measure that helps our management assess our liquidity
and leverage, and it is measured in U.S. dollars. Net Debt/Adjusted EBITDA ratio is not defined under IFRS
Accounting Standards and should not be considered in isolation or as a substitute for net income or other
measures calculated in accordance with IFRS Accounting Standards.
Adjusted EBITDA represents an alternative measure to our net cash provided by operating activities and is
computed by using the net income before net finance expense, income taxes, depreciation, depletion and
amortization, adjusted by results of equity-accounted investments, impairment, results on disposal/write-
offs of assets, and results from co-participation agreements in bid areas. Adjusted EBITDA is not defined
under IFRS Accounting Standards and should not be considered in isolation or as a substitute for net income
or other measures calculated in accordance with IFRS Accounting Standards.
US$ million
2024
2023
2022
Net income
7,605
24,995
36,755
Net finance expense
15,107
2,333
3,840
Income taxes
3,537
10,401
16,770
Depreciation, depletion and amortization
12,479
13,280
13,218
Results of equity-accounted investments
627
304
(251)
Impairment of assets (reversals), net
1,531
2,680
1,315
Results on disposal/write-offs of assets
(228)
(1,295)
(1,144)
Results from co-participation agreements in bid areas
(259)
(284)
(4,286)
ADJUSTED EBITDA
40,399
52,414
66,217
Net Debt reflects the Gross Debt, net of Adjusted Cash and Cash Equivalents (see definition in “Liquidity
and Capital Resources” in this annual report). Gross Debt reflects the sum of current and non-current
finance debt and lease liabilities.
Our Adjusted EBITDA, Adjusted Cash and Cash Equivalents, Net Debt and Net Debt/Adjusted EBITDA ratio
are non-GAAP measures and may not be comparable to the calculation of liquidity measures presented by
other companies, and they should neither be considered in isolation nor as substitutes for any measures
calculated in accordance with IFRS Accounting Standards. These metrics must be considered together with
other measures and indicators for a better understanding of our financial condition.
The following table presents the reconciliation for 2024 and 2023 of Net Debt and Adjusted EBITDA to the
most directly comparable IFRS Accounting Standards captions, which, in this case, is, respectively, the
finance debt plus lease liability minus cash and cash equivalents and the net cash provided by operating
activities:
Annual Report and Form 20-F 2024 I 210
Operating and Financial Review and
Prospects
US$ million
2024
2023
Cash and cash equivalents
3,271
12,727
Government securities and time deposits (maturity of more than three
months)
4,800
5,175
Adjusted Cash and Cash Equivalents
8,071
17,902
Finance debt (current and non-current)
23,162
28,801
Lease liability (current and non-current)
37,149
33,799
GROSS DEBT
60,311
62,600
NET DEBT
52,240
44,698
US$ million
2024
2023
Net cash provided by operating activities - OCF
37,984
43,212
Allowance for credit loss on trade and other receivables, net
(260)
(40)
Trade and other receivables, net
(1,822)
(88)
Inventories
295
(1,564)
Trade payables
(986)
954
Taxes payable (1)
9,895
10,463
Losses on decommissioning of returned/abandoned areas
(2,584)
(1,195)
Losses arising from actuarial review of health care plan
(1,291)
-
Others
(832)
672
ADJUSTED EBITDA
40,399
52,414
NET DEBT/ADJUSTED EBITDA RATIO
1.29
0.85
(1)
It is composed of other taxes payable and Income taxes paid.
Our Net Debt/Adjusted EBITDA ratio computed in U.S. dollar increased from 0.85 as of December 31, 2023,
to 1.29 as of December 31, 2024, reflecting the effects derived by the combination of lower Adjusted EBITDA
and higher Net Debt.
Annual Report and Form 20-F 2024 I 211
Operating and Financial Review and
Prospects
Use of Funds
Capital Expenditures
We disbursed a total of US$16,621 million in 2024 (of which 84% was used in E&P business), a 31.2% increase
when compared to our Capital Expenditures of US$12,673 million in 2023. It was 10% lower than our previous
Strategic Plan (2024-2028). Our Capital Expenditures in 2024 were primarily directed toward the most
profitable investment projects relating to oil and gas production. These expenditures are based on our
Strategic Plan’s cost assumptions and financial methodology.
CAPITAL EXPENDITURES BY BUSINESS SEGMENTS (US$ million)
For the Year Ended December 31,
2024
2023
2022
Exploration and Production
13,934
10,424
7,844
Refining, Transportation and Marketing
1,799
1,559
1,193
Gas and Low Carbon Energies
426
277
350
Total business segments
16,160
12,260
9,387
Corporate and Other Businesses
461
413
461
TOTAL
16,621
12,673
9,848
For information on our future Capital Expenditures, see “Strategic Plan 2050 and Business Plan 2025-2029”
in this annual report.
Annual Report and Form 20-F 2024 I 212
Operating and Financial Review and
Prospects
Distribution to shareholders
Our Board of Directors proposed a distribution to shareholders in 2024 in the amount of US$13,457 million.
This distribution (US$13,076 million through the payment of dividends and interest on capital, and US$381
million through the share repurchase program) was calculated in Brazilian reais, in the amount of R$75,825
million, representing 45% of our Free Cash Flow for 2024, according to the shareholders remuneration
policy, converted to U.S. dollars based on the exchange rate prevailing at the date of approval for each
anticipation and on the closing exchange rate for the complementary dividends.
For more information on our shareholder remuneration policy, see “Shareholder Information –
Shareholders’ Rights” in this annual report and Note 32.4 to our audited consolidated financial statements.
Debt Service Obligations
As of December 31, 2024, our debt maturity profile includes, for the next five years, US$36,424 million in
finance debt and lease liability (nominal amounts).
AMORTIZATION PROFILE (1) (US$ million)
(1) Amounts composed by Lease nominal future payments and Finance debt principal.
Finance Debt
In 2024, we repaid the principal and interest on several finance debts, in the amount of US$8,454 million,
notably: (i) repurchase and withdraw of US$2,512 of securities in the international capital market; and (ii)
pre-payment of US$250 of loans in the international banking market.
Annual Report and Form 20-F 2024 I 213
Operating and Financial Review and
Prospects
Lease Liabilities
We are the lessee in agreements that primarily include oil and gas producing units, drilling rigs and other
exploration and production equipment, vessels and support vessels, helicopters, land and buildings.
Payments in certain lease agreements vary due to changes in facts or circumstances occurring after their
inception other than the passage of time. These payments are not included in the measurement of the lease
obligations.
In addition, there are nominal amounts of lease agreements for which the lease term has not commenced,
as they relate to assets under construction or not yet available for use. As of December 31, 2024, these
agreements amount to US$65,034 million (US$65,358 million on December 31, 2023).
For information on changes in the balance of lease liabilities and on leases by class of underlying assets, see
Note 31 to audited consolidated financial statements.
Ability of Subsidiaries to Transfer Funds to Us
As of the date hereof, we have no knowledge of any legal or economic restrictions on the ability of our
subsidiaries to transfer funds to us in the form of loans and/or dividends. The prejudgment attachment
levied by a number of EIG entities that previously prevented Petrobras International Braspetro B.V. (the
“PIBBV”) from paying dividends to Petrobras was lifted as a result of the settlement entered into with EIG
on March 7, 2025. As a result, we do not anticipate any impact on our ability to meet our cash obligations.
For further information on the prejudgment attachment see “Legal and Tax - Legal Proceedings - Sete
Brasil’s Investor Claim and Mediation Procedure” in this annual report.
Other Information
Judgments and sources of estimation uncertainty
The preparation of the consolidated financial information requires the use of estimates and judgments for
certain transactions.
Note 4 to our audited consolidated financial statements presents key judgments and the main sources of
estimation uncertainty with a significant risk of causing material adjustments to our key accounting
estimates over the next fiscal year.
Explanatory notes to our audited consolidated financial statements to each of those areas provide
additional qualitative and quantitative information for a better understanding of our judgments, the
estimation uncertainties and their impacts.
Note 5 to our audited consolidated financial statements presents information about the potential effects
of climate risks on some of our key accounting estimates.
Management and
Employees
Annual Report and Form 20-F 2024 I 215
Management and
Employees
Management
Board of Directors
Our Board of Directors is composed of a minimum of seven and maximum of eleven members and is
responsible for, among other things, establishing our general business policies. Our Bylaws specifically
provide that our Board of Directors must be composed of external members only, without any current
statutory or employment relationship with us, except for the member designated as our CEO and the
member elected by our employees.
The Brazilian federal government controls a majority of our voting shares and has the right to elect a
majority of the members of our Board of Directors. Our Board of Directors, in turn, elects our management.
As a mixed-capital company with 200 or more employees, in which the Brazilian federal government directly
or indirectly holds a majority of the voting rights, our employees have the right to elect one member of our
Board of Directors to represent them, by means of a separate voting procedure.
Our Bylaws also provide that, regardless of the rights granted to minority shareholders, the Brazilian federal
government always has the right to elect the majority of our directors, regardless of the number of
directors.
The term of office of our directors may not exceed two years and any member of our Board of Directors may
be re-elected for up to three consecutive times.
In accordance with Brazilian Corporate Law, shareholders may remove any director from office at any time
with or without cause at an extraordinary shareholders’ meeting, and in case of removal of any board
member elected through cumulative voting procedure, it will result in the removal of all of the other
members elected under the same procedure, after which new elections must occur.
Our Board of Directors must be composed of, at least, 40% independent members, in compliance with
Brazilian Corporate Law and B3 Level 2 rules. In case of contradictions between these rules, the stricter rules
prevail.
For further information on Level 2 listing segment, see “Shareholder Information” in this annual report.
For further information regarding the composition, attributions and duties of our Board of Directors, see
Exhibit 1.1 to this annual report for a copy of our Bylaws.
Annual Report and Form 20-F 2024 I 216
Management and
Employees
As of the date of this annual report, we have the following 11 directors:
Annual Report and Form 20-F 2024 I 217
Management and
Employees
Annual Report and Form 20-F 2024 I 218
Management and
Employees
Annual Report and Form 20-F 2024 I 219
Management and
Employees
Annual Report and Form 20-F 2024 I 220
Management and
Employees
Annual Report and Form 20-F 2024 I 221
Management and
Employees
Mr. Marcelo Gasparino da Silva resigned as a member of the Board of Directors on February 20, 2025,
effective on March 20, 2025. Under the terms of article 150 of Law No. 6,404/76 and article 25 of our Bylaws,
in the event of a vacancy in the position of Board Member, the position may be filled by a replacement
appointed by the Board of Directors, until the next General Shareholders’ Meeting is held, which, in this case,
is already scheduled to take place on April 16, 2025. On March 28, 2025, our Board of Directors appointed
Mr. Aloisio Macário Ferreira de Souza as an Board Member of the company to replace Mr. Marcelo Gasparino
da Silva until the General Shareholder’s Meeting. Mr. Aloisio Macário Ferreira de Souza took office on April
1, 2025.
Our Annual General Meeting announcing new members joining the Board of Directors will take place in April
2025, after the filing of this report. Information on the proposal regarding the prospective new members is
available to shareholders on our website (www.petrobras.com.br/ir) and the SEC’s website.
Annual Report and Form 20-F 2024 I 222
Management and
Employees
Fiscal Council
We have a permanent Fiscal Council composed of up to five members, which is independent of our
management and independent registered accounting firm. Our Fiscal Council’s responsibilities, as a
supervisory body, include, among others: (i) representing the shareholders, monitoring management
activities; (ii) verifying compliance with legal and statutory duties; and (iii) reviewing the annual
management report and the audited consolidated financial statements, issuing an opinion at the end of the
year.
The members of our Fiscal Council and their corresponding alternates are elected by our shareholders at
the annual shareholders’ meeting for a one-year term. Two consecutive re-elections are permitted under
Brazilian Corporate Law. Holders of preferred shares and minority holders of common shares are each
entitled, as a class, to elect one member and the corresponding alternate of our Fiscal Council. The Brazilian
federal government has the right to appoint the majority of the members of our Fiscal Council and their
alternates, of which one member and the corresponding alternate will be necessarily appointed by the
Minister of Finance, representing the Brazilian Treasury.
CURRENT MEMBERS OF OUR FISCAL COUNCIL
Year of first
appointment
Elected/appointed by
Members
Cristina Bueno Camatta
2023
Brazilian federal government
Daniel Cabaleiro Saldanha (Chairman)
2023
Brazilian federal government
Viviane Aparecida da Silva Varga
2023
Brazilian federal government/
Ministry of Finance
Paulo Roberto Franceschi
2024
Minority shareholder
Ronaldo Dias
2024
Preferred shareholder
Alternate members
Sidnei Bispo
2023
Brazilian federal government
Gustavo Gonçalves Manfrim
2023
Brazilian federal government
Otávio Ladeira de Medeiros
2022
Brazilian federal government/
Ministry of Finance
Vanderlei Dominguez da Rose
2024
Minority shareholder
Ricardo José Martins Gimenez
2024
Preferred shareholder
Our Annual General Meeting announcing new members joining the Fiscal Council will take place in April 2025,
after the filing of this report. Information on the proposal regarding the prospective new members is
available to shareholders on our website (www.petrobras.com.br/ir) and the SEC’s website.
Annual Report and Form 20-F 2024 I 223
Management and
Employees
Executive Officers
Our Executive Officers is composed of one CEO and eight executive officers. According to our Bylaws, our
Executive Officers is responsible for our day-to-day management. Our executive officers are not required
to be Brazilian citizens but must reside in Brazil. Pursuant to our Bylaws, our Board of Directors elects our
executive officers, including the CEO, and must consider personal qualifications, expertise and
specialization when electing executive officers. Our executive officers’ mandate lasts for two years, and no
more than three consecutive re-elections are allowed. Our Board of Directors may remove any executive
officer from office at any time and without cause, with a special procedure for the removal of the Executive
Director of Governance and Compliance pursuant to the Internal Regiment of Board of Directors. According
to the Internal Regiment of Board of Directors, in order to decide on the removal of the Executive Director
of Governance and Compliance the Board of Directors must follow a qualified quorum which requires the
vote of the Director elected by the minority shareholders or the Director elected by the preferred
shareholders.
For further information regarding our Executive Officers, see Exhibit 1.1 to this annual report for a copy of
our Bylaws.
As of the date of this annual report, we have the following nine executive officers:
Annual Report and Form 20-F 2024 I 224
Management and
Employees
Annual Report and Form 20-F 2024 I 225
Management and
Employees
Annual Report and Form 20-F 2024 I 226
Management and
Employees
Annual Report and Form 20-F 2024 I 227
Management and
Employees
Annual Report and Form 20-F 2024 I 228
Management and
Employees
Additional Information on our Board of Directors and Executive Officers
Requirements for Election
Our bylaws (as amended by the Extraordinary Shareholders Meeting dated April 25, 2024) provide that the
election of Board Members and Executive Officers shall follow the requirements and restrictions provided
by Law No. 6.404/76, Law No. 13.303/2016 and Decree No. 8945/16, as well as our Nomination Policy. Thus,
in order to be elected, each of our executive officers and each member of our Board of Directors must:
_ not be a defendant in any legal or administrative proceedings with an unfavorable ruling by appellate
courts concerning a matter related to the activities to be performed in our company;
_ not have commercial or financial pending issues claimed or included in official debtor registers,
although clarification on such issues may be provided to us;
_ demonstrate diligence in solving issues raised in reports of internal or external control bodies in
processes and/or activities under their management, when applicable;
_ not have violated our Code of Ethical Conduct, Compliance Program or other internal rules, when
applicable;
_ not have been included in the disciplinary system of any of our subsidiaries or affiliates, nor have
been subject to labor or administrative penalty in any other legal entity in the last three years as a
result of internal investigations, when applicable; and
_ our executive officers must have 10 years of experience in leadership, preferably, in business or in a
related area, as specified in our nomination policy.
Compensation
Under our Bylaws, our shareholders establish the aggregate compensation, or allocate the compensation
on an individual basis, payable to our directors, executive officers, members of our Fiscal Council and
advisory committees to our Board of Directors. In case shareholders do not allocate the compensation on
an individual basis, our Board of Directors is allowed to do so.
For the year-ended December 31, 2024, the aggregate amount of compensation we paid to all members of
our Board of Directors and our Executive Officers was US$6.8 million. These amounts include payment of
variable compensation to our executive officers. As of December 31, 2024, we had nine executive officers
and 11 Board of Directors members.
For information regarding our variable compensation programs, and other benefits such as pension and
health plans, see “Employees – Benefits” in this section.
Annual Report and Form 20-F 2024 I 229
Management and
Employees
2024(1)
Executive Officers
Board of Directors
Fiscal Council
Average number of members in the period
9
11
5
Average number of paid members in the period
9
8
5
Value of maximum compensation (US$)
583,187.66
30,519.52
33,571.48
Value of minimum compensation (US$) (2)
456,791.94
29,397.77
30,519.52
Average value of compensation (US$) (3)
622,480.03(4)
31,004.72
31,129.81
(1)
The values consider all installments paid in the 2024 financial year as established by the CVM.
(2)
The value of the individual minimum annual remuneration was determined taking into account the remuneration actually paid to members who worked
during the year. The member with the lowest annual salary served for 12 (twelve) months in the fiscal year.
(3)
The average value of compensation corresponds to the total value of the annual compensation paid divided by the average number of paid members in
the period.
(4)
The calculation includes the values related to the termination of the position (gardening leave) and payment of the deferred installments of Variable
Remuneration referring to former members of the Executive Officers who left our company. Consequently, the average value was higher than the value of
the maximum compensation and does not represent the amount actually paid to our current Executive Officers, which is presented in the minimum and
maximum compensation amounts indicated above.
For further information regarding compensation of our employees and officers, see Notes 18 and 34 to our
audited consolidated financial statements.
Besides compensation, the members of our Executive Officers receive additional benefits, such as medical
assistance, supplementary social security benefits and a housing allowance. The members of the Board of
Directors are entitled to supplementary social security benefits.
Members of the Board of Directors, Fiscal Council and the Executive Officers may be legally entitled to
gardening leave (Quarentena) upon termination of office, which rules and exceptions are provided by
Brazilian law.
None of the members of our Executive Officers nor any of our subsidiaries are entitled benefits upon
termination of employment.
For information on our advisory committee, see “Statutory Board Committees” below.
We were not required to prepare an accounting restatement that required recovery of erroneously awarded
compensation pursuant to our clawback policy. Additionally, there was no outstanding balance as of
December 31, 2024 of erroneously awarded compensation to be recovered from the application of the policy
to a prior restatement.
See Exhibit 97.1 to this annual report for a copy of Petrobras’ clawback policy.
Annual Report and Form 20-F 2024 I 230
Management and
Employees
Share Ownership
As of January 31, 2025, the members of our Board of Directors, executive officers and members of Fiscal
Council beneficially held the following shares of our capital stock:
Board of Directors(1)
Executive Officers(1)
Fiscal Council
Common shares (2)
218,608,427 (3)
3,110
—
Preferred shares (2)
10,418
64,333
12,042
(1)
Magda Chambriard is our CEO and member of our Board of Directors. To avoid duplication of data, her share ownership was only considered in the total
amount of shares owned by members of the Board of Directors.
(2)
Considers CVM criteria which includes the shares owned by a spouse from whom they are not legally or extrajudicially separated, a marriage partner, any
dependents included in their annual income tax return and companies directly or indirectly controlled by them. It also includes the position held by
alternate members of the Fiscal Council. It does not include the position held by external members of the Board of Directors' Advisory Committees.
(3)
Also reflects the beneficial ownership of approximately 2.94% common shares by José João Abdalla Filho.
On an individual basis, our Directors, Executive Officers and Fiscal Council members beneficially owned less
than 1% of any class of our shares, except for Mr. José João Abdalla Filho, who beneficially owned, as of
January 31, 2025, 218,601,900 common shares of the company, representing approximately 2.94% of
common shares of the company. The shares held by our Directors, Executive Officers and Fiscal Council
members have the same voting rights as the shares of the same type and class that are held by our other
shareholders. None of our Directors, Executive Officers and Fiscal Council members hold any options to
purchase common shares or preferred shares, nor does any other person have any option to purchase our
common or preferred shares. We do not have a stock option plan for our Directors, Officers or employees.
Annual Report and Form 20-F 2024 I 231
Management and
Employees
Statutory Board Committees
Our Board of Directors has a total of six statutory advisory committees:
_
Investment Committee: responsible for advising our Board of Directors with respect to the
definition of our strategic guidelines, the strategic plan, the annual business plan, among other
strategic matters and financial issues. The committee also assists our Board of Directors in
evaluating the structure and conditions of investment and divestment transactions, including new
business opportunities, mergers, consolidations, and spin-offs in which we are involved, and which
are within the responsibility of the Board of Directors. In addition, the committee provides advice to
our Board of Directors on analyzing our annual financing program.
_
Audit Committee: for further information on our audit committee, please see “Audit Committee” in
this section.
_
Health, Safety and Environmental Committee: responsible for advising our Board of Directors on
policies and guidelines related to the strategic management of HSE, climate change, transition to a
low carbon economy and social responsibility issues, among other matters. This committee
monitors, among other issues, indicators and research on our image and reputation, related to the
HSE and sustainability matters, suggesting actions when necessary. In addition, the committee
approves and monitors ESG initiatives.
_
People Committee: responsible for assisting our Board of Directors in aspects regarding the
management of senior level human assets, including, but not limited to: compensation (fixed and
variable), appointments and succession policies as well as the selection and eligibility processes. The
People Committee stands in compliance with Brazilian Law No. 13,303/12 and Decree No. 8,945/16,
acting as an eligibility committee for assisting shareholders to nominate members to the Board of
Directors and Fiscal Council and overseeing the implementation of the required background checks
on integrity and compliance regarding of the Board of Directors, Fiscal Council and Executive
Officers nominees, as well as external members of the Board of Directors advisory committees, and
having a deliberative role in these cases. The committee advises our Board of Directors on the
possible application of penalties for the Executive Officers and, members of the Board of Directors
and its Statutory Advisory Committees and, evaluates appeals of terminations of employment
contracts if the Integrity Committee does not reach a consensus on disciplinary measures. The
committee also monitors image and reputation surveys, recommending actions when necessary.
_
Minority Committee: responsible for advising our Board of Directors on transactions with related
parties involving, the Brazilian federal government, its entities and foundations, or federal state-
owned enterprises in case of transactions outside the ordinary course of our business, including
following up the revision process of the Transfer of Rights Agreement. The minority committee also
advises our shareholders issuing its opinion on certain matters that require approval in
shareholders’ meetings, pursuant to article 30, §4 of our Bylaws.
_
Conglomerate Audit Committee: approved to meet the requirements of Law No. 13,303/16, which
provides the possibility that controlled companies share the costs and structures of their
corresponding parent companies. The committee is responsible for the companies of the Petrobras
Conglomerate that do not have internal audit committees. In addition, the committee provides
advice to our Board of Directors regarding guidelines for companies of the Petrobras Conglomerate
in matters provided in its bylaws.
Annual Report and Form 20-F 2024 I 232
Management and
Employees
SUMMARY OF THE COMPOSITION OF OUR STATUTORY ADVISORY COMMITTEES, AS OF THE DATE OF
THIS ANNUAL REPORT
Committees
Members
Investment
Audit
Health, Safety,
and
Environment
People
Minority
Audit of the Petrobras
Conglomerate
Arthur Cerqueira Valerio
●
Benjamin Alves Rabello Filho
●
Bruno Moretti
●
Eugênio Tiago Chagas Cordeiro e
Teixeira
●
●
Evely Forjaz Loureiro
●
Fábio Veras de Souza
●
●
●
Francisco Petros Oliveira Lima
Papathanasiadis
●
Gustavo Amarante Gabriel
●
Jerônimo Antunes
●
●
●
●
José Affonso de Albuquerque Netto
●
José João Abdalla Filho
●
●
Newton de Araujo Lopes
●
Rafael Ramalho Dubeux
●
Raoni Iago Pinheiro Santos
●
Renato Campos Galuppo
●
Rodrigo de Melo Teixeira
●
Rosangela Buzanelli Torres
●
●
● CHAIRMAN / CHAIRWOMAN OF EACH COMMITTEE
● EXTERNAL MEMBERS OF EACH COMMITTEE
● REMAINING MEMBERS
Annual Report and Form 20-F 2024 I 233
Management and
Employees
Audit Committee
Our statutory audit committee is an advisory committee of our Board of Directors, and aids in matters
involving our accounting, internal controls, financial reporting and compliance. Our statutory audit
committee also recommends the appointment of our independent registered accounting firm to our Board
of Directors and evaluates the effectiveness of our internal financial and legal compliance controls. In
accordance with Law No. 13,303/2016 and Decree No. 8,945/2016, our statutory audit committee must have
at least three members and no more than five members, who must be independent in accordance with the
independence requirements of the Law No. 13,303/2016 and CVM Resolution 23/2021 and at least one of
the members must have recognized experience in corporate accounting. Additionally, CVM Resolution No.
23/2021 requires at least one member of the audit committee to be a board member, although they permit
the appointment of other members who are not members of the Board of Directors provided that such other
members meet the independence requirements of the CVM. On November 30, 2020, our shareholders
approved an amendment to our bylaws requiring our audit committee to be composed of members of our
Board of Directors and external individuals.
Due to its composition, our statutory audit committee is not equivalent to or comparable with a U.S. audit
committee. Pursuant to Exchange Act Rule 10A-3(c)(3), which provides for an exemption under the rules of
the SEC regarding the audit committees of listed companies, a foreign private issuer is not required to have
an audit committee equivalent to or comparable with a U.S. audit committee if the foreign private issuer
has a body established and selected pursuant to home country legal or listing provisions expressly requiring
or permitting such a body, and if the body meets the requirements that (i) it be separate from the full board,
(ii) its members not be elected by management, (iii) no executive officer be a member of the body, and (iv)
home country legal or listing provisions set forth standards for the independence of the members of the
body.
Given that our statutory audit committee is subject to certain requirements under CVM rules (CVM
Resolution 23/2021), we understand that it complies with these requirements, and we rely on the exemption
provided by Rule 10A-3(c)(3) under the Exchange Act.
Our audit committee currently consists of four members, all of whom are independent in accordance with
the independence requirements set forth by Law No. 13,303/2016 and CVM Resolution No. 23/2021. Since
June 2023, Mr. Fabio Veras de Souza, Mr. Eugênio Tiago Chagas Cordeiro e Teixeira, and Mr. Newton de
Araujo Lopes have been serving as external members of our Audit Committee. On July 29, 2024, Mr.
Jerônimo Antunes was appointed by our Board of Directors as a Board Member and Chairman of the Audit
Committee, succeeding Mr. Francisco Petros, who had served as Chairman since April 2023. Both Mr.
Jerônimo Antunes and Mr. Newton de Araujo Lopes are recognized as financial experts on our audit
committee.
Our audit committee is responsible for, among other matters:
_ Monitoring, analyzing, and making recommendations to our Board of Directors with respect to the
appointment and dismissal of our independent registered accounting firm, as well as evaluating the
independence of our independent registered accounting firm for issuing an opinion on the financial
statements and their qualifications and expertise.
_ Advising our Board of Directors on the review of our annual and quarterly consolidated financial
statements, monitoring compliance with relevant legal and listing requirements and ensuring
appropriate disclosure of our economic and financial situation filed with the CVM and the SEC.
_ Advising our Board of Directors and our management, in consultation with internal and independent
registered accounting firm and our risk management and internal controls units, in monitoring the
quality and integrity of our internal control over financial reporting systems, our audited
consolidated financial statements and related financial disclosures.
Annual Report and Form 20-F 2024 I 234
Management and
Employees
_ Reviewing and submitting proposals to our Board of Directors relating to the resolution of conflicts
between management and the independent registered accounting firm relating to our audited
consolidated financial statements.
_ Assessing and monitoring, together with our internal management and audit area, the adequacy of
actions to prevent and combat fraud and corruption.
_ Evaluating and monitoring, jointly with our management and our internal auditors, our transactions
with related parties, including a review, at least once a year, of all related party transactions and a
previous analysis of related party transactions involving amounts higher than certain levels.
_ Establishing and reviewing procedures for the receipt, retention and processing of complaints
regarding accounting, internal control and auditing matters, including procedures for the
confidential submission of internal and external complaints relating to the scope of the committee’s
activities, as well as receiving, retaining and processing any such complaints.
_ Evaluating the parameters underlying the actuarial calculations, as well as the actuarial result of the
benefit plans maintained by our social security foundation, Fundação Petrobras de Seguridade
Social.
_ Conducting the formal evaluation of our internal audit executive manager on an annual basis.
With respect to the relationship of our audit committee with our independent registered accounting firm,
as provided in our Bylaws, our Board of Directors is responsible for deciding, among other matters, the
appointment and dismissal of independent registered accounting firm, which are prohibited from providing
consulting services to us during the term of an audit’s contract. Our audit committee has the authority to
recommend pre-approval policies and procedures for the engagement of our independent registered
accounting firm’s services. Our management is required to obtain the audit committee’s pre-approval
before engaging an independent registered accounting firm to provide any audit or permitted non-audit
services to us or any of our consolidated subsidiaries. Our audit committee has pre-approved a detailed list
of audit services up to specified monetary thresholds. The list of pre-approved services is updated from
time to time. The audit services that are not included in the list, or that exceed the thresholds specified
therein must be directly approved by our audit committee. Our audit committee monitors the performance
of the services provided by our independent registered accounting firm and reviews and monitors our
independent registered accounting firm’s independence and objectivity.
Annual Report and Form 20-F 2024 I 235
Management and
Employees
Principal accountant fees and services
The following table sets forth the fees billed to us, in US$ million, by our independent registered
accounting firm KPMG Auditores Independentes Ltda. (PCAOB ID 1124) during the fiscal years ended
December 31, 2024 and 2023:
2024
2023
Audit fees(1)
7.2
5.8
Audit-related fees(2)
0.1
0.2
TOTAL FEES
7.3
6.0
(1)
Audit fees comprise fees billed (including fees for services related to tax review in relation to statutory and regulatory filings) in
connection with the audit of our audited individual and consolidated financial statements (IFRS Accounting Standards and Brazilian GAAP),
interim reviews (IFRS Accounting Standards and Brazilian GAAP), audits of our subsidiaries (IFRS Accounting Standards and Brazilian
GAAP, among others), consent letters and review of periodic documents filed with the SEC.
(2)
Audit-related fees refer to assurance and related services that are reasonably related to the performance of the audit or reviews of our
audited consolidated financial statements and are not reported under “audit fees.”
Annual Report and Form 20-F 2024 I 236
Management and
Employees
Employees
Our workforce is our most important asset. Our management approach is stated in our Human Resources
Policy and is based on Petrobras Values: caring for people, promoting diversity, equity, inclusion in the
countries where we operate, and well-being; integrity, acting ethically, transparently and with coherence
between discourse and practice; sustainability, generating value for the company and its stakeholders with
a long-term vision and commitment to life, the fair energy transition, the environment and society;
innovation, building new paths for the company, overcoming barriers to collaboration, technology, technical
capacity and continuous learning; commitment to Petrobras and the country, working with excellence and
purpose for the development of Petrobras and the country.
Annual Report and Form 20-F 2024 I 237
Management and
Employees
As of December 31,
2024
2023
2022
Our employees by region
(not including our subsidiaries, joint operations or structured entities)
Southeastern Brazil
35,332
34,363
32,985
Northeastern Brazil
4,037
3,478
3,390
Other locations in Brazil
2,409
2,372
2,307
Total
41,778
40,213
38,682
Our subsidiaries’ employees by region
Southeastern Brazil
5,240
4,619
4,596
Northeastern Brazil
746
729
734
Other locations in Brazil
813
568
569
Abroad
608
601
568
Total
7,407
6,517
6,467
TOTAL
49,185
46,730
45,149
We attract and retain talented employees by offering competitive benefits and participation in a variable
compensation program. We also offer as the possibility for professional growth and development based on
performance in addition to monthly compensation.
The table below sets forth the main expenses related to our employees for the last three years:
US$ million
2024
2023
2022
Salaries, accrued vacations and related charges
3,652
3,478
3,006
Employee training(1)
165
94
42
Profit-sharing distributions
464
595
131
Performance award program
468
416
547
(1) Employee training is not considered an employee benefit in our audited consolidated financial statements.
For information regarding profit-sharing distributions and variable compensation program see respectively
“Labor Relations” and “Employees Variable Compensation” in this annual report.
Annual Report and Form 20-F 2024 I 238
Management and
Employees
Workforce
One of the main current and future challenges for our people management is to ensure the continuous
adequacy of our workforce to the business portfolio.
Our workforce planning methodology correlates our strategic projects with our employees‘ needs. It is built
through our business’s processes perspective and considers strategic scenario modifications in the medium
and long terms. It considers operational safety and projects requirements, as well as portfolio management
decisions and organizational restructuring.
In addition, we seek to adapt our current workforce to our strategies through the following: improvement
of internal workforce mobility practices; flexibility for our portfolio management strategy; training and
continuing education related to mobility programs; analysis of impacts and costs; critical thinking;
knowledge management; and improvement of our workforce profile. These programs, which facilitate the
increase of productivity and optimize our processes, also allow us to better adjust our workforce to our
business needs.
Employees are one of the most important intangible assets to us and the ability to attract qualified and
talented employees, as well as retain and nurture internal talent is critical to our success and sustainability.
We focus on attracting the best external talent without neglecting the internal talent of employees, who
have grown with us, and understand our organization, mission and culture.
To address our workforce requirements, we emphasize filling open positions internally through structured
processes for career mobility, aiming to retain talent and minimize external hiring expenses. Subsequently,
we evaluate the number of new hires needed by taking into account our business demands alongside our
existing vacancies. The hiring of new employees is made possible mainly by Public Selection Process (“PSP”)
or direct hiring (the latter essentially for senior management positions). Up to 40% of our total senior
management positions may be filled through direct hiring.
Since 2021, we resumed admissions through PSP in Brazil, paying special attention to diversity, increasing
hiring of people with disabilities and for Black people.
As a result, in 2024, 2,009 professionals were hired, of which 95.7% were hired through the PSP, including 92
employees with disabilities, 876 Black people, and 424 women among all new employees.
In addition to new hires, our headcount was impacted by the layoff of employees enrolled in new iterations
of the Voluntary Severance Programs (the “PDV”) that were introduced throughout 2019. In 2024, 141
employees left us through the Incentive Retirement Program.
In total, 444 employees left us in 2024, of which 333 were voluntary dismissals (includes PDVs and other
types of dismissals).
Annual Report and Form 20-F 2024 I 239
Management and
Employees
OUR TURNOVER (not including our subsidiaries, joint operations or structured entities)
The employees that were hired in 2024 support our current Strategic Plan and enable workforce renewal.
We believe that our growth helps ensure competitive advantage and value to our business, in terms of
knowledge and talent management.
Hiring new employees through the PSP and the dismissals contributed to a slight change in the range
distribution of our workforce by time spent with us, as well as the age pyramid.
TIME IN PETROBRAS (not including our subsidiaries, joint operations or structured entities) (%)
Annual Report and Form 20-F 2024 I 240
Management and
Employees
Labor Relations
We respect the freedom of association and recognize the right to collective bargaining, as recommended
by United Nations Global Pact. This commitment is reinforced by our Human Resources Policy, which
determines the implementation of sustainable agreements built through dialogue, ethics and transparency
with employee representatives, and by our Code of Ethical Conduct which ensures freedom of association.
We also follow and encourage the International Labor Organization Constitution and Conventions ratified
by Brazil.
According to Brazilian legislation, all of our employees are represented by independent unions. We maintain
relationships with 17 trade unions and two federations (i.e., a top-level union entity) of oil workers, as well
as five unions and one federation of maritime workers. We value our relationships with all our stakeholders.
For this reason, we invest in open and permanent dialogue with trade unions. As of December 31, 2024, 39%
of our employees were unionized.
We have a Collective Bargaining Agreement (“CBA 2023-2025”) with the oil and maritime trade unions, valid
for two years, until 2025. These agreements include economic and social provisions relating to work, safety
conditions, benefits, and other matters.
Our agreements seek to be aligned with the UN Sustainable Development Goals, contributing mainly to
decent work and gender equality.
Currently, 100% of our employees are covered by Collective Bargaining Agreements.
In 2024, we adjusted the salaries and benefits of oil and maritime employees by 1% above inflation,
according to the conditions negotiated and established in the CBA 2023-2025.
We also have a Profit-Sharing Program (PLR) Agreement valid for 2024/2025, which determines the rules
regarding profit sharing payment.
Another right defined in Brazilian legislation is the power of employees to embrace their causes and
promote strikes under the principles defined by law. We respect the right to strike, but we maintain our
activities in full operation using contingency plans. Contingency plans are the way we can deal with several
types of situations by being backup plans for operational continuity and safety we can use in case of
unexpected situations.
Benefits
Employees Variable Compensation
We adopt a compensation policy in line with market practices in which we operate.
The variable remuneration model for our employees is made up of the PLR, a legal requirement and our
main variable remuneration practice, and the Accomplishment Award (the “PRD”), which complements the
PLR. The PRD was implemented in 2023 to replace the Performance Award Program (the “PPP”), which was
maintained only for members of our Executive Board (Officers). While the PLR only considers organizational
performance, the PRD and PPP consider the employee's individual performance as well. These programs are
aligned with the new guidelines of the Strategic Plan 2050 and Business Plan 2025-29 and our remuneration
policy.
Annual Report and Form 20-F 2024 I 241
Management and
Employees
PLR
In the 2024 fiscal year, we approved the PLR Agreement for all employees, regardless of their position,
except for members of our Executive Board, and it became our main variable remuneration program.
The payment of the 2024 PLR, which shall occur in 2025, is conditioned upon the satisfaction of the following
conditions:
_ declaration and payment of shareholder remuneration, for such fiscal year, approved by our Board
of Directors;
_ obtainment of net income for such fiscal year; and
_ achievement of an average percentage (weighted) of at least 80% for target indicators established
by the Board of Directors.
In 2024, we provisioned US$464 million for the 2024 PLR.
PPP AND PRD
The PPP (for members of the Executive Board) and PRD (for all other employees) are programs that seek to
recognize the individual effort and performance of employees in achieving our results.
As our 2024 results met all the minimum prerequisites established for this year, we provisioned US$468
million to our employees in relation to the PRD for 2024, since the metrics relating to the company and
individual performances were achieved.
The 2024 fiscal year PRD and PPP will be paid after the results for the year have been calculated, provided
that the following conditions established by the programs are met:
_ declaration and payment of dividends to our shareholders, for such fiscal year, approved by our
Board of Directors; and
_ obtaining net income for the year.
Additionally, the organizational unit scorecards continue to be considered as input for the evaluation of all
employees, which are reflected in the calculation of their variable compensation, and include the following
items: (i) the results of our main metrics such as Delta Valor Petrobras (which measures our economic and
financial performance based on the value generated by our activities in a given year), the Indicator of
Compliance with Greenhouse Gas Emissions Targets (IAGEE) and the Indicator of Commitment to the
Environment (ICMA), represented by the Volume of Oil and Oil Products Spilled (VAZO); and (ii) the scores
of specific metrics of each executive scorecard (represented by specific indicators and strategic initiatives
that address economic, environmental and social factors). The higher the hierarchical level, the greater the
weight of the main metrics and, therefore, the multiple remunerations associated with the award reflect the
greater degree of responsibility of the manager in relation to the metrics of his/her area and our
performance metrics.
For members of the Executive Board that are eligible for PPP and for members of our Management eligible
for PRD, as approved by our Board of Directors and SEST, the variable compensation payments must be
deferred over five years as a long-term incentive. The value of such payments is based on the market value
of our shares without factoring in any option to buy our shares. Consequently, payments to the members
of our Executive Board and Management must be carried out as follows:
_ a portion of the PPP or PRD, as applicable, is paid upfront, while the balance is settled in four annual
installments. These deferred installments are converted into phantom shares (PETR3) based on the
weighted average of the share prices over the last 60 trading sessions of the reference year.
Annual Report and Form 20-F 2024 I 242
Management and
Employees
_ the ratio between the upfront payment and the deferred amount varies according to the hierarchical
level of the participant, with higher deferment percentages for higher levels in the hierarchy.
_ for the Executive Board, comprising the President and Directors, 60% of the PPP value is paid
upfront, and 40% is deferred, being settled in four annual installments. For Executive Managers and
General Managers, the PRD ratio is 70% and 80% paid upfront, respectively, while the remaining
balance (30% and 20%, respectively) is also settled in four annual installments, converted into
phantom shares (PETR3) using the same calculation basis.
_ the members of our Executive Board and Management may exercise the right to receive deferred
installments after the established grace periods have been fulfilled.
_ the value of each installment must be equivalent to the conversion of phantom shares into cash
value based on the weighted average of our common shares during the last 20 trading sessions prior
to the request date.
_ for other employees, the payment is made exclusively upfront, upon approval by the Executive
Board. The payment is also conditioned on the approval, by the Board of Directors, of the metrics
measured by the Performance area following the performance evaluation process for the respective
fiscal year.
Main Benefits Granted to Employees
We offer benefits that are commensurate with our size and seek to value our employees. All of our
employees are entitled to the same benefits, regardless of their positions or duties. There are no
differences between the benefit plans of the highest governance body, senior executives and all other
employees. We offer complementary pension plans, medical assistance and pharmacy benefits. In addition,
some of our consolidated subsidiaries have their own benefit plans.
PENSION PLANS
We sponsor six post-employment benefit plans, managed by Petros, with pension characteristics:
_ Plano Petros do Sistema Petrobras Renegotiated (the “PPSP-R”) – Defined Benefit type, closed to
new members.
_ Plano Petros do Sistema Petrobras Not Renegotiated (the “PPSP-NR”) – Defined Benefit type, closed
to new members.
_ Plano Petros do Sistema Petrobras Renegotiated Pré-70– Defined Benefit type, closed to new
members.
_ Plano Petros do Sistema Petrobras Not Renegotiated Pré-70– Defined Benefit type, closed to new
members.
_ Plano Petros -2 (the “PP-2”) – Variable Contribution type, open to new members.
_ Plano Petros-3 (the “PP-3”) – Defined Contribution type, closed to new members.
Together, these plans cover 96% of our employees, considering that only one plan (PP-2) is currently open
to new members with optional membership.
The main purpose of our pension plans is to supplement the social security pension benefits of our retired
employees. Thus, our employees make mandatory monthly contributions as participants of our plans, and
we do the same as sponsors.
Annual Report and Form 20-F 2024 I 243
Management and
Employees
In order to address the history of actuarial insufficiencies that occurred in past years and seek actuarial
rebalancing, currently, the PPSP-R and PPSP-NR plans sponsored by us have equalization plans (DEPs -
Deficit Equalization Plans) in progress. This means the administration of extraordinary contributions that
are added to the normal contributions of their funding plans.
Thus, PPSP-R includes DEP2018 and DEP2021, while PPSP-NR includes DEP2018 and DEP2022 in their
funding plans. All are composed of lifelong and equal extraordinary contributions (50%/50%) between the
Sponsors and the Participants and Beneficiaries.
The remaining balance related to Petrobras to be settled by the extraordinary contributions contracted
through the entirety of these DEPs in the PPSP-R and PPSP-NR plans was US$3.3 billion as of December 31,
2024, as recorded in Petros Plans’ balance sheets at present value.
For more information on the Deficit Equalization Plans, see Note 18.3 to our audited consolidated financial
statements.
The table below presents the benefits paid, contributions made, and outstanding pension liabilities for the
years ended December 31, 2024, 2023, and 2022:
US$ million
2024
2023
2022
Total benefits paid – pension plans
1,432
1,639
1,539
Total contributions – pension plans(1)
757
746
1,945
Net actuarial liabilities(2)
3,900
6,720
5,433
(1)
Contributions of sponsors, including defined contributions recognized in the statement of income (PP-2 and PP-3).
(2)
Unfunded pension plans obligations.
For more information on the Petros plan, see “Risks – Risk Factors” in this annual report and Notes 4.4 and
18 to our audited consolidated financial statements.
HEALTH AND PHARMACY BENEFIT PLAN
We offer a supplementary health care plan, the “AMS”, which provides for medical, hospital and dental care
services to all active and retired employees and their dependents. In 2024, we paid 70% of the health care
costs and our employees (active and retired) paid 30%.
An independent actuary consultant calculates our commitment related to future benefits for plan
participants on an annual basis, based on the projected unit credit method. The health care plan is not
funded or otherwise collateralized by assets. Instead, we make benefit payments based on annual costs
incurred by plan participants.
The benefit also offers coverage of complementary programs, such as the Benefício Farmácia program. This
program only covers drugs with a unit cost over R$150 and drugs of any value used in the treatment of
certain non-transmissible chronic diseases. By choosing to use the Benefício Farmácia, the beneficiary must
incur costs as determined by the co-participation system.
The table below shows the post-employment benefits paid and outstanding medical liabilities for the years
ended December 31, 2024, 2023 and 2022:
Annual Report and Form 20-F 2024 I 244
Management and
Employees
US$ million
2024
2023
2022
Total benefits paid – medical plan(1)
488
413
384
Net actuarial liabilities(2)
7,498
9,662
5,813
(1)
Composed of Saúde Petrobras and Benefício Farmácia amounts.
(2)
Unfunded medical plan obligations.
For more information on our employee benefits, see Notes 4.4 and 18 to our audited consolidated financial
statements and “Risks – Risk Factors” in this annual report.
Compliance and Internal
Controls
Annual Report and Form 20-F 2024 I 246
Compliance and Internal
Controls
Compliance
Ethical principles guide our business and our relations with third parties. Our activities follow clearly
articulated policies, guidelines, standards, and procedures that have been formally established by us. These
policies and procedures are communicated to all employees and accessible from any company device, with
our main corporate policies also available on our website.
Our activities are subject to national and international laws aimed at preventing fraud and corruption,
money laundering, trade sanctions, conflicts of interest, antitrust violations, discrimination, moral
harassment and sexual violence, such as the Brazilian Anti-Corruption Law (Law 12,846/13), the U.S. Foreign
Corrupt Practices Act (FCPA), and the UK Bribery Act.
In addition, we continually work to strengthen our Integrity System. We have our Code of Ethical Conduct
that provides guidance on the behavior that we require from our workforce and counterparties and tools
for self-reflection to help employees to comply with our ethical principles while performing their duties.
In order to further integrate and strengthen our Integrity System, we highlight our corporate Compliance
Policy, the Ethical Conduct Guide for Suppliers and our Compliance Program.
Also, our Competitive Compliance Policy guides our workforce on the rules that regulate free competition
in order to prevent and mitigate violations of Law No. 12,529/2011 (the Competition Defense Law) and
provide mechanisms to detect and address any instances of anticompetitive practices.
To ensure an ethical environment for our business, we work: (i) to promote the principle of integrity in our
corporate culture; (ii) to prevent, detect and correct incidents of fraud, corruption, conflicts of interest,
money laundering, harassment and discrimination; and (iii) to manage our internal controls.
In July 2024, we joined the “Brazil Pact for Corporate Integrity,” an initiative of the Controladoria Geral da
União (CGU or General Federal Comptroller), which aims to promote integrity in the Brazilian corporate
environment and encourage companies to voluntarily commit to corporate integrity. We achieved the
highest score in the self-assessment of integrity measures, taking into account a set of actions aimed at: (i)
preventing, detecting, and addressing deviations, fraud, and acts of corruption against the public
administration; (ii) mitigating social and environmental risks arising from our activities, ensuring the
protection of human rights; and (iii) fostering and maintaining a culture of integrity within the
organizational environment.
We offer training for all our employees, particularly employees working on activities with greater exposure
to compliance risks, as well as the members of our Executive Officers and our Board of Directors.
In 2024, we launched an e-learning course on Petrobras Values. The course aims to provide Petrobras
employees a deep understanding of the company's new values, highlighting their importance in the
organizational culture and their impact on our daily operations, in order to encourage the practice of these
values in the workplace. This training is available to the entire workforce and is mandatory for all company
employees.
This e-learning course reinforces our commitment to promoting a work culture based on high principles of
ethical conduct and on our followings corporate values: Care for People, Integrity, Sustainability, Innovation
and Commitment to Petrobras and the Country. As of February 10, 2025, 41,081 employees, representing
98.3% of our own personnel, completed this e-learning course.
In 2024, we also provided training sessions to directors and executive officers, covering mainly the following
topics:
Annual Report and Form 20-F 2024 I 247
Compliance and Internal
Controls
_
Code of Ethical Conduct;
_
Our corporate governance and decision-making process;
_
Brazilian anti-corruption law;
_
Compliance, internal controls and related party transactions;
_
Disclosure of Information to the Market, Information and Securities Trading including blackout
period; and
_
Risk management.
Code of Ethical Conduct
Our Code of Ethical Conduct (“Our Code”) defines the ethical principles that guide our actions, explaining
the ethical sense of our mission, our vision, and our Strategic Plan.
This document, as a corporate policy, undergoes periodic reviews. In 2024, we conducted a comprehensive
review of Our Code, seeking to align it with Petrobras’ values. Our Code guides the company’s behavior and
actions, and it is expected that the conducts described in Our Code should concretely reflect the expression
of these values in the workplace.
To conduct this review, we considered the following strategic drivers:
_ Collaborative Methods: We involved Petrobras’ workforce to create a document that reflects their
realities and concerns.
_ Coverage and Applicability: We ensured that the document is applicable to Petrobras and its
subsidiaries, including members of the Board of Directors and its Advisory Committees, the Fiscal
Council, the Executive Board, employees, interns, young trainees, and service providers.
Our Code of Ethical Conduct is aligned with the best corporate integrity practices and represents another
step towards strengthening the principle of integrity in our corporate culture.
Our Code of Ethical Conduct is available on our website.
Compliance Policy
The purpose of the Compliance Policy is to ensure that we comply with the laws and rules of regulatory
bodies, acting to correct and prevent misconduct.
The six principles that guide our compliance actions are:
_ All our activities and relations with our stakeholders must be based on ethics, integrity, and
transparency, in compliance with the applicable national and international standards, to provide a
safe environment for decision making.
_ Our priority is the active prevention of any violations of rules and regulations in order to mitigate
compliance risks.
_ All indications of misconduct and harmful actions must be investigated, and measures shall be
adopted for the immediate interruption and repair of any damage to us, and proportional
consequences will be imposed on those responsible.
_ Retaliation against whistleblowers is forbidden, we ensure privacy, confidentiality, and institutional
protection to such persons.
Annual Report and Form 20-F 2024 I 248
Compliance and Internal
Controls
_ Our directors and managers are responsible for supporting the development and improvement of
our culture of integrity.
_ We must encourage an increasingly ethical business environment with integrity and transparency,
setting a positive example for our stakeholders.
Ethical Conduct Guide for Suppliers
Our Ethical Conduct Guide for Suppliers is the first document exclusively aimed at our suppliers, with
guidelines on expected values and ethical behavior. It applies to all suppliers, in Brazil or abroad, that are
involved in business processes and have signed contracts, agreements and terms of cooperation with us. It
was elaborated in accordance with the best international practices and is aligned with the guidelines of the
Dow Jones Sustainability Index, the B3 Corporate Sustainability Index and the Corporate Human Rights
Benchmark.
The document also reinforces that suppliers must promote decent and safe working conditions for their
employees, prevent and combat moral and sexual harassment and discrimination, combat child and slavery
labor and respect the environment. Additionally, it determines that suppliers must promote diversity,
gender and racial equality and the inclusion of people with disabilities. This Ethical Conduct Guide
consolidates ethical guidelines applicable to suppliers in a single document.
The observance of this Ethical Conduct Guide by all suppliers is crucial for us to achieve our goals in an
ethical and transparent way and is aligned with our ESG standards. Therefore, we evaluate suppliers’
compliance through the performance management system, as reinforced in our Quality Guide for Suppliers
which can be found at https://canalfornecedor.petrobras.com.br/en.
Petrobras Compliance Program
The Petrobras Compliance Program is a set of mechanisms intended to prevent, detect and remedy any
misconduct and harmful acts carried out against us, including acts related to fraud and corruption, money
laundering, moral and sexual harassment, discrimination and conflicts of interest and antitrust violations.
The Governance and Compliance Officer is responsible for both the Petrobras Compliance Program and our
integrity practices.
The Petrobras Compliance Program is intended for our various stakeholders, including senior management,
employees, subsidiaries and affiliates, clients, suppliers, investors, partners, public authorities and all those
who relate with or represent our interests in our operations.
Ethics Commission
Our ethics commission acts as a forum for discussion of subjects related to ethics. It also serves in an
advisory capacity to our management and workforce, providing recommendations with respect to topics
related to ethics management issues, proposing rules for the incorporation of new concepts, and adopting
measures to comply with legislation and following best practices that reinforce our zero-tolerance
approach to acts of misconduct.
Our ethics commission is composed of employees appointed after an internal selection process consisting
of background checks and interviews. Our Board of Directors and our Executive Officers approve each new
appointment.
Annual Report and Form 20-F 2024 I 249
Compliance and Internal
Controls
Anti-Money Laundering and Sanctions
Our Guidelines for the Anti-Money Laundering and Sanctions, as approved by our Chief Governance &
Compliance Officer, are composed of specific requirements to minimize the risk of money laundering and
violations of sanctions regulations.
The principles that guide our sanctions policy are:
_
Before initiating a transaction, our organizational areas should screen the counterparty against the
Sanctions List made available by Compliance.
_
If the organizational area identifies that the intended counterparty is sanctioned, Compliance must
be consulted regarding the applicability and restrictions of the sanction before moving forward with
the transaction. Compliance with the support of our Legal department, advises the area on how to
proceed.
_
Training and tools are made available to organizational areas to ensure compliance with applicable
sanctions regulations.
_
Members of our senior management, managers and workforce must report irregularities related to
money laundering and sanctions violations through our whistleblower channel.
_
We monitor transactions more exposed to risk of money laundering or sanctions and take
appropriate measures when needed.
Below is the list of sanctions we and our subsidiaries must observe:
Country
Organization
List
United States
Trade Department
Consolidated Screening List
Office of Foreign Assets Control
Non-SDN – Non-Specially Designated
Nationals
Office of Foreign Assets Control
SDN – Specially Designated Nationals
System for Award Management
Excluded Parties List
European Union
European External Action Service
Consolidated List of Persons, Groups and
Entities Subject to EU Financial Sanctions
United Nations
United Nations Security Council
United Nations Security Council Consolidated
List
World Bank
World Bank
Debarred & Cross-Debarred Firms &
Individuals / Other Sanctions
United Kingdom
Office of Financial Sanctions
Implementation
Consolidated List of Financial Sanction
Targets
Canada
Global Affairs Canada
Consolidated Canadian Autonomous
Sanctions List
France
Direction Générale du Trésor
Liste Unique de Gels de la Direction Générale
du Trésor
Switzerland
State Secretariat for Economic Affairs –
SECO
Sanctions de la Suisse
United Arab Emirates
The Committee for Goods and Materials
Subject to Import and Export – CGMSIEC
UAE National List of Terrorist Individuals and
Entities
Annual Report and Form 20-F 2024 I 250
Compliance and Internal
Controls
Insider Trading Policies
We have adopted insider trading policies and procedures governing the purchase, sale and other disposition
of our securities by directors, senior officers and employees that are reasonably designed to promote
compliance with applicable insider trading laws, rules and regulations and the listing standards applicable
to us. See Exhibit 11.1 to this annual report for a copy of our Policy on the Disclosure of Material Act or Fact
and Securities Trading.
Annual Report and Form 20-F 2024 I 251
Compliance and Internal
Controls
Related Party Transactions
We aim to foster transparency in our procedures and conduct better corporate governance practices. Our
Policy for Related Parties Transaction also aims to guarantee the adequate and diligent decision-making
process by our management, observing market conditions or appropriate compensatory payment, in the
event of potential conflicts of interest.
Some transactions with related parties must be previously analyzed by our audit committee when they meet
certain criteria set out in our policy.
Our policy provides for a strict governance procedure for proposed transactions directly or indirectly
involving our controlling shareholder. In the specific case of transactions with related parties to be
approved by our Board of Directors, involving the Federal government, its autarchies, foundations and
federal state-owned companies, when classified as outside the ordinary course of business by our Audit
Committee the following procedures apply: (i) such transactions must be analyzed by the Audit Committee
and by the Minority Committee prior to submission to our Board of Directors, and (ii) such transactions must
be approved by two-thirds of the members attending our Board of Directors meeting.
Our current Policy for Related Parties Transaction was approved in July 2024.
For additional information regarding our outstanding related party transactions as of and for the year-
ended December 31, 2024, see Note 34 to our audited consolidated financial statements.
Transactions with our Board of Directors or Executive Officers
Direct transactions with the companies of members of our Board of Directors or our executive officers must
follow the conditions of a commercial transaction and market practice guiding transactions with third
parties. None of our Board of Directors members, our executive officers or close members of their families
has had any direct interest in any transaction we performed that is or was unusual in its nature or conditions,
or material to our business during the year, and which remains in any way outstanding or unperformed.
From the preceding financial year until February 28, 2025, we have not entered into any transaction with the
companies of members of our Board of Directors or our executive officers. We have no outstanding loans
or guarantees to the members of our board of directors, executive officers, key management personnel or
any close member of their families.
For a description of the shares beneficially held by the members of our board of directors and close
members of their families, see “Management and Employees – Management – Additional Information on
our Board of Directors and Executive Officers – Share Ownership” in this annual report.
Annual Report and Form 20-F 2024 I 252
Compliance and Internal
Controls
Transactions with the Brazilian Federal Government
We have engaged, and expect to continue to engage, in the ordinary course of business in numerous
transactions with our controlling shareholder, the Brazilian federal government, and with banks and other
entities under its control, including financing and banking, asset management and other transactions.
These transactions resulted in a US$13,379 million asset and a US$3,885 million liability with the Brazilian
federal government and other entities under its control as of December 31, 2024.
On November 30, 2020, there was a final decision in relation to the Petroleum and Alcohol Account lawsuit
filed in 2011. On June 26, 2024, we received the second and final installment of the judicialized debts with
the Brazilian Federal Government (precatórios), arising from the Petroleum and Alcohol Account. We
immediately deposited this amount as a guarantee in a tax lawsuit. The deposit amounts to US$224 million
as of December 31, 2024.
In addition, we are allowed to invest in securities issued by the Brazilian federal government, provided that
the legal and regulatory requirements are met and we have taken into consideration market’s best practices
and the conservatism that should guide our investments.
As of December 31, 2024, the balance of securities issued by the Brazilian federal government that have
been directly acquired and held by us amounted to US$1,114 million.
For further information on related party transactions, see Note 34 to our audited consolidated financial
statements.
Annual Report and Form 20-F 2024 I 253
Compliance and Internal
Controls
Controls and Procedures
Disclosure Controls and Procedures
We, together with our CEO and CFO, have evaluated the effectiveness of our disclosure controls and
procedures as of December 31, 2024. Our CEO and CFO concluded that our disclosure controls and
procedures were effective to provide reasonable assurance that the information we are required to disclose
in the reports that we file or submit under the Exchange Act was being recorded, processed, summarized
and reported within the time periods specified in the applicable rules and forms. They also concluded that
such disclosure was compiled for and communicated to our management, including our CEO and CFO, as
appropriate, to allow for timely decisions regarding the required disclosure.
Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing, adequately maintaining and assessing the effectiveness
of internal control over financial reporting. Such internal control is a process designed by, or under the
supervision of our CEO and CFO, and effected by our board of directors, management and other employees.
The internal control over financial reporting is designed to provide reasonable assurances regarding the
reliability of financial reporting and of the preparation of our consolidated financial statements for external
purposes, in accordance with IFRS Accounting Standards, as issued by the IASB.
Due to its inherent limitations, internal control over financial reporting may not prevent or detect
misstatements. In addition, projections of any evaluation of effectiveness of internal control over financial
reporting to future periods are subject to the risk of becoming inadequate because of changes in its
conditions and assumptions.
Our management has assessed the effectiveness of our internal control over financial reporting as of
December 31, 2024 based on the criteria established in “Internal Controls – Integrated Framework (2013)”
issued by the Committee of Sponsoring Organizations of Treadway Commission (COSO). Our management
has concluded that our internal control over financial reporting was effective.
Audit of the Effectiveness of Internal Control over Financial Reporting
Our independent registered accounting firm has audited the effectiveness of our internal control over
financial reporting as of December 31, 2024, as stated in their report, which is included herein.
Changes in Internal Control over Financial Reporting
There were no significant changes in our internal control over financial reporting during the year ended
December 31, 2024 that have materially affected, or are reasonably likely to materially affect, our internal
control over financial reporting.
Annual Report and Form 20-F 2024 I 254
Compliance and Internal
Controls
Ombudsman and Internal Investigations
Our general ombudsman office provides channels for receiving comments from our internal and external
audience, such as claims, requests for information, general requests, suggestions, compliments and
complaints, including reports of discrimination and all kinds of harassment.
In order to receive complaints, we provide a specific whistleblower channel, operated by an independent
external company, and allowing for anonymity of the informants.
All complaints received through the whistleblower channel are forwarded to the ombudsman’s office, which
analyzes, classifies, and directs them to the relevant office for follow-up. Allegations regarding compliance
issues (fraud, corruption and other matters) and violence in the workplace (sexual violence, moral
harassment, discrimination and retaliation) are sent to the governance and compliance office, which has full
access, independence, qualification and autonomy to thoroughly investigate allegations of this nature.
Upon the conclusion of each investigation, we use any material findings to improve our compliance efforts.
If any finding indicates that a current or former employee did not comply with certain internal policy, the
matter is forwarded to Internal Affairs, responsible for conducting disciplinary processes. The result of the
process is submitted to the Integrity Committee for decision, a collegial body that acts independently and
reports to the Board of Directors, and appropriate disciplinary measures and remedial actions may apply
(according with applicable labor laws and internal policies).
We continue to allocate significant resources to investigating allegations of misconduct and responding
appropriately to investigative findings, and to improve our internal investigation procedures to ensure that
investigations are conducted completely and efficiently and that disciplinary measures are imposed fairly,
uniformly and promptly. We remain cooperative with the authorities, in an effort to uncover wrongdoing
and hold those responsible accountable.
Irrespective of the findings of our internal investigations, in order to mitigate potential risks of further non-
compliance with our internal policies, we continue to develop and implement measures aimed at improving
corporate governance, including those related to fraud and corruption.
Shareholder Information
Annual Report and Form 20-F 2024 I 256
Shareholder Information
Listing
Corporate Governance of B3 – Level 2
We are listed in the corporate governance Level 2 listing segment of the B3.
Below are some of our corporate governance practices due to our listing on the Level 2 listing segment:
_ the roles of our minority committee are expanded;
_ our Board of Directors is composed of at least 40% independent members;
_ we disclose an annual calendar of corporate events;
_ we must assure 100% of tag along to holders of our preferred shares – under the same conditions
granted to holders of our common shares; and
_ our bylaws provide for arbitration as the dispute resolution method.
For more information about our corporate governance practices, see “Environment, Social and
Governance – Corporate Governance” in this annual report.
Annual Report and Form 20-F 2024 I 257
Shareholder Information
Shares and Shareholders
Our capital stock is composed of common and preferred shares, all without par value and denominated in
reais. Under Brazilian Corporate Law, the number of our preferred shares may not exceed two-thirds of the
total number of our shares.
Our shares are negotiated on the B3 and registered in book-entry form. Banco Bradesco performs services
of safekeeping and transfer of shares.
Holders of our common shares are entitled to one voting right for each unit of common shares held. Holders
of our preferred shares are not entitled to voting rights, except for: (i) the right to appoint one member of
our Board of Directors and one member of our Fiscal Council; and (ii) certain matters relating to preferred
shares (such as creation, increasing, changes in the preferences or creation of a new class), whenever rights
of holders of preferred shares are adversely affected.
In the U.S., our common or preferred shares, which are evidenced by ADRs, are listed in the form of ADSs on
the NYSE. The ADSs are registered and delivered by a depositary bank (JPMorgan) which, since January 2,
2020, acts as the depositary for both of our common and preferred ADSs. The ratio of ADR to our common
and preferred shares is two shares to one ADR.
The rights of ADS holders differ from shareholders’ rights. With respect to voting rights, ADS holders may
only vote by means of proxy voting cards mailed to the ADR depositary bank while shareholders have the
right to vote directly at the shareholders’ meeting.
On December 31, 2024, there were 2,068,948,618 outstanding common shares and 648,769,072 outstanding
preferred shares represented by ADSs. There has been no change in the past five fiscal years in the amount
of our issued share capital, as well as in the number of our common and preferred shares or in the voting
rights of our common and preferred shares. On January 29, 2025, our Board of Directors approved the
cancellation of 222,760 common shares and 155,541,409 preferred shares held in treasury, some of which
were the result of the share repurchase program ended in 2024, and others which predate the program. See
Exhibit 1.1 to this annual report for a copy of our Bylaws.
For more information on the share repurchase program, see “Purchases of equity securities by the issuer
and affiliated purchasers” in this annual report.
Additionally, our common (XPBR) and preferred (XPBRA) shares have been traded on the LATIBEX, Spain,
since 2002 under ISIN codes BRPETRACNOR9 and BRPETRACNPR6, respectively. The LATIBEX is an
electronic market created in 1999 by the Madrid Stock Exchange in order to enable trading of Euro-
denominated Latin American equity securities.
In the beginning of 2025, our stock value1F increased, and as of February 28, 2025, our stock price was
US$13.35 (PBR) and US$12.21 (PBR/A). In both 2023 and 2024, our stock outperformed IBOV at B3 and ARCA
Oil (formerly AMEXOIL) at NYSE. In 2022, our stock outperformed IBOV at B3 and underperformed ARCA Oil
(formerly AMEXOIL) at NYSE.
2
Annual Report and Form 20-F 2024 I 258
Shareholder Information
Annual Report and Form 20-F 2024 I 259
Shareholder Information
The following table sets forth information concerning the ownership of our common and preferred shares
as of February 28, 2025, by the Brazilian federal government and certain public sector entities:
Shareholders
Common
Shares
%
Preferred
Shares
%
Total Shares
%
Brazilian federal government
3,740,470,811
50.26
—
—
3,740,470,811
29.02
BNDES
—
—
135,248,258
2.48
135,248,258
1.05
BNDES Participações S.A. –
BNDESPar
—
—
900,210,496
16.53
900,210,496
6.98
All members of our Board of
Directors, Executive Officers
and Fiscal Council(1)
223,281,537
3.00
86,793
0.00
223,368,330
1.73
Others
3,478,479,034
46.74
4,410,955,832
80.99
7,889,434,866
61.21
TOTAL(2)
7,442,231,382
100
5,446,501,379
100
12,888,732,761
100
(1)
Considers CVM criteria which includes the shares owned by a spouse from whom they are not legally or extrajudicially separated, a marriage partner, any
dependents included in their annual income tax return and companies directly or indirectly controlled by them. It also includes the position held by alternate
members of the Fiscal Council. It does not include the position held by external members of the Board of Directors' Advisory Committees.4F
(2)
New total of shares, considering the cancellation of 222,760 common shares and 155,541,409 preferred shares approved by the Board of Directors on
January 29, 2025.
For detailed information on the shares held by the members of our Board of Directors, Executive Officers
and members of our Fiscal Council, see “Management and Employees” in this annual report.
Under Brazilian Corporate Law and Law No. 13,303/16, the Brazilian federal government is required to own
at least a majority of our voting shares.
Although the Brazilian federal government does not have different voting rights than our other
shareholders, it is required by law to hold a majority of our voting share. As a result, any change in our
control would require a change in applicable laws. Our Bylaws also provide for rules applicable to a potential
transfer of control of our major shareholders.
The majority of our voting shares also gives the Brazilian federal government the right to elect a majority
of our directors, regardless of the rights our minority shareholders may have to such election according to
our Bylaws.
Additionally, our Bylaws clearly state that we may have our activities guided by the Brazilian federal
government in order to contribute to the public interest that justified our creation. However, if the Brazilian
federal government’s guidelines lead us to undertake obligations and responsibilities under conditions
different from those of any other company in the private sector that operates in the same market, such
obligations and responsibilities shall be defined in law or regulation and shall have their costs and revenues
broken down and disclosed. In addition, the Brazilian federal government shall compensate us, at each fiscal
year, for the difference between market conditions and the operational result or economic return from such
obligation.
Our shareholding base includes over 1,000,000 shareholders at the B3 and ADR accounts at the NYSE.
Annual Report and Form 20-F 2024 I 260
Shareholder Information
TOTAL CAPITAL(1) (%)
NON-VOTING CAPITAL(1) (%)
VOTING CAPITAL(1) (%)
(1)
Information about our shareholders as of February 28, 2025.
Pursuant to CVM rules, any (i) direct or indirect controlling shareholder, (ii) shareholder who has elected
members of a Brazilian public company’s Board of Directors or Fiscal Council, and (iii) person or group of
persons representing the same interest, in each case that has directly or indirectly acquired or sold an
interest that exceeds (either upward or downward) the threshold of 5%, or any multiple thereof, of the total
number of shares of any type or class, must be disclosed by such Brazilian public company, immediately
after the acquisition or sale of shares, to the CVM and the B3.
The majority of our voting
rights
is
held
by
the
Brazilian
federal
government, which holds
50.26% of our shares with
voting rights.
Annual Report and Form 20-F 2024 I 261
Shareholder Information
Purchases of equity securities by the issuer and affiliated
purchasers
A share repurchase program covering preferred shares was approved by the Board of Directors on
August 3, 2023. The program was carried out in the context of the current Shareholder Remuneration
Policy, which was amended and was approved by the Board of Directors on July 28, 2023, providing the
possibility of repurchasing shares as a way to remunerate our shareholders.
During the fiscal year ended December 31, 2024, we repurchased our equity securities. Our share
repurchase program was completed in August 2024. The total amount repurchased by the company was
155,468,500 preferred shares, a volume equivalent to approximately 3.5% of the total preferred shares
held by unaffiliated shareholders (free float shares). The cancellation of treasury shares was approved
by our Board of Directors on January 29, 2025, without reducing the share capital.
Period
Total
number of
preferred
shares
purchased
Average
price
paid per
preferred
share
Total number of
preferred shares
purchased as part of
publicly announced
plans or programs(1)
Maximum number (or
approximate dollar
value) of shares that
could be purchased
under the plans or
programs
September 2023
28,735,700
6.87
28,735,700
129,081,247
October 2023
27,596,600
7.03
27,596,600
101,484,647
November 2023
17,479,900
7.27
17,479,900
84,004,747
December 2023
30,251,800
7.16
30,251,800
53,752,947
January 2024
15,171,400
7.81
15,171,400
38,581,547
March 2024
15,678,200
7.25
15,678,200
22,903,347
April 2024
383,000
7.38
383,000
22,520,347
May 2024
13,012,500
7.24
13,012,500
9,507,847
June 2024
7,159,400
7.25
7,159,400
2,348,447
TOTAL
155,468,500
7.18
155,468,500
2,348,447
(1) On August 3, 2023, our Board of Directors approved a share repurchase program, with a maximum term of 12 months (beginning on August
4, 2023 and ending on August 4, 2024), limited to 7F157,816,947.
8F
Self-Dealing Restrictions
In accordance with our Disclosure of Material Act or Fact and Securities Trading Policy, the use of material
information not yet disclosed, by any person who has had access to it, for the purpose of gaining advantage,
for himself or for others, through trading in securities, is prohibited.
CVM Resolution No. 44/21, individually or combined, considers the following situations when characterizing
the use of material information not yet disclosed, by any person who has had access to it, for the purpose
of gaining advantage, for himself or for others, through trading in securities, as illicit act ("Insider
Information"):
Annual Report and Form 20-F 2024 I 262
Shareholder Information
_ I – the person who traded securities has material information not yet disclosed and uses such
information in said trading;
_ II – direct or indirect controlling shareholders, directors, members of the board of directors and the
fiscal council, and the company itself with access to all material information not yet disclosed and
trades securities issued by the company;
_ III – the persons listed in item II, as well as those who have a commercial, professional or trust
relationship with the company and, upon having access to material information not yet disclosed,
knows that it is Insider Information;
_ IV – a Director who leaves the company with awareness of material information not yet disclosed and
uses this information for trading securities issued by the company within a period of three months
after leaving the company;
_ V – information shall be considered material from the moment in which studies or analyzes related
to the matter are initiated, or if it is information about corporate operations such as total or partial
spin-offs, mergers, transformations, or any form of corporate reorganization or business
combination, change in control of the company, including the execution, alteration or termination of
a shareholders' agreement, decision to go private or a change in the trading segment of its securities,
notwithstanding other matters that may also constitute a material fact; and
_ VI – information about the request for a judicial or extrajudicial corporate reorganization and filing
for bankruptcy made by the company is considered material information, from the moment in which
studies or analyzes related to these requests are initiated.
Restriction Period
In the period of 15 days before the disclosure of our quarterly information and annual information, with the
exception of the provisions on individual investment/divestment plans in our Policy and in CVM Resolution
No. 44/2021; the company, controlling shareholders, executive officers, members of the Board of Directors,
the Fiscal Council and any bodies with technical or advisory functions, established by a statutory provision,
shall be restricted from trading securities issued by the company, or referenced thereto, regardless if these
individuals have knowledge of the content in the company's quarterly accounting information and the
annual financial statements. The restriction period excludes the day of the disclosure of the financial
statements, however, securities may only be traded on the day of the disclosure after the actual disclosure
has occurred.
This restriction does not apply to:
_
trading of fixed-income securities, when carried out through operations with joint repurchase
commitments by the seller and resale by the buyer, in which settlement has been predefined for a
date that may be prior to, or on the maturity date, of said operations, with profitability or predefined
remuneration parameters;
_
operations aimed at fulfilling obligations that were committed before the start of the restriction
period arising from loans of shares, exercise of purchase or sale options by third parties, and forward
purchase and sale agreements; and
_
trading carried out by financial institutions and legal entities that are part of their economic group,
provided that they are carried out in their normal course of business and in compliance with the
parameters that have been established in the company’s trading policy.
Also, the restriction does not rely on an assessment if material information exists and is pending disclosure
or on the intention for the trading activity.
Annual Report and Form 20-F 2024 I 263
Shareholder Information
The Investor Relations Officer (“IRO”) may, regardless of justification, establish periods in which the
company and Related Parties may not trade securities issued by Petrobras, its Subsidiaries and Affiliates
(that are publicly traded companies). If this option is executed, the IRO must clearly indicate the initial term
and the final term of the Blackout Period, and the company and the Related Parties should maintain these
periods confidential. The lack of communication by the IRO regarding the Blackout Period shall not exempt
anyone from complying with the Policy, as well as with the provisions of CVM Resolution No. 44/21 and other
normative acts of the CVM.
Exceptions to trading Restrictions
Anyone who has a relationship with a publicly-held company that makes them potentially subject to the
presumptions referred to in § 1 of article 13 of CVM Resolution 44/21 may formalize an individual plan
investment or disinvestment regulating their dealings with Securities issued by the company or referenced
to them Securities issued by the company or referenced to them, in order to rule out the applicability of
those presumptions. The individual investment plan will be governed by CVM Resolution No. 44/21.
Dispute Resolution
As a company listed on the B3’s Level 2, our Bylaws provide for mandatory dispute resolution, by means of
arbitration before the Câmara de Arbitragem do Mercado, concerning any dispute or controversies that
may arise among us, our shareholders, our management and members of our Fiscal Council, related to or
arising from the application, validity, effectiveness, interpretation, violation and effects of the provisions
contained in the applicable Brazilian Corporation Law, Law Nº 13,303/16, in the company’s Bylaws, in the
rules issued by the National Monetary Council, Banco Central do Brasil and the CVM, as well as in other rules
applicable to the operation of the general stock market, in addition to those contained in the Level 2
Regulation, Arbitration Regulation, Participation Agreement and Level 2 Sanctions Regulation.
Entities that are part of the direct and indirect public administration, as our company and our controlling
shareholder, may use arbitration as a dispute resolution mechanism only for disputes involving negotiable
economic rights. As a result, such entities cannot submit to arbitration any rights deemed non-negotiable
under Brazilian law (direitos indisponíveis), such as those deemed to relate to public interest. Therefore,
decisions of the Brazilian federal government exercised at any general shareholders’ meeting, if based or
related to public interest, are not expected to be subject to an arbitration proceeding.
Annual Report and Form 20-F 2024 I 264
Shareholder Information
Shareholders’ Rights
Shareholders’ Meetings and Voting Rights
Our shareholders have voting rights at the shareholders’ meeting to decide on any matters related to our
corporate purposes and to pass any resolutions they deem necessary for our protection and development,
except for certain matters whose authority to resolve are exclusively held by our corporate governing
bodies.
Our annual shareholders’ meeting takes place at our headquarters, in Rio de Janeiro, Brazil, in April of each
year. Additionally, our Board of Directors or, in some specific situations set forth in Brazilian Corporate Law,
our shareholders or Fiscal Council, may call our extraordinary shareholders’ meetings. In 2024, our meeting
was held partially virtually (via videoconference), in accordance with CVM Resolution No. 81/2022.
Therefore, shareholders can participate in the meeting through the digital platform we provided or in
person at our headquarters.
The notice of the annual shareholders’ meeting and related documents must be published at least 30
calendar days prior to the scheduled meeting date.
For ADS holders, we are required to provide notice to the ADS depositary at least 30 calendar days prior to
a shareholders’ meeting. Upon receipt of our shareholders’ meeting notice, the depositary must fix the ADS
record date and distribute to ADS holders a notice. This notice must contain (i) final information particular
to such vote and meeting and any solicitation materials, (ii) a statement that each holder on the record date
set by the depositary will be entitled to instruct the depositary as to the exercise of the voting rights,
subject to any applicable provisions of Brazilian law as well as our Bylaws, and (iii) a statement as to the
manner in which these instructions can be given, including instructions to give a discretionary proxy to a
person designated by us.
In person or electronic participation in shareholders’ meetings is not available to ADS holders, which may
only vote by means of proxy voting cards mailed to the ADR depositary bank.
Quorum
Attendance quorum. In order to start, shareholders representing at least one-fourth of our issued and
outstanding common shares must attend our shareholders’ meeting, except when the matter to be decided
aims to amend our Bylaws. In this case, a valid meeting requires the attendance of shareholders
representing at least two-thirds of our issued and outstanding common shares. If the required quorum is
not reached, our Board of Directors may call a second meeting by sending a notice at least eight calendar
days prior to the new scheduled meeting. The attendance quorum requirements will not apply to such
second meeting, but the voting quorum requirements described below shall be observed.
Voting quorum. Matters to be approved at our shareholders’ meeting must be approved by the quorums
specified below.
Annual Report and Form 20-F 2024 I 265
Shareholder Information
Matter approved by majority vote (of holders of common shares attending the meeting):
_
amend our Bylaws;
_
approve any capital change;
_
elect or dismiss members of our Board of Directors and Fiscal Council (and its respective alternates),
subject to the right of our preferred shareholders to elect or dismiss one member of our Board of
Directors and to elect one member of our Fiscal Council (and its respective alternates) and to the
right of our employees to elect or dismiss one member of our Board of Directors;
_
receive the yearly financial statements prepared by our management and accept or reject
management’s financial statements, including the allocation of net income for payment of the
mandatory dividend and allocation to the various reserve accounts;
_
authorize the issuance of debentures, except for the issuance of non-convertible unsecured
debentures or the sale of such debentures when in treasury, which may be approved by our Board of
Directors;
_
accept or reject the valuation of assets contributed by a shareholder in consideration for increase of
capital stock;
_
approve the disposal of convertible debentures issued by our wholly-owned subsidiaries and held by
us;
_
establish the compensation of the former members of our Executive Officers, our Board of Directors,
our Fiscal Council, including the compensation due during the period of six months of forfeiture
provided for in our Bylaws, and of advisory committees to our Board of Directors;
_
approve the cancellation of our registration as a publicly-traded company;
_
approve the requirements of our nomination policy, in addition to the requirements provided by law
applicable to boards of directors and fiscal councils; and
_
approve in the case of publicly-traded company, the execution of transactions with related parties,
and the sale or contribution of assets to another company, if the value of the transaction
corresponds to more than 50% of the value of the total assets listed in the last approved balance
sheet.
Matter approved by at least one-half of the common shares of our total capital stock:
_
reduce of the mandatory dividend distribution;
_
merge into another company or consolidate with another company, subject to the conditions set
forth in Brazilian Corporate Law;
_
participate in a group of companies subject to the conditions set forth in Brazilian Corporate Law;
_
change our corporate purpose, which must be preceded by an amendment to our Bylaws by federal
law, as we are controlled by the Brazilian federal government and our corporate purpose is
established by law;
_
spin-off of a portion of us, subject to the conditions set forth in Brazilian Corporate Law;
_
waive the right to subscribe to shares or convertible debentures issued by our wholly-owned
subsidiaries or associate;
_
decide on our dissolution;
Annual Report and Form 20-F 2024 I 266
Shareholder Information
_
create preferred shares or increase the existing classes of preferred shares, without preserving the
proportions to any other class of preferred shares, except as set forth in or authorized by our Bylaws;
_
change the preferences, privileges or redemption or amortization conditions of any class of
preferred shares; and
_
create new class of preferred shares entitled to more favorable conditions than the existing classes.
Matter approved by a special quorum:
_
select a specialized company to work out the appraisal of our shares by economic value in the event
of the cancellation of our registry as a publicly traded company, which matter must be approved by
the majority of votes from the holders of the outstanding shares that are present at the meeting.
According to B3´s Level 2 regulation, outstanding shares means all the shares issued by a company,
except for the shares held by the controlling shareholder, by persons linked to such controlling
shareholder and by our managers, as well as those shares in treasury and special class of preferred
shares which purpose is to guarantee differentiated political rights and be non-transferable and
exclusive property of the privatizing entity. This matter must only be discussed in a shareholders’
meeting installed with the presence of at least 20% of the holders of the outstanding shares in a first
call, or the presence of any number of holders of the outstanding shares in a second call.
Pursuant to Law No. 13,303/16, no decision taken at any shareholders’ meeting can change the corporate
status of our company (i.e. sociedade anônima).
Under Brazilian Corporate Law, if a shareholder has a conflict of interest with a company in connection with
any proposed transaction, the shareholder may not vote in any decision regarding such transaction. Any
transaction approved with the vote of a shareholder having a conflict of interest may be annulled and such
shareholder may be liable for any damages caused and be required to return to us any gain it may have
obtained as a result of the transaction.
Also under Brazilian Corporate Law, minority shareholders representing at least 10% of our voting capital
have the right to demand that a cumulative voting procedure be adopted to entitle each common share to
as many votes as there are board members and to give each common share the right to vote cumulatively
for only one candidate of our Board of Directors or to distribute its votes among several candidates.
Pursuant to regulations promulgated by the CVM, the 10% threshold requirement for the exercise of
cumulative voting procedures may be reduced depending on the amount of capital stock we possess. For a
company like us, the threshold is 5%. Thus, shareholders representing 5% of our voting capital may demand
the adoption of the cumulative voting procedure.
Regarding the right to appoint members of our Board of Directors and our Fiscal Council, the following
should be highlighted:
_
our minority preferred shareholders that together hold at least 10% of the total capital stock
(excluding the shares held by our controlling shareholder) have the right to elect and remove one
member to our Board of Directors at a shareholders’ meeting, by a separate voting procedure;
_
our minority common shareholders have the right to elect and remove one member to our Board of
Directors, if a greater number of directors is not elected by such minority shareholders by means of
the cumulative voting procedure;
_
our employees have the right to directly elect one member to our Board of Directors by means of a
separate voting procedure, pursuant to Law No. 12,353/10; and
_
subject to the provisions of applicable law, the Brazilian Minister of Economy has the right to elect
and remove one member of our Board of Directors.
Annual Report and Form 20-F 2024 I 267
Shareholder Information
Brazilian Corporate Law and our Bylaws provide that, regardless of the exercise by our minority
shareholders of the rights related to the cumulative voting process, the Brazilian federal government
always has the right to appoint the majority members of our directors and our Fiscal Council.
Other Shareholders’ Rights
In addition to their voting rights, shareholders have the following rights:
Preemptive rights: Each of our shareholders has a general preemptive right to subscribe for shares or
securities convertible into shares in any capital increase, in proportion to his or her shareholding. A
minimum period of 30 days following the publication of notice of a capital increase is assured for the
exercise of the right, and the right is transferable. Under our Bylaws and Brazilian Corporate Law, and
subject to the requirement for shareholder approval of any necessary increase to our authorized share
capital, our Board of Directors may decide not to extend preemptive rights to our shareholders, or to reduce
the 30-day period for the exercise of preemptive rights, in each case with respect to any issuance of shares,
debentures convertible into shares or warrants in the context of a public offering.
In the event of a capital increase by means of the issuance of new shares, holders of ADSs and holders of
common or preferred shares would have, except under circumstances described above, preemptive rights
to subscribe for any class of our newly issued shares. However, holders of ADSs may not be able to exercise
the preemptive rights relating to the common and preferred shares underlying their ADSs unless a
registration statement under the Securities Act is effective with respect to those rights or an exemption
from the registration requirements of the Securities Act is available.
For more information, see “Risks – Risk Factors – Risks related to shares and debt securities” in this annual
report.
Redemption and rights of withdrawal: Brazilian Corporate Law provides that, under limited circumstances,
shareholders have the right to withdraw their equity interest from a company and to receive payment for
the portion of shareholder’s equity attributable to their equity interest.
This right of withdrawal may be exercised by the holders of the adversely affected common or preferred
shares, provided that certain conditions set forth in Brazilian Corporate Law are met, in the event that we
decide to:
_
increase the existing classes of preferred shares, without preserving the proportions to any other
class of preferred shares;
_
change the preferences, privileges, redemption or amortization conditions of any class of preferred
shares or to create a new class of preferred shares entitled to more favorable conditions than the
existing classes;
_
merge into another company or to consolidate with another company;
_
participate in a centralized group of companies as defined under Brazilian Corporate Law;
_
reduce the mandatory distribution of dividends;
_
change our corporate purposes;
_
spin-off a portion of us;
_
transfer all of our shares to another company or to receive shares of another company in order to
make us, whose shares are transferred a wholly-owned subsidiary, known in Brazil as incorporação
de ações; or
_
acquire control of another company at a price that exceeds the limits set forth in Brazilian Corporate
Law.
Annual Report and Form 20-F 2024 I 268
Shareholder Information
This right of withdrawal may also be exercised in the event that the entity resulting from a merger,
consolidation or spin-off of a listed company and us do not negotiate new shares in the secondary market,
within 120 days from the date of the shareholders’ meeting approving the transaction, in accordance with
the applicable SEC regulations.
Considering that our Bylaws do not provide for rules to determine any value for redemption, under Brazilian
Corporate Law, any redemption of shares arising out of the exercise of such withdrawal rights would be
made based on the book value per share, determined on the basis of the last balance sheet approved by our
shareholders. However, if a shareholders’ meeting giving rise to redemption rights occurred more than 60
days after the date of the last approved balance sheet, a shareholder would be entitled to demand that his
or her shares be valued on the basis of a new balance sheet dated within 60 days of such shareholders’
meeting. In this case, we would immediately pay 80% of the amount of reimbursement calculated based on
the last balance sheet and, after the special balance sheet has been drawn up, we would pay the balance
within 120 days from the date of the shareholders’ meeting resolution. The right of withdrawal lapses 30
days after publication of the minutes of the shareholders’ meeting that approved the matters described
above. We would be entitled to reconsider any action giving rise to withdrawal rights within ten days
following the publication of the minutes of the meeting ratifying the decision if the payment of the price of
reimbursement of the shares to the dissenting shareholders would jeopardize our financial stability.
Liquidation: In the event of a liquidation, holders of preferred shares are entitled to receive, prior to any
distribution to shareholders, payment for the portion of shareholder’s equity attributable to their equity
interest.
Conversion rights: Our common shares are not convertible into preferred shares, nor are preferred shares
convertible into common shares.
Liability of our shareholders for further capital calls: Neither Brazilian Corporate Law nor our Bylaws
provide liability for our shareholders for further capital calls. Our shareholders’ liability for capital stock is
limited to the payment of the issuance price of the shares subscribed or acquired.
Rights not subject to waiver: According to Brazilian Corporate Law, neither a company’s Bylaws nor
decisions taken at a shareholders’ meeting may deprive a shareholder of some specific rights, such as the
right to:
_
participate in the distribution of profits;
_
participate in any remaining residual assets in the event of our liquidation;
_
supervise the management of the corporate business as specified in Brazilian Corporate Law;
_
exercise preemptive rights in the event of a subscription of shares, debentures convertible into
shares or subscription warrants (other than with respect to a public offering of such securities, as
may be set out in the Bylaws); and
_
withdraw from us in the cases specified in Brazilian Corporate Law.
Annual Report and Form 20-F 2024 I 269
Shareholder Information
Shareholder Remuneration
Payment of Dividends, Interest on Capital and Buyback
Payments to our shareholders are subject to the provisions of Brazilian Corporate Law and applicable local
laws and regulations, our Bylaws and our shareholder remuneration policy.
Our revised shareholder remuneration policy, approved in July 2023, provides for the payment of dividends
and/or interest on capital (juros sobre capital próprio) and/or the repurchase of shares issued by Petrobras
(“buyback”).
The buyback, when it occurs, must be carried out through a structured program approved by the Board of
Directors. The payment of dividends and/or interest on capital for each fiscal year must be approved by our
shareholders at the annual general meeting of shareholders.
Regarding payment of dividends and/or interest on capital, the profits are distributed to outstanding
shares in proportion to the number of shares owned by each shareholder on the applicable record date. Our
preferred shares have preference in the distribution of dividends and interest on capital. Thus, the payment
of dividends and/or interest on capital to holders of common shares is subject to the right to dividend
distributions held by the holders of preferred shares. In our current Policy we have defined that dividend
distribution payments should be made quarterly.
The payment of interest on capital to our shareholders is subject to withholding income tax, pursuant to
the Brazilian tax laws, which is not levied upon payments of dividends. The holders of ADSs are also subject
to withholding income tax, unless provided otherwise by their applicable law.
Our current shareholder remuneration policy provides the following parameters for the distribution of
remuneration, which should be followed in the decisions of the Board of Directors and in the Management
proposals to the Annual General Meeting:
_
1. We established a minimum annual compensation of US$4 billion for fiscal years in which the
average price of Brent is above US$40/bbl, which may be distributed regardless of our level of
indebtedness, as long as the principles set forth in the policy are observed.
_
1.1. The minimum annual compensation will be the same for common shares and preferred shares,
provided that it exceeds the minimum amount for preferred shares set forth in our Bylaws.
_
2. In case of gross debt equal to or lower than the maximum debt level defined in the Strategic Plan
2050 and Business Plan 2025-29 and accumulated positive result, to be verified in the last quarterly
result calculated and approved by the Board of Directors, we shall distribute to our shareholders
45% of the free cash flow, according to the equation below, provided that the result of this formula
is higher than the amount provided in item 1 and does not compromise our financial sustainability:
Annual Report and Form 20-F 2024 I 270
Shareholder Information
Shareholders Remuneration: 45% of Free Cash Flow
Free cash flow: operating cash flow minus acquisitions of property, plant and equipment, intangible
assets and equity interests.
Operating cash flow: net funds generated by operating activities shown in the consolidated statement
of cash flows.
Acquisitions of PP&E and intangible assets and equity interests: payments made by us for the
acquisition of property, plant and equipment, intangible assets and equity interests, presented in the
statement of consolidated cash flows. Acquisitions of equity interest include contributions, advances
for future capital increase and acquisition and/or increase in the percentage of interest, including in
subsidiaries. Receipts and/or payments from other transactions of investment and financing activities
presented in the consolidated statement of cash flows will not be added, as well as payments related
to repurchases of shares issued by us.
_
3. We may, in exceptional cases, distribute extraordinary remuneration to shareholders, exceeding
the mandatory legal minimum dividend and/or the amounts established in items 1 and 2, provided
that our financial sustainability is preserved.
Furthermore, we may exceptionally approve the distribution of remuneration to shareholders even in the
event of no net income, as long as the rules regarding dividends set forth in Law No. 6,404/76 are complied
with and the criteria defined in the shareholder remuneration policy are observed. In all distribution
scenarios, the remuneration to shareholders must follow the rules set forth in Law 6,404/76 (e.g., Articles
201 to 205: mandatory dividend; dividends on preferred shares; interim dividends; payment of dividends) in
our Bylaws, and must not compromise our short, medium, and long-term financial sustainability.
Pursuant to our Bylaws, intermediate and interim dividends and interest on capital shall be allocated as
minimum mandatory dividend as set forth by the Brazilian Corporate Law, including for the purpose of
paying the minimum priority dividends of preferred shares.
Law No. 9,249/95, as amended, provides for distribution of interest on capital to shareholders as an
alternative form of distribution. Such interest is limited to the daily pro rata variation of the TJLP interest
rate. The effective payment or credit of interest on capital depends on the existence of profits, calculated
before deducting interest, or accumulated profits and profit reserves, in an amount equal to or greater than
twice the amount of the interest to be paid or credited.
We may treat these payments of interest on capital as a deductible expense for calculating real profit, but
the deduction cannot exceed the greater of:
_
50% of net income before taking into account such distribution, in case these are considered
expenses, based on the calculated profit after taking into account any deductions for social
contributions on net income and before deducting income tax for the period in respect of which the
payment is made; or
_ 50% of retained earnings and profit reserves.
With respect to the distribution of remuneration, our shareholders must also consider the following:
_
Taxation: Any payment of interest on capital to ADS holders or shareholders, whether or not they
are Brazilian residents, is subject to Brazilian withholding taxes at the rate of 15% or 25%, subject
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Shareholder Information
to possible reduction by an applicable tax treaty. The 25% rate applies only if the beneficiary is
resident in a tax haven. The amount paid to shareholders as interest on capital, net of any
withholding tax, may be included as part of any mandatory distribution of dividends. Under Brazilian
Corporate Law, we are required to distribute to shareholders an amount sufficient to ensure that
the net amount received, after payment by us of applicable Brazilian withholding taxes in respect
of the distribution of interest on capital, is at least equal to the minimum mandatory dividend as
set forth by the Brazilian law.
For more information on Brazilian taxation of ADSs and our shares, see “Legal and Tax – Tax –
Taxation Relating to the ADSs and our Common and Preferred Shares” in this annual report.
_
Date of payment: Under Brazilian Corporate Law and our Bylaws, dividends are generally required
to be paid within 60 days following the date they are declared, unless a shareholders’ resolution sets
forth for another date of payment, which, in any case, must occur prior to the end of the fiscal year
in which the dividend was declared.
_
Adjustments: Our Board of Directors may approve the payment of anticipated dividends or interest
on capital to our shareholders which amount is subject to financial charges at the SELIC rate from
the date of the payment until the end of each fiscal year.
_
Unclaimed dividends: Shareholders have a three-year period from the dividend payment date to
claim dividends or interest on capital payments with respect to their shares, after which the amount
of the unclaimed dividends reverts to us.
Our total distributions to shareholders for 2024 are expected to be US$13,457 million and will be voted on
at our shareholder’s annual general meeting to be held in April 2025. For further information, see Note 32.4
to our audited consolidated financial statements.
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Shareholder Information
Mandatory distribution
Pursuant to Brazilian Corporate Law and our Bylaws, we must comply with two minimum mandatory
distributions of dividends, both of which are provided in our shareholder remuneration policy:
_ we must pay at least 25% of our adjusted net income, after deducting allocations to the legal reserve
and further allocations eventually required by Brazilian Corporate Law; and
_ holders of our preferred shares have priority to receive the mandatory dividend amount, as well as to
receive a payment in the event of reimbursement of capital. They are also entitled to minimum annual
non-cumulative preferential dividends in case we declare dividends equal to the higher of (a) 5% of
their pro rata share of our paid-in capital, or (b) 3% of the book value of their preferred shares.
To the extent that we declare dividends on our common shares in any particular year in an amount that
exceeds the minimum preferential dividends, holders of preferred shares are entitled to an additional
dividend amount per share in the same amount per share paid to holders of common shares. Holders
of preferred shares also participate equally with common shareholders in share capital increases
derived from the incorporation of reserves and profits.
Brazilian Corporate Law, however, permits a publicly held company such as ours to suspend the
minimum mandatory distribution of dividends in case our Board of Directors and our Fiscal Council
report to the annual general shareholders’ meeting that the distribution would not be advisable due
to our financial condition. In this case, our Board of Directors must file with the CVM an explanation for
suspending the dividend distribution. Profits not distributed due to such suspension must be allocated
to a special reserve and, if not absorbed by subsequent losses, must be distributed as soon as our
financial condition allows such payments.
Allocation of net income
At each annual general shareholders’ meeting, our Board of Directors and Executive Officers are required
to recommend how to allocate net income for the preceding fiscal year. The General Shareholder’s’ Meeting
may disagree with such recommendation and decide for other allocations, such as for the allocation to the
statutory reserves. Under Brazilian Corporate Law, net income is obtained after deducting statutory
holdings of the employees, managers and beneficiary parties.
In accordance with Brazilian Corporate Law, an amount equal to our net income, as further reduced by
amounts allocated to the legal reserve, to the fiscal incentive investment reserve, to the contingency
reserve or to the unrealized income reserve established by us in compliance with applicable law (discussed
below) and increased by reversals of reserves constituted in prior years, is available for distribution to
shareholders in any given year. After the distribution of preferred dividends, a percentage of net income
may be allocated to a contingency reserve for anticipated losses that are deemed probable for future years.
Any amount so allocated in a prior year must be either (i) reversed in the fiscal year in which the reasons
justifying the reserve cease to exist, or (ii) written off in the event that the anticipated loss occurs.
A portion of the net income from donations or government grants for investments may also be allocated to
the creation of a tax incentive reserve.
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Shareholder Information
If the mandatory distribution amount, determined without deducting the amount of unrealized profits from
its calculation basis, exceeds the sum of realized net income in a given year, this excess may be allocated to
an unrealized revenue reserve. Brazilian Corporate Law defines realized net income as the amount of net
income that exceeds the sum of the net positive result of equity adjustments and profits or revenues from
operations whose financial results take place after the end of the next succeeding fiscal year. As long as we
are able to make the minimum mandatory distribution described below, we must allocate an amount
equivalent to 0.5% of subscribed and fully paid-in capital at year-end to a statutory reserve. The reserve is
used to fund the costs of research and technological development programs. The accumulated balance of
this reserve cannot exceed 5% of the subscribed and fully paid-in capital stock. Additionally, we may allocate
up to 70% of the adjusted net income for the year to a capital remuneration reserve, in compliance with
article 202 of the Brazilian Corporation Law and the Shareholder Remuneration Policy, up to the limit of the
share capital. The purpose of the reserve is to ensure resources for the payment of dividends, interest on
equity, or other forms of remuneration to shareholders provided for by law, interim or intermediate
dividends, share buy-backs authorized by law, absorption of losses and incorporation into share capital. The
accumulated balance of the two reserves, together with the balance of the other profit reserves, in
accordance with art. 199 of the Brazilian Corporation Law, may not exceed the share capital.
Brazilian Corporate Law also provides for the retention of profits, which cannot be approved in the event
there is mandatory dividend distribution and must be in accordance with the terms of our capital budget
previously approved by the shareholders’ meeting. A portion of our net income that exceeds the minimum
mandatory distribution may be allocated to fund working capital needs and investment projects, as long as
such allocation is based on a capital budget previously approved by our shareholders. Capital budgets for
more than one year must be reviewed at each annual shareholder meeting.
The creation of statutory reserves and the retention of profits cannot be approved to the detriment of the
mandatory dividend.
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Shareholder Information
Additional Information for Non-Brazilian
Shareholders
Foreign investors may trade their shares directly on the B3 (non-Brazilian holders) or through ADSs on the
NYSE. There are no restrictions on ownership of our common or preferred shares in Brazil by individuals or
legal entities domiciled outside Brazil and all of them are entitled to the rights and preferences of our
common or preferred shares, as the case may be.
The ability to convert dividend payments and proceeds from the sale of common or preferred shares or
preemptive rights into foreign currency and to remit such amounts outside Brazil is subject to restrictions
under foreign investment legislation (Brazilian foreign exchange controls). However, if foreign investors are
registered with the CVM, in accordance with CMN Resolution No. 4,373, they may use the dividend payments
and proceeds from the sale of shares to buy and sell securities directly on the B3, which generally requires,
among other steps, the registration of the relevant investment with the Central Bank of Brazil. Nonetheless,
any non-Brazilian holder who registers with the CVM in accordance with CMN Resolution No. 4,373 may buy
and sell securities directly on the B3. Such non-Brazilian holders must appoint a local representative in
Brazil who will be required, among other duties, to register and keep updated with the Central Bank of Brazil
the record of all transactions of such investors on the B3.
The right to convert dividend payments and proceeds from the sale of shares into foreign currency and to
remit such amounts outside Brazil may also be subject to restrictions under foreign investment legislation.
If any restrictions are imposed on the remittance of foreign capital abroad, they could hinder or prevent the
Central Depositária, as custodian for the common and preferred shares represented by the ADSs, or
registered holders who have exchanged ADSs for common or preferred shares, from converting dividends,
distributions or the proceeds from any sale of such common or preferred shares, as the case may be, into
U.S. dollars and remitting the U.S. dollars abroad.
Non-Brazilian Holders on B3
Under CMN Resolution No. 4,373, foreign investors may invest in almost all financial assets and engage in
almost all transactions available in the Brazilian financial and capital markets, provided that certain
requirements are fulfilled. Therefore, a foreign investor must:
_
appoint at least one representative in Brazil, with powers to perform actions relating to the
investor’s investment;
_
register as a foreign investor with the CVM;
_
appoint at least one authorized custodian in Brazil for the investor’s investments;
_
register all portfolio investments of the foreign investor in Brazil, through the investor’s
representative, with the Central Bank of Brazil; and
_
comply with other requirements provided for under CVM Resolution No. 13/20.
After the fulfillment of these requirements, the foreign investor will be able to trade in the Brazilian
financial and capital markets.
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Shareholder Information
Securities and other financial assets held by investors under CMN Resolution No. 4,373 must be registered
or maintained in deposit accounts or under the custody of an entity duly licensed by the Central Bank of
Brazil or the CVM. In addition, any transfer of securities held under CMN Resolution No. 4,373 and CVM
Resolution No. 13/20 must be carried out in the stock exchanges or through organized over-the-counter
markets licensed by the CVM, except for transfers resulting from private transactions.
ADS Holders
CMN Resolution No. 4,373 allows Brazilian companies to issue depositary receipts in foreign exchange
markets. CVM Resolution 13 is the rule that currently deals with the registration of these investors with the
CVM. We currently have an ADR program for our common and preferred shares duly registered with the CVM
and the Central Bank of Brazil. The proceeds from the sale of ADSs by holders outside Brazil are free of
Brazilian foreign exchange controls.
JPMorgan is the depositary for both of our common and preferred ADSs since January 2, 2020. The
Depositary will register and deliver the ADSs, each of which currently represents (i) two shares (or a right to
receive two shares) deposited with an agent of the Depositary acting as custodian, and (ii) any other
securities, cash or other property which may be held by the Depositary. The Depositary’s corporate trust
office at which the ADSs will be administered is located at 383 Madison Avenue, Floor 11, New York, New
York 10179, United States.
The Depositary has obtained from the Central Bank of Brazil an electronic certificate of registration with
respect to our existing ADR programs. Pursuant to the registration, the custodian and the Depositary will
be able to convert dividends and other distributions with respect to the relevant shares represented by
ADSs into foreign currency and to remit the proceeds outside Brazil.
In the event that an ADS holder exchanges ADSs for the underlying common or preferred shares, the holder
will be required to obtain registration as a foreign investor in Brazil pursuant to CMN Resolution No. 4,373
by appointing a local representative and obtaining a certificate of registration from the Central Bank of
Brazil. Failure to take these measures may subject the holder to the inability of converting the proceeds
from the disposition of, or distributions with respect to, the relevant shares, into foreign currency and to
remit proceeds outside of Brazil. Additionally, the holder may be subjected to a less favorable Brazilian tax
treatment than a holder of ADSs. If the foreign investor resides in a tax haven jurisdiction, the investor will
also be subject to less favorable tax treatment.
For more information, see “Risks – Risk Factors – Risks related to shares and debt securities” and “Legal and
Tax – Tax – Taxation Relating to the ADSs and our Common and Preferred Shares” in this annual report.
Fees Payable by ADS holders
The Depositary may charge ADS holders various fees, including: (i) an annual fee of US$0.05 (or less) per
ADS for administering the ADR program, and (ii) amounts in respect of expenses incurred by the Depositary
or its agents on behalf of ADS holders, including expenses arising from compliance with applicable law, taxes
or other governmental charges, facsimile transmission, or conversion of foreign currency into U.S. dollars.
In both cases, the Depositary may decide in its sole discretion to seek payment by directly billing investors
or by deducting the applicable amount from cash distributions. ADS holders may also be required to pay
additional fees for certain services provided by the Depositary, as set forth in the table below.
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Shareholder Information
Depositary Services
Fees Payable by ADS Holders
Issuance and delivery of ADSs, including issuances resulting from a distribution
of shares or rights or other property
US$5.00 (or less) per 100 ADSs
(or portion thereof)
Distribution of dividends
US$0.05 (or less) per ADS
Cancellation of ADSs for the purpose of withdrawal
US$5.00 (or less) per 100 ADSs
(or portion thereof)
Fees Payable by the Depositary
The Depositary reimburses us for certain expenses we incur in connection with the administration and
maintenance of the ADR program. These reimbursable expenses comprise, among others, investor relations
expenses, listing fees and legal fees.
Legal and Tax
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Regulation
Business Regulation
Exploration & Production
Under Brazilian law, the federal government owns all crude oil and natural gas subsoil accumulations in
Brazil, and any state- or privately-owned company can carry out the exploration and production of such oil
and natural gas accumulations in the country. There are three different types of E&P contracts: (i)
Concession Regime; (ii) Production Sharing; and (iii) Transfer of Rights.
CONCESSION REGIME
Until 1997, we were the Brazilian federal government’s exclusive agent to carry out exploration and
production of oil and gas in Brazil.
In 1997, the Brazilian federal government established a concession-based regulatory framework and
created an independent regulatory agency to regulate the oil, natural gas and renewable fuel industry in
Brazil, namely the ANP. This framework and the ANP created a competitive environment in the oil and gas
sector.
The concession-based regulatory framework granted us the right to explore crude oil reserves in each of
our already existing producing fields under concession contracts for an initial term of 27 years from the
date when they were declared commercially profitable. These are known as the “Round Zero” concession
agreements. This initial 27-year period for production can be extended at the request of the concessionaire,
subject to approval from the ANP.
Starting in 1999, all areas that were not already subject to concessions became available for public bidding
conducted by the ANP. We participated in these biddings both independently or through partnerships with
private companies (as operator or as non-operator, in a case-by-case analysis).
According to Law No. 9,478/1997, and as per our concession agreements for exploration and production
activities, we are entitled to the oil and gas exploited from the concession areas and we are required to
distribute to the Brazilian federal government a portion of the corresponding proceeds.
For information related to Taxation under Concession Regime for Oil and Gas, see item “Legal and Tax –
Government Take in Different Regulatory Regimes” in this annual report.
PRODUCTION-SHARING CONTRACT REGIME FOR UNLICENSED PRE-SALT AND POTENTIALLY
STRATEGIC AREAS
Discoveries of large oil and natural gas reserves in the Pre-salt areas of the Campos basin and the Santos
basin prompted a change in the legislation regarding oil and gas exploration and production activities. In
2010, laws were enacted to regulate contracts under a production-sharing regime in the Pre-salt area, as
defined under Law No. 12,351/2010 and in potentially strategic areas. The enacted legislation did not
impact the concession contracts.
We are not required to be the exclusive operator of the Pre-salt areas, but prior to any bid round, the
Brazilian federal government must offer us the right to express our interest to exercise the preemption
right to operate the blocks under production-sharing regime with minimum 30% of interest. Should there
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be no proposal for the areas to which we have expressed such interest that area will not be awarded and
therefore, we have no remaining obligations. The preemption right only becomes effective in (i) cases of
winning proposals above the minimum profit oil, should we decide to be part of such consortium and have
previously expressed interest and (ii) cases in which the winning proposal is in the minimum profit oil, then
we are required to be the operator, with minimum 30% of interest, as applicable according to the relevant
Governmental Resolution. Regardless of whether we exercise our preemption right, we will also be able to
participate, at our discretion, in the bidding process to increase our interest in any of the Pre-salt areas.
The winning bidder will be the company that offers to the Brazilian federal government the highest
percentage of “profit oil,” which is the Gross Revenue of the production of a certain field after deduction of
royalties and “cost oil,” which is the cost associated with oil production. The royalty rate is 15% applicable
to the gross production of oil and natural gas and there is no other government fee payable to the Brazilian
federal government.
The production-sharing contracts are executed by and between the private companies that are winning
bidders, the state-owned non-operating company PPSA, which represents the interests of the Brazilian
federal government in the production-sharing contracts and manages the Brazilian federal government’s
share of the profit oil, and the ANP. The PPSA participates in operational committees, with a casting vote
and veto powers and manages and controls the relevant costs, all of it according to each specific
production-sharing contract.
TRANSFER OF RIGHTS (CESSÃO ONEROSA)
In 2010, we entered into an agreement with the Brazilian federal government under which the government
assigned to us the right to conduct activities for the exploration and production of oil, natural gas and other
fluid hydrocarbons in specified Pre-salt areas, subject to a maximum production of five bn boe. The initial
contract price for our rights under the Transfer of Rights Agreement was US$42.5 billion (R$74.8 billion),
which was paid in full on September 1, 2010. See “Material Contracts” in this annual report.
Both Law No. 12,276/2010 (the “Transfer of Rights Law”) and the Transfer of Rights Agreement provide for
a review procedure. The main purpose of the review procedure is to verify whether the price paid to the
Brazilian federal government by us in 2010 was appropriate in relation to the price for granting us the rights
to explore and produce five billion barrels of oil equivalent in certain Pre-salt areas.
According to the Transfer of Rights Agreement, the review must be based on technical reports prepared by
independent certifying entities to be contracted by the ANP and the assignee, which shall consider the best
practices of the oil industry, including the following items: (a) information contained in the final report of
the mandatory exploration program (as such term is defined in the Transfer of Rights Agreement); (b) the
market prices of oil and natural gas; and (c) specification of the product being produced. In addition, as
provided in the Transfer of Rights Agreement, the review must follow the assumptions set forth in such
agreement.
An internal committee to negotiate the revision of the Transfer of Rights Agreement with representatives
of the Brazilian federal government (i.e. representatives of the MME, the Ministry of Finance, and the ANP)
was created. The negotiations resulted in a revision of the Transfer of Rights Agreement that was submitted
to the TCU for analysis, by recommendation of the MME.
In 2019, the amendment to the Transfer of Rights Agreement was approved by us, the TCU and the National
Council for Energy Policy.
The amendment consolidates one of several scenarios discussed among the Brazilian federal government
and our commissions and resulted in a credit of US$9.058 billion in our favor, that was fully paid in December
2019. Additionally, the amendment establishes new percentages for local content: 25% for well
construction; 40% for production collection and disposal system; and 25% for stationary production unit.
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For information related to the new taxation model for the oil and gas industry (“Repetro”) see “Legal and
Tax – Government Take in Different Regulatory Regimes” in this annual report.
Refining, Transportation & Marketing
Regarding oil refining, by the Resolution No. 852/2021, the ANP requires a specific notification before
starting the construction of a new process unit, product treatment unit and/or ancillary unit of an oil
refinery and a specific authorization for operation of each of the process units, product treatment units and
ancillary units of an oil refinery. The oil products commercialization is subject to compliance with the
specifications established by the ANP for each product (e.g. gasoline, diesel, jet fuel, liquefied petroleum
gas).
The ANP requires information on import, export, production, processing, handling, transportation and
transfer, storage and distribution of oil, oil products, natural gas products and shale products activities on
a monthly basis.
Regarding fuel storage, the ANP, through Resolution No. 868/2022, established that information must be
provided both daily and monthly by us and other agents.
Since 2013, the ANP requires oil product producers (refineries and other agents) and fuel distributors to
ensure minimum inventories of gasoline and diesel. In 2015, the ANP established the same obligation for
producers of LPG and jet fuel.
The ANP also requires that refineries and importers of oil products publicly release their price lists
electronically (standard prices) as well as the prices for the previous 12 months, with a description of the
specific commercial terms for: (i) regular and premium gasoline; (ii) diesel oil and marine diesel; (iii) jet fuel;
(iv) LPG; (v) fuel oil; and (vi) asphalt.
Failure to comply with the ANP rules can lead to a range of fines and penalties, including the revocation of
the authorization.
In December 2016, the Brazilian federal government launched the “RenovaBio” program to stimulate the
production of biofuels in the local market, namely ethanol, biodiesel, biogas and biojet fuel. In June 2019,
the CNPE fixed the mandatory annual reduction of carbon emission targets and the ANP established (i) the
individualization of the annual mandatory greenhouse gas emission reduction targets for the
commercialization of fuels (Resolution No. 791/2019) and (ii) the procedures for the primary emission of
carbon emission reduction credits (Resolution No. 802/2019).
Our oil and natural gas refining area is also subject to the preventive and stringent control of CADE.
In 2019, we signed a commitment with CADE (termo de cessação de conduta) that consolidates our
understanding on the divestment of refining assets in Brazil. In November 2023, we formally requested a
review of the agreement signed with CADE in line with the Strategic Plan. Thus, in 2024, Petrobras and CADE
reached an agreement and established new commitments that served the interests of both parties. For
more information on our agreement with CADE regarding our divestments in refining assets, see “Risks –
Risk Factors – 6.b) The competitive environment of the Brazilian oil and gas market may intensify the
requirements for our performance levels to remain in line with the best companies in the sector. The need to
adapt to a competitive and complex environment may compromise our ability to implement our current
Strategic Plan or any subsequent plans adopted” and “Mergers and Acquisitions” in this annual report.
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Gas and Low Carbon Energies
NATURAL GAS LAWS
New Gas Law, regulated by Decree No. 10,712/2021, represents a new regulatory framework for the Brazilian
natural gas market, introducing relevant legal innovations and ensuring legal certainty to the
administrative rules arising from the “New Gas Market” Program, instituted by the Brazilian federal
government in mid-2019.
Among other matters, the New Gas Law provides: (i) negotiated access to flow pipelines, UPGNs and LNG
Terminals; (ii) the implementation of the entry and exit model for the transport of natural gas; (iii) the
change in the regime of use of transportation pipelines and storage facilities (from concession to
authorization); (iv) the unbundling of the natural gas transportation and distribution segments; and (v) the
change of competence to approve the import and export of natural gas (from the MME to the ANP).
In 2022, the CNPE published Resolution No. 3, establishing (i) the strategic guidelines for the new natural
gas market, (ii) the improvement of energy policies related to free competition in this market, (iii) the
fundamentals of the transition period, and (iv) the revocation, among others, of the CNPE Resolution No.
4/2019.
In August 2024, Decree No. 12.153/2024 was published, amending Decree No. 10.712/2021, introducing
significant changes to the regulation of the New Gas Law, related to natural gas activities. Despite the
significance of the publication of the New Gas Law, we expect further action by the ANP to establish
measures that will be necessary to implement most of the changes brought about by the new law.
In August 2023, the ANP published the 3rd update of its regulatory agenda for the years 2022-2023. For
more
information
see:
https://www.gov.br/anp/pt-br/acesso-a-informacao/acoes-e-
programas/agenda-regulatoria.
In November 2023, ANP published Resolution ANP No. 961/2023, with a specific revision of Resolutions ANP
No. 51/2013 and No. 11/2016, which regulate, respectively, the loading activity and natural gas
transportation service, in order to adapt and simplify the process of offering and contracting firm
transportation capacity in accordance with the new natural gas legal framework. With this publication, it
became possible to contract capacity in the transportation systems directly through the Capacity Offer
Portal without the need for a previous public call.
In July 2019, we signed a commitment with CADE (termo de cessação de conduta) which consolidates the
understandings between the parties on the promotion of competition in the natural gas sector in Brazil,
including the sale of equity participation in companies operating in this sector. In November 2023, we
formally requested a review of the agreement signed with CADE in line with the Strategic Plan. Thus, in 2024,
Petrobras and CADE reached an agreement and established new commitments that served the interests of
both parties. For more information on our agreement with CADE, see “Mergers and Acquisitions” and “Risks
— Risk Factors — 6.b) The competitive environment of the Brazilian oil and gas market may intensify the
requirements for our performance levels to remain in line with the best companies in the sector. The need to
adapt to a competitive and complex environment may compromise our ability to implement our current
Strategic Plan or any subsequent plans adopted” in this annual report.
RENEWABLE ENERGY AND CARBON
In August 2024, Law No. 14.948 was enacted. It represents a new regulatory framework for hydrogen in
Brazil, introducing relevant legal innovations. However, this regulatory framework still needs to be
regulated to enter into force.
On October 8, 2024, Law No. 14,993 (Lei Combustível do Futuro) was published, establishing the following:
i) the National Sustainable Aviation Fuel Program (ProBioQAV), the National Green Diesel Program (PNDV),
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and the National Decarbonization Program for Producers and Importers of Natural Gas and Incentives for
Biogas and Biomethane; ii) adjustments to the maximum and minimum limits for the blend of anhydrous
ethanol in gasoline C sold to the end consumer and the blend of biodiesel in diesel sold to the end consumer;
iii) regulations for the oversight of carbon dioxide capture and geological storage activities and the
production and commercialization of synthetic fuels; iv) the integration of initiatives and measures adopted
under the National Biofuels Policy (RenovaBio), the Green Mobility and Innovation Program (Programa
Mover), the Brazilian Vehicle Labeling Program (PBEV), and the Vehicle Emission Control Program
(Proconve). However, this regulatory framework still needs to be regulated to enter into force.
On December 12, 2024, Law No. 15,042 was published, which establishes the Brazilian System for Emissions
Trading of Greenhouse Gases (Sistema Brasileiro de Comércio de Emissões de Gases de Efeito Estufa - SBCE),
aimed at fulfilling the National Policy on Climate Change (Política Nacional sobre Mudanças do Clima) and
the commitments made under the United Nations Framework Convention on Climate Change, through the
definition of environmental commitments and financial discipline for the trading of assets. However, this
regulatory framework still needs to be regulated to enter into force.
Price Regulation
Until 1997, the Brazilian federal government had the power to regulate all aspects of the pricing of crude
oil, oil products, ethanol, natural gas, electric power and other energy sources. In 2002, the Brazilian federal
government eliminated price controls for crude oil and oil products, although it retained regulation over
certain existing natural gas sales agreements and electricity agreements (specifically the electric power
trade contracts in the regulated market – CCEAR).
For information on our price policy, see “Our Business – Refining, Transportation & Marketing” in this annual
report.
Environmental Regulation
All phases of the crude oil and natural gas business present environmental risks and hazards. Our facilities
in Brazil are subject to a wide range of federal, state and local laws, regulations and permit requirements
relating to the protection of human health and the environment, and they fall under the regulatory
authority of CONAMA.
Our offshore activities are subject to the administrative authority of IBAMA, which issues operating and
drilling licenses. We are required to submit reports on a regular basis, including pollution monitoring reports
to IBAMA and third-party environmental audits in order to maintain our licenses. This way, we maintain an
ongoing communication channel with the environmental authorities, in order to improve issues connected
with the environmental management of our exploration, production and refining processes of oil and
natural gas. In 2018, we designed actions and measures, together with IBAMA, to adjust the treatment and
discharge of produced water in some of our offshore platforms in order to accommodate recently issued
requirements by IBAMA. All of these actions are being met by us within the timeframes defined with IBAMA.
Since 2023, a new regional plan is being designed by IBAMA related to the social impact of the petroleum
chain, but it has not yet been completed. We are already monitoring vessels, aircraft, workforce, inputs and
wastes transport as the first part of this macroplan.
In addition, in order to help ensuring the safety of navigation, the Brazilian maritime authority also works
towards the prevention of environmental pollution, with random or periodic surveys of offshore units.
Most of the onshore environmental, health and safety conditions are controlled either at the federal or the
state level depending on where our facilities are located and the type of activity under development.
However, it is also possible for these conditions to be controlled on a local basis whenever the activities
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generate a local impact or are established in a county conservation unit. Under Brazilian law, there is strict
and joint liability for environmental damage, mechanisms for enforcement of environmental standards and
licensing requirements for polluting activities.
Individuals or entities whose conduct or activities cause harm to the environment are subject to criminal,
civil and administrative sanctions. Government environmental protection agencies may also impose
administrative sanctions for noncompliance with environmental laws and regulations, including:
_ fines;
_ partial or total suspension of activities;
_ requirements to fund reclamation and environmental projects;
_ forfeiture or restriction of tax incentives or benefits;
_ closing of establishments or operations; and
_ forfeiture or suspension of participation in credit lines with official credit establishments.
Government Regulation
As a federal state-owned company, we are subject to certain rules that limit our investments, and we are
required to submit our annual capital expenditures budget (Orçamento Anual de Investimentos, or OAI) to
the ME and the MME. Following the review by these governmental authorities, the Brazilian Congress must
approve our budget. Thus, there may be a reduction or change in our planned investments. As a result, we
may not be able to implement all of our planned investments, including those related to the expansion and
development of our oil and natural gas fields, which may adversely affect our results of operation and
financial condition.
All medium and long-term debt incurred by us or our subsidiaries requires the approval of the Finance
Executive Manager jointly with another Executive Manager within the parameters established by our
Executive Officers and the Board of Directors.
The exceptions are the issuance of public debt in the capital markets and collateralized debt obligations
and, specially until December 31, 2025 or the general Meeting that approves the amendment of Petrobras’
Bylaws whichever occurs first, the issuance of unsecured debentures, which requires the approval of our
Executive Officers, within the parameters established by our Board of Directors, and the issuance of secured
debentures, which requires the approval of our Board of Directors.
In addition, Law No. 13,303/16 requires us to define in our Bylaws the public interest we pursue and which
publicly-oriented actions we are allowed to take in the pursuit of such public interest. In order to comply
with Law No. 13,303/16, we amended our Bylaws to include the definition of public interest and to state that
the Brazilian federal government may orient our activities to pursue the public interest under certain
circumstances, which distinguishes us from any other private company operating in the oil and gas market.
See “Risks – Risk Factors – 2.a) Our controlling shareholder may pursue certain objectives that may differ
from those of certain minority shareholders, or that may affect our long-term strategy” in this annual report.
More specifically, the Brazilian federal government may guide us to take publicly-oriented obligations or
responsibilities, including executing investment projects and undertaking certain operating costs, when two
conditions are met: (i) the undertaking of obligations or responsibilities must be defined by law or
regulation and provided for in a contract or agreement entered into with any public entity with powers to
negotiate such contract or agreement; and (ii) the investment projects must have their cost and revenues
broken down and disclosed in a transparent manner.
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Our financial committee and our minority committee, exercising their advisory role to our Board of
Directors, are in charge of evaluating whether the obligations and responsibilities undertaken by us, in
connection with the pursuit of the public interest, are different from those of any other private company
operating in the oil and gas market. The evaluation by our committees is based on certain technical and
economic aspects of the planned investment projects and on the analysis of certain operating costs
previously adopted by our management.
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Material Contracts
Production Sharing Contracts (Contratos de Partilha de Produção)
First Production Sharing Contract – First Production Sharing Bidding Round
In 2013, a consortium formed by us (with a 40% interest), Shell (with a 20% interest), Total S.A. (with a 20%
interest), CNODC (with a 10% interest) and CNOOC (with a 10% interest) (the “Libra Consortium”), entered
into a production sharing contract with the Brazilian federal government, which holds 41.65% of the Libra
Consortium’s profit oil, the ANP, as regulator and supervisor, and PPSA, as manager (the “First Production
Sharing Contract”). Under the First Production Sharing Contract, the Libra Consortium was awarded the
rights and obligations to operate and explore a strategic Pre-salt area known as Libra block, located in the
Ultra-deepwaters of the Santos basin. For further information on the Production Sharing Contract, see
Exhibit 2.16 to this annual report.
Second and Third Production Sharing Contracts – Second and Third Production Sharing
Bidding Rounds
In 2017, we acquired, in partnership with other international oil companies, three offshore blocks: (i) Entorno
de Sapinhoá; (ii) Peroba; and (iii) Alto de Cabo Frio Central, in the second and third bidding rounds under the
production sharing system held by the ANP. We are the operator of these blocks (the “Second and Third
Production Sharing Contracts”). In January 2018, together with our partners, the ANP, PPSA and the
Brazilian federal government, we signed the Second and Third Production Sharing Contracts for exploration
and production of oil and natural gas. Under the production sharing system, the consortium submits to the
government a percentage of the so-called “surplus in oil profit for the Brazilian federal government,” which
is applied to revenue discounted of the production costs and royalties. The only criteria adopted by the ANP
to define the winning bidder was the amount of profit oil to the Brazilian federal government, since the
bidding rules provided for the fixed value of the signing bonus, the minimum exploratory program and the
local content commitments.
Fourth and Fifth Production Sharing Contracts – Fourth and Fifth Production Sharing
Bidding Rounds
On June 7, 2018, we acquired, together with other international companies, three offshore blocks: (i) Dois
Irmãos, (ii) Três Marias and (iii) Uirapuru (the Fourth Production Sharing Contracts and, together with the
First Production Sharing Contract and the Second and Third Production Sharing Contracts, the “Production
Sharing Contracts”). We will be the operator of these three additional blocks under the production sharing
regime. According to the regime, the consortium submits to the Brazilian federal government a percentage
of the “surplus in oil profit for the Brazilian federal government.” The only criteria adopted by the ANP to
define the winning bidder was the amount of oil profit to the Brazilian federal government. The bidding
rules established the fixed value of the signing bonus, the minimum exploratory program, and the local
content commitments. On September 28, 2018, we acquired the block Sudoeste de Tartaruga Verde under
the production sharing regime and, as a result, we will be the operator of the corresponding contract.
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Sixth Production Sharing Contract and First Transfer of Rights Surplus Production
Sharing Contracts – Sixth Production Sharing Bidding Round and First ToR Surplus
Production Sharing Bidding Rounds
On November 6, 2019, we acquired, together with other international companies, the Búzios block, and with
100% of participation, the Itapu block. On November 7, 2019, we acquired, together with another
international company, the Aram block, and we will be the operator of such block. The resulting three
production-sharing contracts were all signed on March 30, 2020. We will be the operator of these blocks
under the production-sharing regime. According to the relevant production-sharing contracts, the
appointed operator, on behalf of the parties, offers to the Brazilian federal government a percentage of the
surplus in oil profit. The only criteria adopted by the ANP to define the winning bidder was the amount of
oil profit to the Brazilian federal government, since the bidding rules provided for the fixed value of the
signing bonus, the compensation, the minimum exploratory program and the local content commitments.
Second ToR Surplus Production Sharing Bidding Round
On December 17, 2021, we acquired, together with other international companies, the exploration and
production rights over the surplus volumes in the Atapu and Sépia blocks. The production-sharing
contracts were signed on April 27, 2022 and we will be the operator of these blocks under the production-
sharing regime. According to the relevant production-sharing contracts, the appointed operator, on behalf
of the parties, offers to the Brazilian federal government a percentage of the surplus in oil profit. The only
criteria adopted by the ANP to define the winning bidder was the amount of oil profit to the Brazilian federal
government, since the bidding rules provided for the fixed value of the signing bonus, the minimum
exploratory program and the local content commitments.
Basic terms:
Operating committee. The Production Sharing Contract Consortia are managed by an operating committee
in which we, our partners, and PPSA all participate. PPSA represents the interests of the Brazilian federal
government and although it will not invest in the blocks, PPSA holds 50% of the operating committee voting
rights and also has a casting vote and veto powers, as defined in the Production Sharing Contracts.
Risks, Costs and Compensation. All exploration, development and production activities under the
Production Sharing Contracts will be conducted at the expense and risk of the members of the consortium.
For commercial discoveries of crude oil and/or natural gas in the blocks, the consortium will be entitled to
recover, on a monthly basis, (i) a portion of the production of oil and gas in the block corresponding to its
royalty expenses and (ii) the “cost oil” corresponding to costs incurred (which is the amount associated with
capital expenditures incurred and operating costs of the consortium’s exploration and production
activities), subject to the conditions, proportions and terms set forth in the Production Sharing Contracts.
In addition, for each commercial discovery, the consortia are entitled to receive, on a monthly basis, their
share of “profit oil” as defined under the Production Sharing Contracts.
Duration:
The term of the Production Sharing Contracts is 35 years.
Phases:
Our activities under the Production Sharing Contracts are divided into two phases, as follows:
Exploration phase. This phase comprises appraisal activities for purposes of determining the commerciality
of any discoveries of crude oil and natural gas. The exploration phase begins upon the execution of the
Production Sharing Contracts and will end for each discovery upon the declaration of commerciality. We will
have four years (which may be extended upon the ANP’s prior approval) to comply with the minimum work
program and other ANP-approved activities provided for in the Production Sharing Contracts. Production
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Phase. The production phase for each particular discovery begins as of the date of the declaration of
commerciality by the consortia to the ANP, and lasts until the termination of the Production Sharing
Contracts. It comprises a development period, during which we will carry out activities pursuant to a
development plan approved by the ANP.
Minimum work program:
During the exploration phase, we are required to undertake a minimum work program, as specified in the
Production Sharing Contracts. We may perform other activities outside the scope of the minimum work
program, provided that such activities are approved by the ANP.
Unitization:
A reservoir covered by a block granted to us in the Production Sharing Contracts may extend to adjacent
areas outside the block. In such case, we must notify the ANP immediately after identifying the extension
and we will be prevented from performing development and production activities within such block, until
we have negotiated unitization agreement with the third-party concessionaire or contractor who has rights
over such adjacent area, unless otherwise authorized by the ANP. The ANP will determine the deadline for
the execution of unitization agreement by the parties. If the adjacent area is not licensed (i.e., not granted
for E&P activities to any other party), the Brazilian federal government, represented by PPSA or by the ANP,
shall negotiate with us.
In compliance with regulatory requirements, the unitization agreements of the shared reservoirs of Atapu
and Sépia were signed on April 27, 2022. As a result, we are the operator of the Units.
Environmental:
We are required to preserve the environment and protect the ecosystem in the area subject to the
Production Sharing Contracts and to avoid harming local fauna, flora and natural resources. We will be liable
for damages to the environment resulting from our operations, including costs related to any remediation
measures.
Brazilian content:
The Production Sharing Contracts specify certain equipment, goods and services, as well as different levels
of required local content, in accordance with the different phases under the Production Sharing Contracts.
If we fail to comply with the Brazilian content obligations, we may be subject to fines imposed by the ANP.
Royalties and expenses with research and development:
Once we begin production in each field, members of the consortia (other than PPSA) will be required to pay
monthly royalties of 15% of the oil and natural gas production, to be recovered from a portion of the
production of oil and gas in the block. All members of the consortia (other than PPSA) will also be required
to invest 1.0% of their annual Gross Revenues from crude oil and natural gas production under the
Production Sharing Contracts in research and development activities related to the oil, gas and biofuel
sectors.
Miscellaneous provisions:
Under the Brazilian production-sharing regime, we can assign our rights and obligations inherent to our
participation above 30% in the areas in which we exercised our preemptive right to be the operator.
All members of the consortia (other than PPSA) have a right of first refusal with respect to an assignment
of rights and obligations by any other member of the consortium (other than PPSA).
The Production Sharing Contracts shall be terminated in the following circumstances: (i) the expiration of
their terms; (ii) if the minimum work program has not been completed by the end of the exploration phase;
(iii) if there has not been any commercial discovery by the end of the exploration phase; (iv) if the consortium
members (other than PPSA) exercise their withdrawal rights during the exploration phase; (v) if the
consortium refuses to execute a unitization agreement after the ANP makes such determination (which
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termination may be complete or partial) and (vi) any other basis for termination described in the Production
Sharing Contracts.
Any breach of the Production Sharing Contracts or of any regulations issued by the ANP may result in
sanctions and fines imposed by the ANP on the relevant party, in accordance with applicable legislation and
the terms of the Production Sharing Contracts. If any breach of the Production Sharing Contracts is
considered by the Brazilian federal government not to be significant, intentional, or a result of negligence,
imprudence or recklessness, or it is proved that the consortium has worked diligently to cure such breach,
the Brazilian federal government may, instead of terminating the Production Sharing Contracts, propose
that the ANP apply designated sanctions on the relevant parties.
We and other consortium members will use our best efforts to settle any disputes. If we are unable to do so,
any consortium member may submit such dispute or controversy to an ad hoc arbitration following the rules
established by the United Nations Commission On International Trade Law (UNCITRAL), or by the consent
of the parties in interest, to the International Chamber of Commerce (the “ICC”), or any other well-regarded
arbitration chamber. If a dispute involves only public administration entities, it may be submitted to
conciliation service of the Câmara de Conciliação e Arbitragem da Administração Federal, under the
Brazilian Attorney General's Office (Advocacia-Geral da União). In the event of a dispute involving non-
negotiable rights, the parties shall submit the dispute to the federal courts in Brasília, Brazil.
The Production Sharing Contracts are governed by Brazilian law.
1st cycle of the Permanent Offer under the Production Sharing Regime
On December 16, 2022, in the 1st cycle of the Permanent Offer under the Production Sharing Regime, we
acquired, together with other international companies, the exploration and production rights in the Água
Marinha and Sudoeste de Sagitário blocks. We also acquired 100% of the rights in the Norte de Brava block.
The resulting production-sharing contracts were all signed on May 31, 2023 and we will be the operator of
these blocks. The only criteria adopted by the ANP to define the winning bidder was the amount of profit
oil to the Brazilian federal government.
Amendment to the Transfer of Rights Agreement
The Transfer of Rights Agreement was executed in 2010. Its amendment was approved in 2019 by the TCU
and the CNPE and our governing bodies.
The parties involved discussed several scenarios about the revision of the original agreement, as both of
them could be simultaneously creditor and/or debtor. The amendment consolidates one such scenario,
resulting in a credit of US$9,058 billion in our favor, which was fully paid in December 2019.
In addition to such credit, the main changes as a result of the amendment to the Transfer of Rights
Agreement were (i) the local content clauses that lowered the local content requirements for the production
phase (development and production stages) and (ii) the dispute resolution provisions that became similar
to the provisions of the Production Sharing Contracts of the latest ANP bid round.
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Legal Proceedings
We are currently party to numerous legal proceedings mainly related to civil, tax, labor and environmental
issues arising in the normal course of our business. These proceedings involve claims for substantial
amounts of money and other remedies. Several individual disputes account for a significant part of the total
amount of claims against us. Our audited consolidated financial statements only include provisions for
probable and reasonably estimable losses and expenses we may incur in connection with pending
proceedings. We are also party to other claims related to administrative, corporate and criminal matters.
Some of our main legal proceedings are listed below.
Lava Jato Investigation
In 2009, the Brazilian federal police began an investigation aimed at criminal organizations engaged in
money laundering in several Brazilian states, known as Lava Jato. The Lava Jato investigation is extremely
broad and comprises numerous investigations into several criminal practices, spanning crimes and conduct
committed by individuals in different parts of the country and different sectors of the Brazilian economy.
In 2014, Lava Jato started to focus part of its investigation on irregularities involving our contractors and
suppliers and uncovered a broad payment scheme that involved a wide range of participants, including our
former personnel. It is possible that further information damaging us and our interests will come to light in
the course of the ongoing investigations of corruption by Brazilian authorities.
We are not a target of the Lava Jato investigation and we are formally recognized, by the Brazilian
authorities, as a victim of the improper payments scheme. We will continue to pursue legal measures
against companies and individuals, including former employees and politicians, who have caused financial
and image damages to us. We have been cooperating with the Brazilian Federal Prosecutor’s Office, the
Brazilian federal police, the Federal Revenue Services and other competent authorities since the beginning
of the investigation. The total amount of restitution paid to us since the beginning of Lava Jato through
December 31, 2024 was US$1,787 million (most recently, US$60 million, US$109 million and US$96 million
in 2024, 2023 and 2022, respectively).
Since 2021, Brazil’s higher courts have been deciding cases brought by criminal defendants in Lava Jato
proceedings aimed at nullifying criminal convictions relating to the investigation. As a result, some criminal
convictions have been nullified. Other cases are still in progress and their outcomes may affect our
interests.
For further information regarding proceedings arising from past investigations related to alleged
irregularities or corruption, see “Risks - Risk Factors - 1.t) We may face additional proceedings arising from
past investigations related to alleged irregularities or corruption” and Note 22 to our audited consolidated
financial statements.
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Investor Claims
Netherlands: Collective action in the Netherlands
In 2017, the Stichting Petrobras Compensation Foundation (the “Foundation”) filed an action before the
district court in Rotterdam, in the Netherlands, against us and our subsidiaries Petrobras International
Braspetro B.V. (PIBBV), Petrobras Global Finance B.V (PGF), our former joint venture Petrobras Oil & Gas
B.V. (the “POGBV”) and some of our former officers.
The Foundation allegedly represents the interests of an unidentified group of investors and alleges that,
based on the facts uncovered by the Lava Jato investigation, the defendants acted unlawfully towards
investors. Based on the allegations, the Foundation seeks declaratory relief rulings from the Dutch court.
In 2021, after a number of prior interim judgments in which the Dutch Court accepted jurisdiction over most
of the seven claims of the Foundation, the Dutch Court decided that the collective action shall continue and
that the arbitration clause of our bylaws does not bar our shareholders from access to the Dutch courts and
that the Foundation can represent the interests of these shareholders. Notwithstanding the foregoing, the
Dutch Court decided that our investors who have commenced arbitration proceedings, as well as our
investors who have commenced proceedings in which an independent public court has ruled by final
decision that they are bound by the arbitration clause, are excluded from the scope of the collective action.
In 2021 and 2022, the parties presented their written submissions regarding the merits of the case, and in
2023, the hearings for the oral arguments took place.
In July 2023, the Dutch Court issued an intermediary decision on the merits, ordering the production of
additional evidence by the parties. In addition, the Dutch Court expressed in advance their decision on the
merits of certain allegations, among which include: (i) the allegations made against PIB BV, POGBV and
certain former members of the company’s management will be rejected by the Dutch Court, (ii) the Dutch
Court declared that Petrobras and PGF acted unlawfully in relation to their investors, although the Court
expressed it does not consider itself sufficiently informed about relevant aspects of Brazilian, Argentine
and Luxembourger laws to definitively decide on the merits of the claim, and (iii) the claims under Spanish
law have expired.
On October 30, 2024, the Dutch Court handed down a judgment that broadly accepted Petrobras’
arguments against the claims brought by the Foundation on behalf of the shareholders’ interests and
decided that:
_ under Brazilian law, all the damages alleged by the Foundation qualify as indirect and cannot be
compensated; and
_ under Argentinian law, shareholders cannot, in principle, claim compensation from the company for
the damages alleged by the Foundation, and the Foundation has not demonstrated that it
represents a sufficient number of investors who could, in theory, make such a claim.
The Court therefore rejected the Foundation’s claims under Brazilian and Argentinian law, resulting in the
rejection of all claims made in favor of the shareholders.
With respect to certain bondholders, the Court found that Petrobras and PGF acted illegally under
Luxembourg law, while PGF acted illegally under Dutch law.
In addition, the Court confirmed the following points of the decision ruled in July 2023:
_ dismissal of the allegations against PIBBV, POGBV and the former CEOs of Petrobras, Maria das
Graças Silva Foster and José Sérgio Gabrielli de Azevedo; and
_ claims brought under Spanish law are time-barred.
The Foundation and PGF have filed appeals against the judgment and prior interim decisions, and they will
have the opportunity to present their arguments and respond to each other’s appeals before the Court of
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Appeals in The Hague. Petrobras retains the option to file its own appeal when responding to the
Foundation’s appeal.
Even for bondholders, the Foundation will not be able to claim compensation for damages within the scope
of the collective action. Any compensation can only be claimed in new lawsuits to be filed by or on behalf of
such investors, who would need to prove all the elements necessary for Petrobras and PGF to be held liable.
Should this happen, Petrobras will defend itself vigorously.
We have no information to project a reliable estimate of the potential loss resulting from this lawsuit, which
will depend on any subsequent legal actions. We, based on the assessments of our advisors, consider that
there are not enough indicative elements to qualify the universe of potential beneficiaries, nor to quantify
the supposedly indemnifiable damages. Therefore, it is not possible to predict at this time whether we will
be responsible for the actual payment of compensation in any future individual actions, as this analysis will
depend on the outcome of complex procedures. Furthermore, it is not possible to know which investors will
be able to file subsequent individual actions related to this matter against Petrobras.
We continue to deny the allegations presented by the Foundation and will continue to defend ourselves
vigorously.
Other Related Investor Claims
ARBITRATION IN BRAZIL
As of December 31, 2024, we were party to arbitration proceedings brought by Brazilian and foreign
investors that purchased our shares traded on the B3, alleging financial losses caused by facts uncovered
in Lava Jato.
Due to substantial uncertainties inherent to these kinds of proceedings and the highly uncertain impacts
of such allegations, it is not possible for us to identify possible risks related to this action and to produce a
reliable estimate of eventual loss.
Depending on the outcome of these claims, we may have to pay substantial amounts, which may have a
significant effect on our financial condition.
In September 2024, the collective arbitration ruled in favor of the company, with the illegitimacy of the
plaintiff association to file a collective claim being recognized by the Arbitral Tribunal. The arbitration is
confidential.
In January 2025, one of the arbitration proceedings ruled in favor of the company, establishing that the
damages alleged by investors are indirect and, therefore, not indemnifiable. The award is final and the
arbitration is confidential.
The remaining arbitration proceedings do not have a definitive judgment by the respective arbitral
tribunals. However, in one of the arbitrations, proposed by two institutional investors, in May 2020, a partial
arbitration award that indicated our liability, but did not determine our payment of amounts, nor did it end
the procedure, was issued. This arbitration is confidential, as well as the others in progress, and the partial
award represented only the position of the three arbitrators of such arbitration panel and was not
extendable to the other existing arbitrations. In July 2020, we filed a lawsuit for the annulment of this partial
arbitration award, considering our view that it contained serious flaws and improprieties. In November 2020,
the first level judge of Rio de Janeiro state court declared the partial award null. The Rio de Janeiro state
court’s decision after the appeal has not yet been released. In compliance with CAM rules, the cases are
confidential. We reiterate that we will continue to defend ourselves vigorously, out of respect for our
current shareholders, in all arbitrations to which we are a party.
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ARBITRATION AND COLLECTIVE ACTION IN ARGENTINA
In 2018, we were served with an arbitral claim filed by Consumidores Financieros Asociación Civil para su
Defensa, currently named Consumidores Damnificados Asociación Civil, (the “Association”) against us and
other individuals and legal entities, before the “Tribunal de Arbitraje General de la Bolsa de Comercio de
Buenos Aires” (“Arbitral Tribunal”).
Among other issues, the Association alleged our liability for a supposed loss of market value of our shares
in Argentina, due to proceedings related to Lava Jato.
In June 2019, the Arbitral Tribunal decided that the arbitral claim should be considered withdrawn due to
the lack of payment of the arbitral fee by the Association. The Association has filed appeals that were
rejected by the court of appeals in November 2019. The Association has appealed to the Argentinian
Supreme Court which denied the appeal, and the Association filed a new appeal to the Argentine Supreme
Court, which was also denied. As a result, the arbitration was sent to the Arbitration Court. We are unable to
provide a reliable estimate of the potential loss in this arbitration.
At the same time, the Association also filed a class action before the Civil and Commercial Court of Buenos
Aires, Argentina, against us, which we became aware of in April 2023. The Association claims Petrobras bears
responsibility for an alleged loss of market value of its securities in Argentina, as a result of allegations
made within the scope of the Lava Jato Operation and its effects on the company’s financial statements
prior to 2015. After Petrobras presented its defense in August 2023, on May 14, 2024, the Court granted
Petrobras’ request and ordered the commencement of a class certification incident. A decision regarding
this matter is still pending and the other procedural and merit defenses raised by Petrobras will be
examined at a later stage of the proceeding. We deny such allegations and will vigorously defend ourselves
against the accusations made by the Association. We are unable to provide a reliable estimate of the
potential loss in this proceeding.
Criminal Actions in Argentina
We were accused of these two criminal actions in Argentina, as described below:
_ Criminal action alleging non-compliance by us with the obligation to publish as “relevant fact” in the
Argentine market the existence of a class action claim filed by the Association, before the Judicial
Commercial Courts (Judicial Commercial Claim), pursuant to provisions of Argentine capital market
law. In March 2021, the court (Room A of the Economic Criminal Chamber) decided that this criminal
action should be transferred from the Criminal Economic Court No. 3 of the city of Buenos Aires to
the Criminal Economic Court No. 2 of the same city. We have filed procedural and merit defenses
before the criminal court, but the Criminal Economic Court No. 2 has not yet rendered a decision.
Criminal action alleging fraudulent offer of securities aggravated by allegedly having stated false data in
our financial statements issued in 2015. In October 2021, after an appeal by the Association, the Court of
Appeals revoked the lower court decision that had recognized our immunity from jurisdiction and
recommended that the lower court take steps to certify whether we could be considered criminally immune
in Argentina. After reassessing the issue, the lower court denied our immunity from jurisdiction we appealed
to the Court of Appeals. In December 2022, the Court again considered the first instance decision to be
premature, determining that a third decision be issued. In May 2023, the lower court denied the recognition
of our immunity from jurisdiction. We then filed an appeal and the Court of Appeals overturned the lower
court decision, but on December 20, 2024, the Court of Cassation granted an appeal filed by the Association
and denied our immunity from jurisdiction. We subsequently appealed to the Supreme Court, seeking to
reinstate the Court of Appeals' decision. On December 27, 2024, prior to a final ruling by the Supreme Court
on the matter, the lower court issued an order for the continuation of the proceedings and a precautionary
measure against Petrobras. This order is currently under appeal in the Court of Appeals. On another
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procedural front, in September 2022, the decision that had recognized that the Association could not act as
a representative of financial consumers was reformed by the Court of Cassation after an appeal by the
Association. In November 2022, we filed an appeal against this decision, which was denied by the Argentine
Supreme Court. We have filed other procedural defenses, which may be rediscussed again at later stages of
the proceedings. This criminal case is originally presided by the Criminal Economic Court No. 2 of the city of
Buenos Aires.
Sete Brasil’s Investor Claim and Mediation Procedure
We are currently a party to a lawsuit in the District Court for the District of Columbia in Washington, D.C.
(the “D.C. District Court”) filed by EIG in 2016, concerning its indirect purchase of equity interests in Sete
Brasil, a company created in order to build rigs with high local content. In this proceeding, EIG alleges that
we induced investors to invest in Sete Brasil and that we were among the parties responsible for the
financial crisis of Sete Brasil, which filed judicial recovery proceedings (recuperação judicial), in Brazil.
The D.C. District Court denied our motion to dismiss on various grounds including sovereign immunity and
ruled that the claims could proceed to discovery, which is the exchange of legal information and known facts
of a case between the parties. During 2020 and 2021, the parties engaged in extensive fact and expert
Discovery, and filed motions for summary judgment.
On August 8, 2022, the D.C. District Court issued a ruling holding us liable for the plaintiffs’ claims but denied
the plaintiffs’ summary judgment motion with respect to damages, and any award of damages on these
claims would have to be proven by EIG at trial. In the same ruling, the D.C. District Court denied our motion
for summary judgment to dismiss all of the plaintiffs' claims due to our immunity from jurisdiction and
deferred ruling on two procedural issues. On August 18, 2022, we filed a notice of appeal to inform the Court
that we intend to appeal the denial of our motion to dismiss.
On August 26, 2022, we requested a stay of the lawsuit until the judgment of the aforementioned appeal,
and the stay was granted by the judge on October 26, 2022.
The United States Court of Appeals for the District of Columbia Circuit denied our appeal in June 2024. We
submitted a request to review the issue, which was rejected on July 24, 2024. As a result, the process, which
had been suspended by the lower court on October 26, 2022, due to the filling of the appeal by Petrobras,
resumed its course.
In another motion filed by EIG, on August 26, 2022, the District Court of Amsterdam granted an attachment
order against certain of our assets in the Netherlands. Leave to make such pre-judgement attachments was
granted by the Amsterdam District Court on a summary judgment basis and serves to guarantee the
satisfaction of EIG's claims in the aforementioned U.S. proceedings.
On March 7, 2025, we reached an agreement to settle the lawsuit with EIG. Under the terms of the
settlement, we paid EIG US$ 283 million. In return, EIG requested the dismissal of the lawsuit pending in the
District Court for the District of Columbia, the cancellation of the pre-judgment attachment of Petrobras's
assets in the Netherlands, as well as the release of any rights related to the dispute.
The settlement does not constitute an admission of fault or wrongdoing by Petrobras and is entered in the
best interests of Petrobras and its shareholders, considering the peculiarities of U.S. law applicable to the
disputes, as well as the stage of the lawsuit and the characteristics of litigation before the U.S. Federal
Courts.
We were also a party to arbitrations in Brazil filed by investors of Sete Brasil. One of them was concluded in
2017 and the other arbitrations were finished in 2020. In 2017 and 2020, two favorable arbitral awards were
granted to us. In 2020, we disclosed the settlement of three other arbitrations related to the investment in
Sete Brasil.
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In December 2024, the judge issued a bankruptcy ruling for Sete Brasil. However, this decision was
suspended after Sete Brasil filed an appeal, which remains under judicial review.
We no longer hold any direct or indirect equity in the companies of the Sete Brasil Group.
Other Legal proceedings
Labor Proceedings
RMNR
The Minimum Compensation by Level and Work Regime (RMNR) consists of a guaranteed minimum
compensation for employees, based on salary level, work regime, and geographical location. This
compensation policy was created and implemented by Petrobras in 2007 through collective bargaining with
union representatives, and approved in employee assemblies. However, the formula used to calculate this
minimum compensation was subsequently challenged in court by employees and unions.
The Brazilian Superior Labor Court (TST) established a position that was partially contrary to the company,
deciding to exclude some components from the calculation. The Brazilian Federal Supreme Court (STF),
upon accepting the company's appeal, recognized that the calculation formula used by the company is valid
and in accordance with what was negotiated between the parties.
As there were several lawsuits at various procedural stages, the company monitors the application of the
STF’s ruling to the respective cases, which are being closed as they progress through the Judiciary.
Applicable rate
Due to the legislative change (Law 14.905/24) and case law regarding the correction of labor debts, the
company is assessing the impacts on the reported liability.
Unification of Fields
We filed five arbitrations under the ICC administration challenging the ANP’s decision to unify our
unconnected oil fields (Parque das Baleias, Tupi and Cernambi; Baúna and Piracaba; Tartaruga Verde and
Tartaruga Mestiça; Sururu and Berbigão). The Parque das Baleias arbitration was terminated by means of
an agreement executed by the parties.
In the case of the Tartaruga Mestiça and Tartaruga Verde arbitration, the arbitral tribunal recognized its
competence to decide on the unification of such fields. The ANP filed a lawsuit in order to annul the arbitral
award, and, the Federal Court of Rio de Janeiro has allowed the arbitration to continue.
In relation to the Baúna and Piracaba arbitration, the judicial injunction that has kept it suspended was
reversed.
In addition, the BM-S-11 consortium, formed with Shell and Petrogal, of which we are the operator,
challenged the ANP’s decision on unifying Tupi and Cernambi fields. The suspension of the arbitration was
reverted by BM-S-11 Consortium in Brazilian Superior Court.
The Baúna and Piracaba and Tupi and Cernambi arbitration proceedings are ongoing and the Sururu and
Berbigão arbitration was recently filled. .
Petros
Since 2013, lawsuits classified as “Petros Class Actions” were filed by unions and associations related to
Petros, whereby we are being sued to contribute directly to the pension plan scheme, suspension of the
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balancing plan (plano de equacionamento), payment of increased benefits to participants and beneficiaries,
payment of all actuarial and financial insufficiencies of the plan and estimated economic value of the
participants in solving the entity's accumulated deficits based on allegation of fraud and mismanagement
of Petros.
There are also lawsuits filed by Petros against us, requesting i) payment of contributions for a reinstated
employee (which was settled by an agreement), ii) payment of employer contributions for increased judicial
benefits and iii) payment of amounts to restore the mathematical reserve. We filed a lawsuit against Petros
to obtain the reimbursement of amounts paid by us as a consequence of judicial rulings according to which
Petrobras and Petros would have a joint and several liability and we also filed an action for accounting due
to agreements (Convênio PETROBRAS x PETROS – 1984 e Convênio PETROBRAS x PETROS – 1986) signed
by us and Petros.
There are no final decisions on the aforementioned proceedings as of the date of this annual report.
Natural Gas Distributors
Since December 2021, we were sued by some natural gas distributors and/or public entities. The requests
in the lawsuit seek the extension of the terms of natural gas supply contracts that would have expired in
December 2021. Since the prices of natural gas showed a large increase in the last months of 2021, we
offered to the natural gas distributors proposals for new contracts with prices aligned with the current
natural gas market. However, some natural gas distributors and/or public entities intend to avoid the
adjusted prices alleging that we abused our economic power. In some cases, judges granted the injunction
to maintain the previous contracts’ prices. We were able to execute agreements to resolve the arbitrations
and lawsuits in the cases in which the injunctions were granted.
Applicable rate
Due to the legislative change (Law 14.905/24) and case law regarding the correction of civil debts, the
company is assessing the impacts on the reported liability.
Environmental
Ibama issued fines because of a leak from the OSPAR oil pipeline in Paraná State in July 2000. After the
administrative process, there was a court proceeding, and the current decision was unfavorable to us. We
appealed and decision on our appeal to the Superior Court is pending.
For further information on our material legal proceedings, see Note 19 to our audited consolidated financial
statements.
Tax Proceedings
We are currently party to legal proceedings relating to tax claims. For further information on our material
tax proceedings, see Note 19 to our audited consolidated financial statements.
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Tax
Tax Strategy and Effect of Taxes on Our Income
In January 2023, our Board of Directors approved a Tax Policy, in line with the continuous improvement of
our governance, establishing principles and guidelines to properly drive our leaders and professionals’
conduct in regard to the development of our tax strategy.
Our Tax Policy aims to comply with the tax legislation of Brazil and of the countries where we operate,
defining our strategy based on the technical interpretation of the rules, standards and processes, aligned
with the business purpose and our tax risk management. We assume the commitment of not holding equity
interests in low-tax jurisdictions, as well as observing the transfer pricing rules provided for in Brazil and in
the countries where we operate, in relation to all transactions with related or unrelated parties, when
required by law.
Our tax strategy outlines the compliance with tax laws of Brazil and other countries. We also aim at engaging
with tax authorities and other public authorities in an ethical and transparent manner, based on mutual
respect, cooperation and in compliance with the Petrobras’ Code of Ethical Conduct. Considering that we
are the largest taxpayer in Brazil, our operations can result in various effects on tax collection at the federal,
state, and municipal levels, as well as on government take applicable to the production of oil and natural
gas.
We are subject to tax on our income at a Brazilian statutory corporate rate of 34%, comprising of a 25% rate
of income tax and a social contribution tax at a 9% rate. Since 2015, we have been recognizing the accounting
results of our foreign subsidiaries for Brazilian income tax purposes based on Brazilian statutory corporate
rates as established by Law No. 12,973/2014.
In addition to taxes paid on behalf of consumers to the Brazilian federal government, as well as state and
municipal governments, such as the value-added tax (ICMS), we are required to pay three main charges on
our oil production activities in Brazil under the scope of the ANP: (i) royalties, (ii) special participation and
(iii) retention bonuses. See “Government Take in Different Regulatory Regimes” below and “Risk Factors -
2.a) Our controlling shareholder may pursue certain objectives that may differ from those of certain minority
shareholders, or that may affect our long-term strategy” in this annual report.
In December 2023, Constitutional Amendment (EC) No. 132/2023 was enacted, establishing the Tax Reform
on consumption, to be implemented from 2026.
As main measures, the EC created the Contribution on Goods and Services (CBS) and the Tax on Goods and
Services (IBS) replacing the PIS/Pasep and COFINS contributions, the Tax on Operations relating to the
Circulation of Goods and on the Provision of Services Interstate and Intermunicipal Transport and
Communication (ICMS) and the Service Tax (ISS). Furthermore, the EC also created the Selective Tax (IS).
The implementation of these new taxes requires the promulgation of complementary laws and other legal
regulations. In January 2025, Complementary Law No. 214 was published to regulate the Tax Reform on
consumption.
The transition to CBS will begin in 2026, with its definitive implementation in 2027, when PIS/Pasep and
COFINS contributions will be extinguished. In the case of IBS, the transition period will be longer, also
starting in 2026, but with the termination of ICMS and ISS only in 2033.
IS collection will begin in 2027 when most industrialized products will be exempt from the Tax on
Industrialized Products (IPI). The IPI will not be extinguished, but it will not be applied cumulatively with the
Selective Tax.
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Changes to the corporate income tax laws in certain countries as of 2022 may impact our activities and
results. As a reference, we perform our activities through the implementation of Pillar II in target-countries
that follow the OECD Guidelines (such as the Netherlands, Spain, Colombia and Singapore). In the case of
the United States, the Inflation Reduction Act of 2022 introduced a Corporate Alternative Minimum Tax
(CAMT) of 15% of the “adjusted financial statement income” effective for tax years beginning in 2023. Brazil
has published Law No. 15.079 on December 27, 2024, implementing one of the mechanisms designed in the
Pillar II as of 2025, by instituting the Additional CSLL, which is aligned with the Qualified Domestic Top Up
Tax (QDMTT). In both Pillar II and CAMT, the countries are seeking a minimum effective tax rate of 15% on
the generated profits before tax. In Brazil, we emphasize the recent changes in the transfer price legislation
aligned with the OCDE Guidelines implemented by Law No. 14.596 published on June 14, 2023.
For more information regarding Pillar II, see Note 17.4. to our audited consolidated financial statements.
For further information regarding our Tax Policy or our tax collection disclosed in our Tax Report, please
visit our website at www.petrobras.com.br/ir.
Government Take in Different Regulatory Regimes
Government take is a financial compensation due to the Brazilian Federal Government, paid by companies
that explore and produce oil and natural gas in Brazilian territory. The collection is made to the National
Treasury Secretariat and the amounts are distributed to the beneficiaries defined by legislation, based on
calculations performed by the ANP. Government take consists of royalties, special participation, signature
bonuses and payment for the occupation or retention of the area. Its objective is to make pecuniary
retribution to society for the exploitation of these nonrenewable resources.
In accordance with Law No. 9,478/1997 and due to the concession contracts entered into with ANP, the
exploration and production activities of oil and natural gas are subject to the payment of the following
government shares:
_ Royalties established in the concession contracts at a rate of 10% of the gross production revenue
based on the reference prices for crude oil or natural gas established by ANP in its regulatory acts.
When establishing the royalty rates, ANP also considers the geological risks and expected
productivity levels for each concession and may provide a reduction of the rate to an amount
corresponding to at least 5%. Most of our crude oil and natural gas production currently pays the
maximum royalty rate.
_ Special participation at a rate ranging from zero to 40% of the net revenue from the production of
fields that reach high production volumes or profitability, according to the criteria established in the
applicable legislation. The calculation takes into account the Gross Revenue (oil and gas production
volume multiplied by price) from each production field, based on the reference prices for crude oil or
natural gas established by Decree No. 2,705/1998 and ANP regulatory acts, minus the royalties paid,
exploration investments, operational costs, and applicable depreciation and taxes adjustments. In
2024, payments of this government share were made in 12 of our fields, namely, Barracuda,
Berbigão, Jubarte, Leste do Urucu, Marlim Leste, Marlim Sul, Rio Urucu, Roncador, Sapinhoá, Sururu,
Tartaruga Verde, and Tupi.
_ The signing bonus will have its minimum value established in the bidding notice and will correspond
to the payment offered in the proposal to obtain the concession. It must be paid at the time of
signing the concession contract.
_ Payment for the retention or occupation of contracted areas for exploration and production, at a
rate established by ANP in the relevant bid notices, based on the size, location, and geological
characteristics of the concession block.
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Laws No. 9,478/1997 and No. 12351/2010 also require producers in onshore fields to pay landowners a share
equivalent to a percentage of the quota ranging from 0.5% to 1.0% of the field's production, at the
discretion of the ANP, which must be included in the concession contracts and also in the production sharing
contracts.
Below, we describe how government take works in each of the different regimes of exploration and
production of oil, natural gas, and other fluid hydrocarbons we deal with.
REGULATORY REGIMES: CONCESSION
_ Contracting through bidding process.
_ Brazilian federal government awards the exploration right to winning companies.
_ Production belongs to the concessionaire.
TRANSFER OF RIGHTS
_ Petrobras directly contracted for production.
_ Right to produce up to five billion barrels of equivalent oil.
PRODUCTION SHARING
_ Specific regime for Pre-salt areas and others considered strategic.
_ Hiring by a bidding process, where the winning companies form a consortium with Pré-Sal Petróleo
S.A (PPSA), representing the Brazilian federal government.
_ The largest supply of surplus oil for the Brazilian federal government wins.
_ Shared production between the State and the contracted consortium, each one’s share calculated
by discounting the royalties due and all investment and operating expenses (cost in oil).
Government Take
Frequency
Concession
Sharing
Transfer of
Rights
Royalties
Monthly
10% on the gross income of the field,
which can be reduced up to 5%
15% on Gross
Revenue from the
field
10% on Gross
Revenue from the
field
Special Participation
Quarterly
Rates from zero to 40% (nominal)
on net revenue of fields with high
production
Not applicable
Not applicable
Signature Bonus
Upon contract
signature
Amount offered by companies in
bidding
Predefined value
Not applicable
Retention of Area
Yearly
Value per Km² defined in the notice
and concession contract (updated
by IGP DI index)
Not applicable
Not applicable
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Taxation Model for the Oil and Gas Industry (Repetro-SPED)
Law No. 13,586/2017 outlined a new taxation model for the oil and gas industry and, along with the Decree
No. 9,128/2017, established a new special regime for exploration, development and production of oil, gas
and other liquid hydrocarbons named Repetro-Sped, which will expire in December 2040.
This regime provides for the continuation of total tax relief over goods imported with temporary
permanence in Brazil, as previously established by the former Repetro (special customs regime for the
export and import of goods designated to exploration and production of oil and natural gas reserves), and
adds this relief to goods permanently held in Brazil. This benefit allowed for the migration of all the goods
acquired in the former Repetro to the Repetro-Sped.
In 2018, we started to transfer the ownership of oil and gas assets under this regime from our foreign
subsidiaries to our parent company and the joint ventures (consortia) in Brazil. The transfer was completed
in 2022.
In addition, the legislation prescribes the Repetro-Industrialização, a special tax regime, regulated in 2019,
which exempts acquisitions from the oil and gas supply chain established in Brazil.
Following the creation of Repetro-Sped and Repetro-Industrialização, some Brazilian states, pursuant to a
decision by the Brazilian National Council of Finance Policies (CONFAZ), agreed to grant tax incentives
relating to the value added tax (ICMS) over transactions under these regimes to the extent each state enacts
its specific regulation providing for the tax relief on the oil and gas industry.
Regarding the new changes in Brazilian law due to the Tax Reform, above mentioned in chapter Tax Strategy
and Effect of Taxes on Our Income, we do not anticipate significant impacts in our results at this moment.
Taxation Relating to the ADSs and our Common and Preferred Shares
The following summary contains a description of material Brazilian and U.S. federal income tax
considerations that may be relevant to the purchase, ownership and disposition of preferred or common
shares or ADSs by a holder. This summary does not describe any tax consequences arising under the laws
of any state, locality or taxing jurisdiction other than Brazil and the United States.
This summary is based upon the tax laws of Brazil and the United States as in effect on the date of this
annual report, which are subject to change (possibly with retroactive effect). This summary is also based
upon the representations of the depositary and on the assumption that the obligations in the deposit
agreement and any related documents will be performed in accordance with their respective terms.
This description is not a comprehensive description of the tax considerations that may be relevant to any
particular investor, including tax considerations that arise from rules that are generally applicable to all
taxpayers or to certain classes of investors or rules that investors are generally assumed to know. Holders
of common or preferred shares or ADSs should consult their own tax advisors as to the tax consequences
of the acquisition, ownership and disposition of common or preferred shares or ADSs.
There is no income tax treaty between the United States and Brazil. In recent years, the tax authorities of
Brazil and the United States have held discussions that may culminate in such a treaty. We cannot predict,
however, whether or when a treaty will enter into force or how it will affect the U.S. holders of common or
preferred shares or ADSs.
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Brazilian Tax Considerations
General
The following discussion summarizes the material Brazilian tax consequences of the acquisition, ownership
and disposition of preferred or common shares or ADSs, as the case may be, by a holder that is not deemed
to be domiciled in Brazil for purposes of Brazilian taxation, also called a non-Brazilian holder.
Under Brazilian law, investors (non-Brazilian holders) may invest in the preferred or common shares under
CMN Resolution No. 4,373 or under Law No. 4,131/1962. The rules of CMN Resolution No. 4,373 allow foreign
investors to invest in almost all instruments and to engage in almost all transactions available in the
Brazilian financial and capital markets, provided that certain requirements are met. In accordance with CMN
Resolution No. 4,373, the definition of foreign investor includes individuals, legal entities, mutual funds and
other collective investment entities, domiciled or headquartered abroad.
Pursuant to this rule, foreign investors must: (i) appoint at least one representative in Brazil with powers to
perform actions relating to their foreign investment (such as registration and keeping updated records of
all transactions with the Central Bank of Brazil); (ii) complete the appropriate foreign investor registration
form; (iii) register as a foreign investor with the CVM; and (iv) register the foreign investment with the
Central Bank of Brazil.
Securities and other financial assets held by foreign investors pursuant to CMN Resolution No. 4,373 must
be registered or maintained in deposit accounts or under the custody of an entity duly licensed by the CVM.
In addition, securities trading is restricted to transactions carried out in the stock exchanges or organized
over-the-counter markets authorized by the CVM.
Taxation of Dividends
Generally speaking, dividends paid by us, including stock dividends and other dividends paid in property to
the Depositary in respect of the ADSs, or to a non-Brazilian holder in respect of the preferred or common
shares, are not subject to withholding income tax in Brazil, to the extent that such amounts are related to
profits generated after January 1, 1996.
We must pay to our shareholders (including non-Brazilian holders of common or preferred shares or ADSs)
interest on the amount of dividends payable to them, updated by the SELIC rate, from the end of each fiscal
year through the date of effective payment of those dividends. These interest payments are considered
fixed-yield income and are subject to withholding income tax at varying rates depending on the length of
period of interest accrual. The tax rate for payments made to beneficiaries resident or domiciled in Brazil
varies from 15%, in case of interest accrued for a period greater than 720 days, 17.5% in case of interest
accrued for a period between 361 and 720 days, 20% in case of interest accrued for a period between 181
and 360 days, and to 22.5%, in case of interest accrued for a period up to 180 days. However, when the
beneficiary is a non-Brazilian holder, under CMN Resolution No. 4,373 rules, the general applicable
withholding income tax rate over interest is 15% except in case the beneficiary is resident or domiciled in a
country or other jurisdiction that does not impose income tax or imposes it at a maximum income tax rate
lower than 17% (a Low or Nil Tax Jurisdiction) or, based on the position of the Brazilian tax authorities, a
country or other jurisdiction where the local legislation does not allow access to information related to the
shareholding composition of legal entities, to their ownership or to the identity of the effective beneficiary
of the income attributed to shareholders (the “Non-Transparency Rule”), when the applicable withholding
income tax rate will be 25%. See “Tax – Taxation of Dividends – Clarifications on Non-Brazilian Holders
Resident or Domiciled in a Low or Nil Tax Jurisdiction” in this annual report.
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Taxation on Interest on Capital
Any payment of interest on capital to holders of ADSs or preferred or common shares, whether or not they
are Brazilian residents, is subject to Brazilian withholding income tax at the rate of 15% at the time we record
such liability, whether or not the effective payment is made at that time. See “Shareholder Information –
Shareholder Remuneration – Payment of Dividends and Interest on Capital” in this annual report. In the case
of non-Brazilian residents that are resident in a Low or Nil Tax Jurisdiction (including in the view of Brazilian
authorities the jurisdictions to which the Non-Transparency Rule applies), the applicable withholding
income tax rate is 25%. See “Tax – Taxation of Dividends – Clarifications on Non-Brazilian Holders Resident
or Domiciled in a Low or Nil Tax Jurisdiction” in this annual report. The payment of interest with respect to
updating recorded distributions by the SELIC rate that is applicable to payments of dividends applies
equally to payments of interest on capital. The determination of whether or not we will make distributions
in the form of interest on capital or in the form of dividends is made by our Board of Directors at the time
distributions are to be made. We cannot determine how our Board of Directors will make these
determinations in connection with future distributions.
Taxation of Gains
For purposes of Brazilian taxation on capital gains, two types of non-Brazilian holders have to be
considered: (i) non-Brazilian holders of ADSs, preferred shares or common shares that are not resident or
domiciled in a Low or Nil Tax Jurisdiction, and that, in the case of preferred or common shares, have
registered before the Central Bank of Brazil and the CVM in accordance with CMN Resolution No. 4,373; and
(ii) any other non-Brazilian holder, including non-Brazilian holders who invest in Brazil not in accordance
with CMN Resolution No. 4,373 (including registration under Law No. 4,131/1962) and who are resident or
domiciled in a Low or Nil Tax Jurisdiction. See “Tax – Taxation of Dividends – Clarifications on Non- Brazilian
Holders Resident or Domiciled in a Low or Nil Tax Jurisdiction” in this annual report.
According to Law No. 10,833/2003, capital gains realized on the disposition of assets located in Brazil by
non-Brazilian holders, whether or not to other non-residents and whether made outside or within Brazil,
may be subject to taxation in Brazil. With respect to the disposition of common or preferred shares, as they
are assets located in Brazil, the non-Brazilian holder may be subject to income tax on any gains realized,
following the rules described below, regardless of whether the transactions are conducted in Brazil or with
a Brazilian resident. It is possible to argue that the ADSs do not fall within the definition of assets located
in Brazil for the purposes of this law, but there is still neither pronunciation from tax authorities nor judicial
court rulings in this respect. Therefore, we are unable to predict whether such understanding will prevail in
the courts of Brazil.
Although there are grounds to sustain otherwise, the deposit of preferred or common shares in exchange
for ADSs may be subject to Brazilian taxation on capital gains if the acquisition cost of the preferred or
common shares is lower than the average price per preferred or common share.
The difference between the acquisition cost and the market price of the preferred or common shares will be
considered realized capital gain that is subject to taxation as described below. There are grounds to sustain
that such taxation is not applicable with respect to non-Brazilian holders registered under the rules of CMN
Resolution No. 4,373 and not resident or domiciled in a Low or Nil Tax Jurisdiction.
The withdrawal of ADSs in exchange for preferred or common shares should not be considered as giving
rise to a capital gain subject to Brazilian income tax, provided that on receipt of the underlying preferred or
common shares, the non-Brazilian holder complies with the registration procedure with the Central Bank of
Brazil as described below in “Registered Capital.”
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Capital gains realized by a non-Brazilian holder on a sale or disposition of preferred or common shares
carried out on a Brazilian stock exchange (which includes transactions carried out on the organized over-
the-counter market) are:
_ exempt from income tax when the non-Brazilian holder (i) has registered its investment in
accordance with CMN Resolution No. 4,373 and (ii) is not resident or domiciled in a Low or Nil Tax
Jurisdiction;
_ subject to an income tax at a 25% rate, in cases of gains realized by a non-Brazilian holder resident
or domiciled in a Low or Nil Tax Jurisdiction or a jurisdiction to which the Non-Transparency Rule
applies. In this case, a withholding income tax at a rate of 0.005% of the sale value is levied on the
transaction which can be offset against the eventual income tax due on the capital gain; or
_ in all other cases, including a case of capital gains realized by a non-Brazilian holder that is not
registered in accordance with CMN Resolution No. 4,373, subject to income tax at the following
progressive rates: 15% that do not exceed R$5 million, 17.5% on the gains between R$5 million and
R$10 million, 20% on the gains between R$10 million and R$30 million and 22.5% on the gains that
exceed R$30 million. In these cases, a withholding income tax at a rate of 0.005% of the sale value is
levied on the transaction, which can be offset against the eventual income tax due on the capital
gain.
Any capital gains realized on a disposition of preferred or common shares that is carried out outside the
Brazilian stock exchange are subject to income tax above rates in case of gains realized by a non-Brazilian
holder that is domiciled or resident in a Low or Nil Tax Jurisdiction or a jurisdiction to which the Non-
Transparency Rule applies. In this last case, for the capital gains related to transactions conducted on the
Brazilian non-organized over-the-counter market with intermediation, the withholding income tax of
0.005% will also apply and can be offset against the eventual income tax due on the capital gain.
In the case of a redemption of preferred or common shares or ADSs or a capital reduction made by us, the
positive difference between the amount received by the non-Brazilian holder and the acquisition cost of the
preferred or common shares or ADSs redeemed or reduced is treated as capital gain derived from the sale
or exchange of shares not carried out on a Brazilian stock exchange market and is therefore generally
subject to the above rates. See “Tax – Taxation of Dividends – Clarifications on Non-Brazilian Holders
Resident or Domiciled in a Low or Nil Tax Jurisdiction” in this annual report.
Any exercise of preemptive rights relating to the preferred or common shares will not be subject to Brazilian
taxation. Any gain on the sale or assignment of preemptive rights will be subject to Brazilian income taxation
according to the same rules applicable to the sale or disposition of preferred or common shares.
No assurance can be made that the current preferential treatment of non-Brazilian holders of the ADSs and
some non-Brazilian holders of the preferred or common shares under CMN Resolution No. 4,373 will
continue to apply in the future.
Additional Rules Regarding Taxation of Gains
Law No. 13,259/2016 established progressive income tax rates applicable to capital gains derived from the
disposition of assets by Brazilian individuals, providing for rates that range from 15% to 22.5% depending
on the amount of the gain recognized by the Brazilian individual, as follows: (i) 15% on gains not exceeding
R$5 million; (ii) 17.5% on gains that exceed R$5 million and do not exceed R$10 million; (iii) 20% on gains
that exceed R$10 million and do not exceed R$30 million; and (iv) 22.5% on gains exceeding R$30 million.
Pursuant to Section 18 of Law No. 9,249/95, the tax treatment applicable to capital gains earned by Brazilian
individuals also applies to capital gains earned by non-Brazilian residents (except in cases that remain
subject to the application of specific rules).
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Clarifications on Non-Brazilian Holders Resident or Domiciled in a Low or Nil Tax
Jurisdiction
Law No. 9,779/1999 states that, except for limited prescribed circumstances, income derived from
transactions by a person resident or domiciled in a Low or Nil Tax Jurisdiction will be subject to withholding
income tax at the rate of 25%. A Low or Nil Tax Jurisdiction is generally considered to be a country or other
jurisdiction which does not impose any income tax or which imposes such tax at a maximum rate lower than
17%. Under certain circumstances, the Non-Transparency Rule is also taken into account for determining
whether a country or other jurisdiction is a Low or Nil Tax Jurisdiction. In addition, Law No. 11,727/2008
introduced the concept of a “privileged tax regime,” which is defined as a tax regime which (i) does not tax
income or taxes it at a maximum rate lower than 17%; (ii) grants tax benefits to non-resident entities or
individuals (a) without the requirement to carry out a substantial economic activity in the country or other
jurisdiction or (b) contingent on the non-exercise of a substantial economic activity in the country or other
jurisdiction; (iii) does not tax or that taxes foreign source income at a maximum rate lower than 17%; or (iv)
does not provide access to information related to shareholding composition, ownership of assets and rights
or economic transactions carried out. We believe that the best interpretation of Law No. 11,727/2008 is that
the concept of a “privileged tax regime” will apply solely for purposes of the transfer pricing rules in export
and import transactions, deductibility for Brazilian corporate income taxes and the thin capitalization rules
and, would therefore generally not have an impact on the taxation of a non-Brazilian holder of preferred or
common shares or ADSs, as discussed herein. However, we are unable to ascertain whether the privileged
tax regime concept will also apply in the context of the rules applicable to Low or Nil Tax Jurisdictions,
although the Brazilian tax authorities appear to agree with our position, in view of the provisions of the
Withholding Income Tax Manual (MAFON – 2023), issued by the Brazilian Revenue Service.
Taxation of Foreign Exchange Transactions (“IOF/Exchange”)
Brazilian law imposes the IOF/Exchange on the conversion of reais into foreign currency and on the
conversion of foreign currency into reais. Currently, for most foreign currency exchange transactions, the
rate of IOF/Exchange is 0.38%. However, foreign exchange transactions related to inflows of funds to Brazil
for investments made by foreign investors in the Brazilian financial and capital markets are generally
subject to IOF/Exchange at a 0% rate. Foreign exchange transactions related to outflows of proceeds from
Brazil in connection with investments made by foreign investors in the Brazilian financial and capital
markets are also subject to the IOF/Exchange tax at a 0% rate. This 0% rate applies to payments of dividends
and interest on capital received by foreign investors with respect to investments in the Brazilian financial
and capital markets, such as investments made by a non-Brazilian holder as described in CMN Resolution
No. 4,373. The Brazilian tax authorities has permission by law to increase such rates at any time, up to 25%
of the amount of the foreign exchange transaction, but not with retroactive effect.
Taxation on Bonds and Securities Transactions (“IOF/Bonds”)
Brazilian tax legislation imposes IOF/Bonds on transactions involving equity securities, bonds and other
securities, including those carried out on a Brazilian stock exchange. The rate of IOF/Bonds applicable to
transactions involving preferred or common shares is currently zero. However, the Brazilian tax authorities
may increase such rate at any time up to 1.5% of the transaction amount per day, but the tax increase cannot
be applied retroactively.
The IOF on transfer of shares traded on the Brazilian Stock Exchange which have the specific purpose of
backing the issuance of depositary receipts traded abroad, have been reduced from 1.5% to zero since
December 24, 2013.
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Other Brazilian Taxes
There are no Brazilian inheritance, gift or succession taxes applicable to the ownership, transfer or
disposition of preferred or common shares or ADSs by a non-Brazilian holder, except for gift and inheritance
taxes which are levied by certain states of Brazil on gifts made or inheritances bestowed by a non-Brazilian
holder to individuals or entities resident or domiciled within such states in Brazil. There are no Brazilian
stamp, issue, registration, or similar taxes or duties payable by holders of preferred or common shares or
ADSs.
Registered Capital
The amount of an investment in preferred or common shares held by a non-Brazilian holder who obtains
registration under CMN Resolution No. 4,373, or by the depositary representing such holder, is eligible for
registration with the Central Bank of Brazil; and such registration allows the remittance outside Brazil of
foreign currency, converted at the commercial market rate, acquired with the proceeds of distributions on,
and amounts realized with respect to dispositions of, such preferred or common shares. The amount
registered ( “Registered Capital”) for each preferred or common share purchased as part of the international
offering or purchased in Brazil after the date hereof, and deposited with the depositary, will be equal to its
purchase price (in U.S. dollars). The Registered Capital for a preferred or common share that is withdrawn
upon surrender of an ADS will be the U.S. dollar equivalent of:
_ the average price of a preferred or common share on the Brazilian stock exchange on which the
highest volume of such shares were traded on the day of withdrawal; or
_ if no preferred or common shares were traded on that day, the average price on the Brazilian stock
exchange on which the highest volume of preferred or common shares were traded in the 15 trading
sessions immediately preceding the date of such withdrawal.
The U.S. dollar value of the average price of preferred or common shares is determined on the basis of the
average of the U.S. dollar/real commercial market rates quoted by the Central Bank of Brazil information
system on that date (or, if the average price of preferred or common shares is determined under the second
option above, price will be determined by the average quoted rates verified on the same 15 preceding
trading sessions as described above).
A non-Brazilian holder of preferred or common shares may be subject to delays in effecting such
registration, which in turn may delay remittances abroad. Such a delay may adversely affect the amount, in
U.S. dollars, received by the non-Brazilian holder. See “Risks – Risk Factors – Taxation Relating to the ADSs
and our Common and Preferred Shares” in this annual report.
U.S. Federal Income Tax Considerations
This summary describes material U.S. federal income tax consequences that may be relevant to a U.S.
Holder (as defined below) from the ownership and disposition of common or preferred shares or ADSs. This
summary is based on the U.S. Internal Revenue Code of 1986, as amended (the “Code”), its legislative
history, existing and proposed U.S. Treasury regulations promulgated thereunder, published rulings by the
U.S. Internal Revenue Service (the “IRS”), and court decisions, all as in effect as of the date hereof, and all of
which are subject to change or differing interpretations, possibly with retroactive effect. This summary does
not purport to be a comprehensive description of all of the tax consequences that may be relevant to a
decision to hold or dispose of common or preferred shares or ADSs. This summary applies only to
purchasers of common or preferred shares or ADSs who hold the common or preferred shares or ADSs as
“capital assets” (generally, property held for investment), and does not apply to special classes of holders
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such as dealers or traders in securities or currencies, holders whose functional currency is not the U.S. dollar,
holders of 10% or more of our shares, measured by voting power or value (taking into account shares held
directly or through depositary arrangements), tax-exempt organizations, partnerships or partners therein,
financial institutions, life insurance companies, holders liable for the alternative minimum tax, securities
traders who elect to account for their investment in common or preferred shares or ADSs on a mark-to-
market basis, persons that enter into a constructive sale transaction with respect to common or preferred
shares or ADSs, persons holding common or preferred shares or ADSs in a hedging transaction or as part of
a straddle or conversion transaction, or nonresident alien individuals present in the United States for more
than 182 days in a taxable year. Moreover, this summary addresses only U.S. federal income tax
consequences and does not address state, local or foreign taxes or the U.S. federal estate and gift taxes or
the Medicare tax on net investment income.
EACH HOLDER SHOULD CONSULT ITS OWN TAX ADVISOR CONCERNING THE OVERALL TAX
CONSEQUENCES IN ITS PARTICULAR CIRCUMSTANCES, INCLUDING THE CONSEQUENCES UNDER LAWS
OTHER THAN U.S. FEDERAL INCOME TAX LAWS ADDRESSED HEREIN, OF AN INVESTMENT IN COMMON
OR PREFERRED SHARES OR ADSs.
Shares of our preferred stock will be treated as equity for U.S. federal income tax purposes. In general, a
holder of an ADS will be treated as the holder of the shares of common or preferred stock represented by
those ADSs for U.S. federal income tax purposes, and no gain or loss will be recognized if you exchange ADSs
for the shares of common or preferred stock represented by that ADS.
In this discussion, references to ADSs refer to ADSs with respect to both common and preferred shares, and
references to a “U.S. Holder” are to a beneficial owner of a common or preferred share or ADS that is:
_ an individual who is a citizen or resident of the United States;
_ a corporation organized under the laws of the United States, any state thereof, or the District of
Columbia; or
_ otherwise subject to U.S. federal income taxation on a net basis with respect to the share or the ADS.
Taxation of Distributions
The amount of any cash and the value of any property we distribute that is paid out of our current or
accumulated earnings and profits, as determined for U.S. federal income tax purposes, will generally be
includible in taxable income as ordinary dividend income when such distribution is received by the
depositary, in the case of ADSs, or by the U.S. Holder in the case of a holder of common or preferred shares.
The amount of any distribution will include distributions characterized as interest on capital and the amount
of Brazilian tax withheld on the amount distributed. The amount of a distribution paid in reais will be
measured by reference to the exchange rate for converting reais into U.S. dollars in effect on the date the
distribution is received by the depositary, in the case of ADSs, or by a U.S. Holder in the case of a holder of
common or preferred shares. If the depositary, in the case of ADSs, or U.S. Holder in the case of a holder of
common or preferred shares, does not convert such reais into U.S. dollars on the date it receives them, it is
possible that the U.S. Holder will recognize foreign currency loss or gain, which would be U.S. source ordinary
loss or gain, when the reais are converted into U.S. dollars. Dividends paid by us will not be eligible for the
dividends received deduction allowed to corporations under the Code.
The U.S. dollar amount of dividends received by a non-corporate U.S. Holder with respect to the ADSs will
generally be subject to taxation at preferential rates if the dividends are “qualified dividends.” Subject to
certain exceptions for short-term and hedged positions, dividends paid on the ADSs will be treated as
qualified dividends if (i) the ADSs are readily tradable on an established securities market in the United
States and (ii) we were not, in the year prior to the year in which the dividend was paid, and are not, in the
year in which the dividend is paid, a “passive foreign investment company” as defined for U.S. federal income
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tax purposes (a PFIC). The ADSs are listed on the NYSE, and will qualify as readily tradable on an established
securities market in the United States so long as they are so listed. Based on our audited consolidated
financial statements and relevant market and shareholder data, we believe that we should not be treated
as a PFIC for U.S. federal income tax purposes with respect to the 2024 or 2023 taxable years. In addition,
based on our audited consolidated financial statements and our current expectations regarding the value
and nature of our assets, the sources and nature of our income, and relevant market and shareholder data,
we do not anticipate becoming a PFIC for our 2025 taxable year. Based on existing guidance, it is not clear
whether dividends received with respect to the shares will be treated as qualified dividends, because the
shares are not themselves listed on a U.S. exchange. U.S. Holders of our ADSs should consult their own tax
advisors regarding the availability of the reduced dividend tax rate in the light of their particular
circumstances.
Subject to generally applicable limitations and conditions, Brazilian withholding tax on dividends with
respect to the shares or ADSs that is paid at the appropriate rate applicable to the U.S. Holder may be
eligible for credit against such U.S. Holder’s U.S. federal income tax liability. These generally applicable
limitations and conditions include requirements adopted by the IRS in regulations promulgated in
December 2021 and any Brazilian tax generally will need to satisfy these requirements in order to be eligible
to be a creditable tax for a U.S. Holder. In the case of a U.S. holder that consistently elects to apply a
modified version of these rules under recently issued temporary guidance and complies with specific
requirements set forth in such guidance, the Brazilian tax on dividends will be treated as meeting the new
requirements and therefore as a creditable tax. In the case of all other U.S. Holders, the application of these
requirements to the Brazilian tax on dividends is uncertain and we have not determined whether these
requirements have been met. If the Brazilian dividend tax is not a creditable tax or the U.S. Holder does not
elect to claim a foreign tax credit for any foreign income taxes paid or accrued in the same taxable year, the
U.S. Holder may be able to deduct the Brazilian tax in computing such U.S. Holder’s taxable income for U.S.
federal income tax purposes. Dividend distributions will constitute income from sources without the United
States and, for U.S. Holders that elect to claim foreign tax credits, generally will constitute “passive category
income” for foreign tax credit purposes.
The availability and calculation of foreign tax credits and deductions for foreign taxes depend on a U.S.
Holder’s particular circumstances and involve the application of complex rules to those circumstances. The
temporary guidance discussed above also indicates that the Treasury and the IRS are considering proposing
amendments to the December 2021 regulations and that the temporary guidance can be relied upon until
additional guidance is issued that withdraws or modifies the temporary guidance. U.S. Holders should
consult their own tax advisors regarding the application of these rules to their particular situations.
Holders of ADSs that are foreign corporations or nonresident alien individuals (non-U.S. Holders) generally
will not be subject to U.S. federal income tax, including withholding tax, on distributions with respect to
shares or ADSs that are treated as dividend income for U.S. federal income tax purposes unless such
dividends are effectively connected with the conduct by the holder of a trade or business in the United
States.
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Taxation of Capital Gains
Upon the sale or other disposition of a share or an ADS, a U.S. Holder will generally recognize U.S. source
capital gain or loss for U.S. federal income tax purposes, equal to the difference between the amount
realized on the disposition and the U.S. Holder’s tax basis in such share or ADS. Any gain or loss will be long-
term capital gain or loss if the shares or ADSs have been held for more than one year. Non-corporate U.S.
Holders of shares or ADSs may be eligible for a preferential rate of U.S. federal income tax in respect of
long-term capital gains. Capital losses may be deducted from taxable income, subject to certain limitations.
A U.S. Holder generally will not be entitled to credit any Brazilian tax imposed on the sale or other
disposition of the shares against each U.S. Holder’s U.S. federal income tax liability, except in the case of a
U.S. Holder that consistently elects to apply a modified version of the U.S. foreign tax credit rules that is
permitted under recently issued temporary guidance and complies with the specific requirements set forth
in such guidance. Additionally, capital gain or loss recognized by a U.S. Holder on the sale or other
disposition of the shares generally will be U.S. source gain or loss for U.S. foreign tax credit purposes.
Consequently, even if the withholding tax qualifies as a creditable tax, a U.S. Holder may not be able to credit
the tax against its U.S. federal income tax liability unless such credit can be applied (subject to generally
applicable conditions and limitations) against tax due on other income treated as derived from foreign
sources. If the Brazilian tax is not a creditable tax for a U.S. holder, the tax would reduce the amount realized
on the sale or other disposition of the shares even if the U.S. Holder has elected to claim a foreign tax credit
for other taxes in the same year. The temporary guidance discussed above also indicates that the Treasury
and the IRS are considering proposing amendments to the December 2021 regulations and that the
temporary guidance can be relied upon until additional guidance is issued that withdraws or modifies the
temporary guidance. U.S. Holders should consult their own tax advisors regarding the application of the
foreign tax credit rules to a sale or other disposition of the shares and any Brazilian tax imposed on such
sale or disposition.
Information Reporting and Backup Withholding
The payment of dividends on, and proceeds from the sale or other disposition of, the ADSs or common or
preferred shares to a U.S. Holder within the United States (or through certain U.S. related financial
intermediaries) will generally be subject to information reporting, and may be subject to “backup
withholding” unless the U.S. Holder (i) is an exempt recipient, and demonstrates this fact when so required,
or (ii) timely provides a taxpayer identification number and certifies that no loss of exemption from backup
withholding has occurred and otherwise complies with applicable requirements of the backup withholding
rules. Backup withholding is not an additional tax. The amount of any backup withholding collected from a
payment to a U.S. Holder will be allowed as a credit against the U.S. Holder’s U.S. federal income tax liability
and may entitle the U.S. Holder to a refund, so long as the required information is furnished to the IRS in a
timely manner.
U.S. Holders should consult their own tax advisors about any additional reporting requirements that may
arise as a result of their purchasing, holding or disposing of our ADSs, or common or preferred shares.
A Holder that is not a “United States person” (as defined in the Code) generally will be exempt from these
information reporting requirements and backup withholding tax, but may be required to comply with certain
certification and identification procedures in order to establish its eligibility for such exemption.
Specified Foreign Financial Assets
Certain U.S. Holders that own “specified foreign financial assets” with an aggregate value in excess of
US$50,000 on the last day of the taxable year or US$75,000 at any time during the taxable year are generally
required to file an information statement along with their tax returns, currently on IRS Form 8938, with
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respect to such assets. “Specified foreign financial assets” include any financial accounts held at a non-U.S.
financial institution, as well as securities issued by a non-U.S. issuer (which would include our common and
preferred shares and ADSs) that are not held in accounts maintained by financial institutions. Higher
reporting thresholds apply to certain individuals living abroad and to certain married individuals.
Regulations extend this reporting requirement to certain entities that are treated as formed or availed of
to hold direct or indirect interests in specified foreign financial assets based on certain objective criteria.
U.S. Holders who fail to report the required information could be subject to substantial penalties. In
addition, the statute of limitations for assessment of tax would be suspended, in whole or part. U.S. Holders
should consult their own tax advisors concerning the application of these rules to their investment,
including the application of the rules to their particular circumstances.
Taxation Relating to PGF’s Notes
The following summary contains a description of material Brazilian, Dutch, European Union and U.S. federal
income tax considerations that may be relevant to the purchase, ownership and disposition of PGF’s debt
securities (the “notes”). This summary does not describe any tax consequences arising under the laws of
any state, locality or taxing jurisdiction other than the Netherlands, Brazil and the United States.
This summary is based on the tax laws of the Netherlands, Brazil and the United States as in effect on the
date of this annual report, which are subject to change (possibly with retroactive effect). This description is
not a comprehensive description of all tax considerations that may be relevant to any particular investor,
including tax considerations that arise from rules generally applicable to all taxpayers or to certain classes
of investors or that investors are generally assumed to know. Prospective purchasers of notes should
consult their own tax advisors regarding the tax consequences of the acquisition, ownership and disposition
of the notes.
There is no tax treaty to avoid double taxation between Brazil and the United States. In recent years, the
tax authorities of Brazil and the United States have held discussions that may culminate in such a treaty.
We cannot predict, however, whether or when a treaty will enter into force or how it will affect the U.S.
Holders of notes.
Dutch Taxation
This section is a general summary and it only outlines certain material Dutch tax consequences to holders
of the notes that are not resident nor deemed to be resident of the Netherlands for tax purposes in
connection with the acquisition, ownership and disposal of notes issued by PGF. This summary does not
purport to describe all possible Dutch tax considerations or consequences that may be relevant to a holder
or prospective holder of the notes and does not purport to deal with the tax consequences applicable to all
categories of investors, some of which (such as trusts or similar arrangements) may be subject to special
rules. In view of its general nature, this general summary should therefore be treated with appropriate
caution.
This section is based on the tax laws of the Netherlands, published regulations thereunder and published
authoritative case law, all as in effect on the date hereof, including the tax rates applicable on the date
hereof, and all of which are subject to change or to different interpretation, possibly with retroactive effect.
Any such change may invalidate the contents of this section, which will not be updated to reflect such
change. Where the text refers to the “Netherlands” or “Dutch”, it refers only to the part of the Kingdom of
the Netherlands located in Europe. In addition, the summary is based on the assumption that the notes
issued by PGF do not qualify as equity for Dutch tax purposes.
For Dutch tax purposes, a holder of notes may include, without limitation:
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_ an owner of one or more notes who, in addition to the title to such notes, has an economic interest
in such notes;
_ a person who or an entity that holds the entire economic interest in one or more notes;
_ a person who or an entity that holds an interest in an entity, such as a partnership or a mutual fund,
that is transparent for Dutch tax purposes, the assets of which comprise one or more notes; and
_ an individual who or an entity that does not have the legal title to the notes, but to whom the notes
are attributed based either on such individual or entity holding a beneficial interest in the notes or
based on specific statutory provisions, including statutory provisions pursuant to which the notes
are attributed to an individual who is, or who has directly or indirectly inherited the notes from a
person who was, the settlor, grantor or similar originator of a trust, foundation or similar entity that
holds the notes.
The discussion below is included for general information purposes only and is not Dutch tax advice or a
complete description of all Dutch tax consequences relating to the acquisition, holding and disposal of the
notes. Holders or prospective holders of notes should consult their own tax advisers as to the Dutch tax
consequences of purchasing, including, without limitation, the consequences of the receipt of interest and
the sale or other disposition of notes or coupons, in light of their particular circumstances.
Withholding Tax
All payments of interest and principal made by or on behalf of PGF under the notes to holders of notes may
be made free of withholding or deduction of, for or on account of any taxes of any nature imposed, levied,
withheld or assessed by the Netherlands or any political subdivision or taxing authority thereof or therein
except that Dutch withholding tax at a rate of 25.8% (rate for 2024 and 2025) may apply with respect to
payments of interest made or deemed to be made by or on behalf of PGF, if such payments are made or
deemed to be made to an entity related (gelieerd) to PGF (within the meaning of the Dutch Withholding Tax
Act 2021, Wet Bronbelasting 2021 see below), if such related entity:
_ is considered to be resident (gevestigd) in a jurisdiction that is listed in the yearly updated Dutch
Regulation on low-taxing states and non-cooperative jurisdictions for tax purposes (Regeling
laagbelastende staten en niet-coöperatieve rechtsgebieden voor belastingdoeleinden) (a "Listed
Jurisdiction"); or
_ has a permanent establishment located in a Listed Jurisdiction to which the interest payment is
attributable; or
_ is entitled to the interest payment with the main purpose or one of the main purposes of avoiding
taxation for another person or entity and there is an artificial arrangement or transaction or a series
of artificial arrangements or transactions; or
_ is not considered to be the recipient of the interest in its jurisdiction of residence because such
jurisdiction treats another entity as the recipient of the interest (a hybrid mismatch); or
_ is not resident in any jurisdiction (also a hybrid mismatch); or
_ is a reverse hybrid (within the meaning of Article 2(12) of the Dutch Corporate Income Tax Act; Wet
op de vennootschapsbelasting 1969), if and to the extent (x) there is a participant in the reverse
hybrid holding a Qualifying Interest in the reverse hybrid, (y) the jurisdiction of residence of the
participant holding the Qualifying Interest in the reverse hybrid treats the reverse hybrid as
transparent for tax purposes and (z) such participant would have been subject to Dutch withholding
tax in respect of the payments of interest without the interposition of the reverse hybrid;
_ all within the meaning of the Dutch Withholding Tax Act 2021.
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RELATED ENTITY
For purposes of the Dutch Withholding Tax Act 2021, an entity is considered a related entity in respect of
PGF if:
_ such entity has a Qualifying Interest (as defined below) in PGF; or
_ PGF has a Qualifying Interest in such entity; or
_ a third party has a Qualifying Interest in both PGF and such entity.
The term "Qualifying Interest" means a direct or indirectly held interest – either by an entity individually or
jointly if an entity is part of a collaborating group (samenwerkende groep) – that enables such entity or such
collaborating group to exercise a definite influence over another entity's decisions, such as PGF decisions,
and allows it to determine the other entity’s activities (within the meaning of case law of the European Court
of Justice on the right of freedom of establishment (vrijheid van vestiging).
Taxes on Income and Capital Gains
Please note that the summary in this section does not describe the Dutch tax considerations for:
_ holders of the notes if such holders, and in the case of an individual, his or her partner or certain of
his or her relatives by blood or marriage in the direct line (including foster children), have a
substantial interest (aanmerkelijk belang) or deemed substantial interest (fictief aanmerkelijk
belang) in PGF under the Dutch Income Tax Act 2001 (Wet inkomstenbelasting 2001). Generally
speaking, a holder of notes has a substantial interest in PGF if it has, directly or indirectly (and, in the
case of an individual, alone or together with certain relatives) (i) the ownership of, a right to acquire
the ownership of, or certain rights over, shares representing 5% or more of either the total issued
and outstanding capital of PGF or the issued and outstanding capital of any class of shares of PGF,
or (ii) the ownership of, or certain rights over, profit participating certificates (winstbewijzen) that
relate to 5% or more of either the annual profit or the liquidation proceeds of PGF. A deemed
substantial interest may arise if a substantial interest (or part thereof) has been disposed of, or is
deemed to have been disposed of, on a non-recognition basis;
_ pension funds, investment institutions (fiscale beleggingsinstellingen), exempt investment
institutions (vrijgestelde beleggingsinstellingen) (as defined in the Dutch Corporate Income Tax Act
1969 (Wet op de vennootschapsbelasting 1969)) and other entities that are, in whole or in part, not
subject to or exempt from Dutch corporate income tax; and
_ holders of notes who are individuals and for whom the notes or any benefit derived from the notes
are a remuneration or deemed to be a remuneration for activities performed by such holders or
certain individuals related to such holders (as defined in the Dutch Income Tax Act 2001).
A holder of notes will not be subject to any Dutch taxes on income or capital gains in respect of the notes,
including such tax on any payment under the notes or in respect of any gain realized on the disposal,
deemed disposal, redemption or exchange of the notes, provided that:
_ such holder is neither a resident nor deemed to be a resident of the Netherlands;
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_ such holder does not have, and is not deemed to have, an enterprise or an interest in an enterprise
(as defined in the Dutch Income Tax Act 2001 and the Dutch Corporate Income Tax Act 1969, as
applicable) that, in whole or in part, is either effectively managed in the Netherlands or carried on
through a (deemed) permanent establishment (vaste inrichting) or a permanent representative
(vaste vertegenwoordiger) in the Netherlands and to which enterprise or part of an enterprise the
notes are attributable;
_ if such holder is an individual, such income or capital gains do not form “benefits from miscellaneous
activities in the Netherlands” (resultaat uit overige werkzaamheden in Nederland), including without
limitation activities in the Netherlands with respect to the notes that exceed “normal asset
management” (normaal, actief vermogensbeheer);
_ if such holder is an entity, the holder is not entitled to a share in the profits of an enterprise nor a
co-entitlement to the net worth of an enterprise, which is effectively managed in the Netherlands,
other than by way of securities, and to which enterprise the notes are attributable; and
_ if such holder is an individual, the holder is not entitled to a share in the profits of an enterprise that
is effectively managed in the Netherlands, other than by way of securities, and to which enterprise
the notes are attributable.
A holder of notes will not be treated as a resident of the Netherlands by reason only of the execution,
delivery or enforcement of its rights and obligations connected to the notes, the issue of the notes or the
performance by PGF of its obligations under the notes.
Gift and Inheritance Taxes
No gift or inheritance taxes will arise in the Netherlands with respect to an acquisition or deemed acquisition
of notes by way of a gift by, or on the death of, a holder of notes who is neither resident nor deemed to be
resident in the Netherlands for the relevant provisions, unless:
_ in case of a gift of the notes under a suspensive condition by an individual who at the date of the gift
was neither resident nor deemed to be resident in the Netherlands, such individual is resident or
deemed to be resident in the Netherlands at the date of (i) the fulfillment of the condition or (ii)
his/her death and the condition of the gift is fulfilled after the date of his/her death; or
_ in case of a gift of notes by an individual who at the date of the gift or, in case of a gift under a
suspensive condition, at the date of the fulfillment of the condition was neither resident nor deemed
to be resident in the Netherlands, such individual dies within 180 days after the date of the gift or
fulfillment of the condition, while being resident or deemed to be resident in the Netherlands.
For purposes of Dutch gift and inheritance taxes, amongst others, a person who holds the Dutch nationality
will be deemed to be resident in the Netherlands if such person has been resident in the Netherlands at any
time during the ten years preceding the date of the gift or such person’s death. Additionally, for purposes
of Dutch gift tax, amongst others, a person not holding the Dutch nationality will be deemed to be resident
in the Netherlands if such person has been resident in the Netherlands at any time during the twelve months
preceding the date of the gift.
Value added tax (VAT)
No Dutch VAT will be payable by a holder of the notes in respect of any payment in consideration for the
issue of the notes or with respect to any payment by PGF of principal, interest or premium (if any) on the
notes.
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Other Taxes and Duties
No other Dutch registration taxes, or any other similar taxes of a documentary nature, such as capital tax or
stamp duty, will be payable in the Netherlands by or on behalf of a holder of the notes by reason only of the
purchase, ownership and disposal of the notes.
Brazilian Taxation
The following discussion is a summary of the Brazilian tax considerations relating to an investment in the
notes by a non-resident of Brazil. The discussion is based on the tax laws of Brazil as in effect on the date
hereof and is subject to any change in Brazilian law that may come into effect after such date. The
information set forth below is intended to be a general discussion only and does not address all possible
consequences relating to an investment in the notes.
INVESTORS SHOULD CONSULT THEIR OWN TAX ADVISERS AS TO THE CONSEQUENCES OF
PURCHASING THE NOTES, INCLUDING, WITHOUT LIMITATION, THE CONSEQUENCES OF THE RECEIPT OF
INTEREST AND THE SALE, REDEMPTION OR REPAYMENT OF THE NOTES OR COUPONS.
Generally, an individual, entity, trust or organization domiciled for tax purposes outside Brazil, or a
“Nonresident,” is taxed in Brazil only when income is derived from Brazilian sources or when the transaction
giving rise to such earnings involves assets in Brazil. Therefore, any gains or interest (including original issue
discount), fees, commissions, expenses and any other income paid by PGF in respect of the notes issued by
them in favor of non-resident holders are not subject to Brazilian taxes.
Interest, fees, commissions, expenses and any other income payable by us as guarantor resident in Brazil to
a non-resident are generally subject to income tax withheld at source. The rate of withholding income tax
in respect of interest payments is generally (in case of fixed yields – See “Taxation of Dividends”) 15%,
unless (i) the holder of the notes is resident or domiciled in a “tax haven jurisdiction” (that is deemed to be
a country or jurisdiction which does not impose any tax on income or which imposes such tax at a maximum
effective rate lower than 17% or where the local legislation imposes restrictions on disclosing the identities
of shareholders, the ownership of investments, or the ultimate beneficiary of earnings distributed to the
non-resident – “tax haven jurisdiction”), in which case the applicable rate is 25% or (ii) such other lower rate
as provided for in an applicable tax treaty between Brazil and another country where the beneficiary is
domiciled. In case the guarantor is required to assume the obligation to pay the principal amount of the
notes, Brazilian tax authorities could attempt to impose withholding income tax at the rate of up to 25% as
described above. Although Brazilian legislation does not provide a specific tax rule for such cases and there
is no official position from tax authorities or precedents from the Brazilian court regarding the matter, we
believe that the remittance of funds by us as a guarantor for the payment of the principal amount of the
notes will not be subject to income tax in Brazil, because the mere fact that the guarantor is making the
payment does not convert the nature of the principal due under the notes into income of the beneficiary.
If the payments with respect to the notes are made by us, as provided for in the guaranties, the non-resident
holders will be indemnified so that, after payment of all applicable Brazilian taxes collectable by
withholding, deduction or otherwise, with respect to principal, interest and additional amounts payable with
respect to the notes (plus any interest and penalties thereon), a non-resident holder will receive an amount
equal to the amount that such non-resident holder would have received as if no such Brazilian taxes (plus
interest and penalties thereon) were withheld. The Brazilian obligor will, subject to certain exceptions, pay
additional amounts in respect of such withholding or deduction so that the non-resident holder receives
the net amount due.
Gains on the sale or other disposition of the notes made outside of Brazil by a non-resident, other than a
branch or a subsidiary of Brazilian resident, to another non-resident are not subject to Brazilian income tax.
Annual Report and Form 20-F 2024 I 313
Legal and Tax
In addition, payments made from Brazil are subject to the tax on foreign exchange transactions
(“IOF/Câmbio”), which is levied on the conversion of Brazilian currency into foreign currency and on the
conversion of foreign currency into Brazilian currency at a general rate of 0.38%. Other IOF/Câmbio rates
may apply to specific transactions. In any case, the Brazilian federal government may increase, at any time,
such rate up to 25% but only with respect to future transactions.
Generally, there are no inheritance, gift, succession, stamp, or other similar taxes in Brazil with respect to
the ownership, transfer, assignment or any other disposition of the notes by a non-resident, except for gift
and inheritance taxes imposed by some Brazilian states on gifts or bequests by individuals or entities not
domiciled or residing in Brazil to individuals or entities domiciled or residing within such states.
U.S. Federal Income Taxation
The following summary sets forth material United States federal income tax considerations that may be
relevant to the beneficial owner of a note that is, for U.S. federal income purposes, a citizen or resident of
the United States or a domestic corporation or that otherwise is subject to U.S. federal income taxation on
a net income basis in respect of the notes (a “U.S. Holder”). This summary is based upon the Code, its
legislative history, existing and proposed U.S. Treasury regulations promulgated thereunder, published
rulings by the IRS, and court decisions, all as in effect as of the date hereof, all of which are subject to change
or differing interpretations, possibly with retroactive effect. This summary does not purport to discuss all
aspects of the U.S. federal income taxation which may be relevant to special classes of investors, such as
financial institutions, insurance companies, dealers or traders in securities or currencies, securities traders
who elect to account for their investment in notes on a mark-to-market basis, regulated investment
companies, tax-exempt organizations, partnerships or partners therein, holders that are subject to the
alternative minimum tax, certain short-term holders of notes, persons that hedge their exposure in the
notes or hold notes as part of a position in a “straddle” or as part of a hedging transaction or “conversion
transaction” for U.S. federal tax purposes, persons that enter into a “constructive sale” transaction with
respect to the notes, nonresident alien individuals present in the United States for more than 182 days in a
taxable year, or U.S. Holders whose functional currency is not the U.S. dollar. U.S. Holders should be aware
that the U.S. federal income tax consequences of holding the notes may be materially different for investors
described in the prior sentence.
In addition, this summary addresses only U.S. federal income tax consequences and does not discuss any
foreign, state or local tax considerations or the Medicare tax on net investment income or under special
timing rules prescribed under section 451(b) of the Code. This summary only applies to original purchasers
of notes who have purchased notes at the original issue price and hold the notes as “capital assets”
(generally, property held for investment). U.S. Holders of notes denominated in a currency other than US$
should consult their tax advisors regarding the application of foreign currency gain or loss rules to the notes
and the treatment of any foreign currency received in respect of the notes.
EACH INVESTOR SHOULD CONSULT ITS OWN TAX ADVISOR CONCERNING THE OVERALL TAX
CONSEQUENCES IN ITS PARTICULAR CIRCUMSTANCES, INCLUDING THE CONSEQUENCES UNDER LAWS
OTHER THAN U.S. FEDERAL INCOME TAX LAWS ADDRESSED HEREIN, OF AN INVESTMENT IN THE NOTES.
Annual Report and Form 20-F 2024 I 314
Legal and Tax
Payments of Interest
Payment of “qualified stated interest,” as defined below, on a note (including any amounts withheld and
additional amounts paid with respect thereto, if any) generally will be taxable to a U.S. Holder as ordinary
interest income when such interest is accrued or is actually or constructively received, in accordance with
the U.S. Holder’s applicable method of accounting for U.S. federal tax purposes. In general, if a note is issued
with an “issue price” that is less than its “stated redemption price at maturity” by an amount equal to or
greater than a de minimis amount, such note will be considered to have “original issue discount,” or OID for
U.S. tax purposes. For this purpose, the “issue price” generally is the first price at which a substantial amount
of such notes is sold to investors for money. A U.S. Holder should consult its own tax advisors regarding the
issue price for a note, in particular where the note has been issued pursuant to an exchange offer or a
reopening or the note’s terms have been amended. The stated redemption price at maturity of a note
generally includes all payments on the note other than payments of qualified stated interest. The term
“qualified stated interest” generally means stated interest that is unconditionally payable in cash or
property (other than debt instruments of the issuer) at least annually during the entire term of a note at a
single fixed rate of interest, or subject to certain conditions, based on one or more interest indices.
In general, if a note is issued with OID at or above a de minimis threshold, a U.S. Holder, whether such holder
uses the cash or the accrual method of tax accounting, will be required to include in gross income as ordinary
interest income the sum of the “daily portions” of OID on the note, if any, for all days during the taxable
year that the U.S. Holder owns the note. The daily portions of OID on a note are determined by allocating to
each day in any accrual period a ratable portion of the OID allocable to that accrual period. In general, in the
case of an initial holder, the amount of OID on a note allocable to each accrual period is determined by (i)
multiplying the “adjusted issue price,” as defined below, of the note at the beginning of the accrual period
by the yield to maturity of the note, and (ii) subtracting from that product the amount of qualified stated
interest allocable to that accrual period. U.S. Holders should be aware that they generally must include OID
in gross income as ordinary interest income for U.S. federal income tax purposes as it accrues, in advance of
the receipt of cash attributable to that income. The “adjusted issue price” of a note at the beginning of any
accrual period will generally be the sum of its issue price (generally including accrued interest, if any) and
the amount of OID allocable to all prior accrual periods, reduced by the amount of all payments other than
payments of qualified stated interest (if any) made with respect to such note in all prior accrual periods. The
term “qualified stated interest” generally means stated interest that is unconditionally payable in cash or
property (other than debt instruments of the issuer) at least annually during the entire term of a note at a
single fixed rate of interest, or subject to certain conditions, based on one or more interest indices.
Subject to generally applicable limitations and conditions, Brazilian interest withholding tax paid at the
appropriate rate applicable to the U.S. Holder may be eligible for credit against such U.S. Holder’s U.S.
federal income tax liability. These generally applicable limitations and conditions include requirements
adopted by the IRS in regulations promulgated in December 2021and any Brazilian tax generally will need
to satisfy these requirements in order to be eligible to be a creditable tax for a U.S. Holder. In the case of a
U.S. Holder that consistently elects to apply a modified version of these rules under recently issued
temporary guidance and complies with specific requirements set forth in such guidance, the Brazilian tax
on interest generally will be treated as meeting the new requirements and therefore as a creditable tax. In
the case of all other U.S. Holders, the application of these requirements to the Brazilian tax on interest is
uncertain and we have not determined whether these requirements have been met. If the Brazilian interest
tax is not a creditable tax or the U.S. Holder does not elect to claim a foreign tax credit for any foreign income
taxes, the U.S. Holder may be able to deduct the Brazilian tax in computing such U.S. Holder’s taxable income
for U.S. federal income tax purposes. Interest and additional amounts will constitute income from sources
without the United States and, for U.S. Holders that elect to claim foreign tax credits, generally will
constitute “passive category income” for foreign tax credit purposes.
Annual Report and Form 20-F 2024 I 315
Legal and Tax
The availability and calculation of foreign tax credits and deductions for foreign taxes depend on a U.S.
holder’s particular circumstances and involve the application of complex rules to those circumstances. The
temporary guidance discussed above also indicates that the Treasury and the IRS are considering proposing
amendments to the December 2021 regulations and that the temporary guidance can be relied upon until
additional guidance is issued that withdraws or modifies the temporary guidance. U.S. holders should
consult their own tax advisors regarding the application of these rules to their particular situations.
Sale or Disposition of Notes
A U.S. Holder generally will recognize capital gain or loss upon the sale, exchange, retirement or other
disposition of a note in an amount equal to the difference between the amount realized upon such sale,
exchange, retirement or other disposition (other than amounts attributable to accrued qualified stated
interest, which will be taxed as such) and such U.S. Holder’s adjusted tax basis in the note. A U.S. Holder’s
adjusted tax basis in the note generally will equal the U.S. Holder’s cost for the note increased by any
amounts included in gross income by such U.S. Holder as OID, if any, and reduced by any payments other
than payments of qualified stated interest on that note.
The gain or loss realized by a U.S. Holder will be capital gain or loss, and will be long-term capital gain or loss
if the notes were held for more than one year. The net amount of long-term capital gain recognized by an
individual holder generally is subject to taxation at preferential rates. Capital losses may be deducted from
taxable income, subject to certain limitations.
A U.S. Holder generally will not be entitled to credit any Brazilian tax imposed on the sale or other
disposition of the Notes against such U.S. Holder’s U.S. federal income tax liability, except in the case of a
U.S. Holder that consistently elects to apply a modified version of the U.S. foreign tax credit rules that is
permitted under recently issued temporary guidance and complies with the specific requirements set forth
in such guidance. Additionally, capital gain or loss realized by a U.S. Holder on the sale, exchange, retirement
or other disposition of a note generally will be U.S. source gain or loss for U.S. federal income tax purposes.
Consequently, even if the withholding tax qualifies as a creditable tax, a U.S. Holder may not be able to credit
the tax against its U.S. federal income tax liability unless such credit can be applied (subject to generally
applicable conditions and limitations) against tax due on other income treated as derived from foreign
sources. If the Brazilian tax is not a creditable tax, the tax would reduce the amount realized on the sale or
other disposition of the Notes even if the U.S. Holder has elected to claim a foreign tax credit for other taxes
in the same year. The temporary guidance discussed above also indicates that the Treasury and the IRS are
considering proposing amendments to the December 2021 regulations and that the temporary guidance
can be relied upon until additional guidance is issued that withdraws or modifies the temporary guidance.
U.S. Holders should consult their own tax advisors regarding the application of the foreign tax credit rules
to a sale or other disposition of the Notes and any Brazilian tax imposed on such sale or disposition.
Backup Withholding and Information Reporting
A U.S. Holder may, under certain circumstances, be subject to “backup withholding” with respect to certain
payments to that U.S. Holder, unless the holder (i) is an exempt recipient, and demonstrates this fact when
so required, or (ii) provides a correct taxpayer identification number, certifies that it is not subject to backup
withholding and otherwise complies with applicable requirements of the backup withholding rules. Any
amount withheld under these rules generally will be creditable against the U.S. Holder’s U.S. federal income
tax liability. While a Holder that is not a “United States person” (as defined in the Code) generally is exempt
from backup withholding, such Holder may, in certain circumstances, be required to comply with certain
information and identification procedures in order to prove entitlement to this exemption.
Annual Report and Form 20-F 2024 I 316
Legal and Tax
Holders should consult their own tax advisors about any additional reporting requirements that may arise
as a result of their purchasing, holding or disposing of the notes.
Specified Foreign Financial Assets
Certain U.S. Holders that own “specified foreign financial assets” with an aggregate value in excess of
US$50,000 on the last day of the taxable year or US$75,000 at any time during the taxable year are generally
required to file an information statement along with their tax returns, currently on IRS Form 8938, with
respect to such assets. “Specified foreign financial assets” include any financial accounts held at a non-U.S.
financial institution, as well as securities issued by a non-U.S. issuer (which would include the notes) that
are not held in accounts maintained by financial institutions. Higher reporting thresholds apply to certain
individuals living abroad and to certain married individuals. Regulations extend this reporting requirement
to certain entities that are treated as formed or availed of to hold direct or indirect interests in specified
foreign financial assets based on certain objective criteria. U.S. Holders who fail to report the required
information could be subject to substantial penalties. In addition, the statute of limitations for assessment
of tax would be suspended, in whole or part. Holders should consult their own tax advisors concerning the
application of these rules to their investment in the notes, including the application of the rules to their
particular circumstance.
Additional Information
Annual Report and Form 20-F 2024 I 318
Additional Information
List of Exhibits
No.
Description
1.1
Amended Bylaws of Petróleo Brasileiro S.A.- Petrobras, dated as of April 25, 2024.
2.1
Indenture, dated as of December 15, 2006, between Petrobras International Finance Company and The Bank
of New York, as Trustee (incorporated by reference to Exhibit 4.9 to the Registration Statement of Petrobras
and Petrobras International Finance Company on Form F-3, filed with the Securities and Exchange
Commission on December 18, 2006 (File Nos. 333-139459 and 333-139459-01)).
2.2
Fourth Supplemental Indenture, dated as of October 30, 2009, among Petrobras International Finance
Company, Petrobras and The Bank of New York Mellon, as Trustee, relating to the 6.875% Global Notes due
2040 (incorporated by reference to Exhibit 2.36 to the Annual Report and Form 20-F of Petrobras and
Petrobras International Finance Company, filed with the Securities and Exchange Commission on May 20,
2010 (File Nos. 001-15106 and 001-33121)).
2.3
Guaranty for the 6.875% Global Notes due 2040, dated as of October 30, 2009, between Petrobras and The
Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 2.38 to the Annual Report and
Form 20-F of Petrobras and Petrobras International Finance Company, filed with the Securities and Exchange
Commission on May 20, 2010 (File Nos. 001-15106 and 001-33121)).
2.4
Description of Securities.
2.5
Transfer of Rights Agreement, dated as of September 3, 2010, among Petrobras, the Brazilian federal
government and the ANP (incorporated by reference to Exhibit 2.47 to the Annual Report and Form 20-F of
Petrobras and Petrobras International Finance Company, filed with the Securities and Exchange Commission
on May 26, 2011 (File Nos. 001-15106 and 001-33121)).
2.6
Further Amended and Restated Deposit Agreement, dated as of January 2, 2020, among Petrobras,
JPMorgan Chase Bank, N.A., as depositary, and registered holders and beneficial owners from time to time of
the ADSs, representing the common shares of Petrobras, and Form of ADR evidencing ADSs representing the
common shares of Petrobras (File Nos. 001-15106).
2.7
Further Amended and Restated Deposit Agreement, dated as of January 2, 2020, among Petrobras,
JPMorgan Chase Bank, N.A., as depositary, and registered holders and beneficial owners from time to time of
the ADSs, representing the preferred shares of Petrobras, and Form of ADR evidencing ADSs representing
the preferred shares of Petrobras (File Nos. 333-235803 and 001-15106).
2.8
Amended and Restated Seventh Supplemental Indenture, dated as of February 6, 2012, among Petrobras
International Finance Company, Petrobras and The Bank of New York Mellon, as Trustee, relating to the
6.750% Global Notes due 2041 (incorporated by reference to Exhibit 4.5 to Form 6-K of Petrobras and
Petrobras International Finance Company, furnished to the Securities and Exchange Commission on February
6, 2012 (File Nos. 001-15106 and 001-33121)).
2.9
Amended and Restated Guaranty for the 6.750% Global Notes due 2041, dated as of February 6, 2012,
between Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.4 to
Form 6-K of Petrobras and Petrobras International Finance Company, furnished to the Securities and
Exchange Commission on February 6, 2012 (File Nos. 001-15106 and 001-33121)).
2.10
Thirteenth Supplemental Indenture, dated as of February 10, 2012, among Petrobras International Finance
Company, Petrobras and The Bank of New York Mellon, as Trustee, relating, among others, to the 6.875%
Global Notes due 2040 and the 6.750% Global Notes due 2041 (incorporated by reference to Exhibit 2.60 to
Annual Report and Form 20-F 2024 I 319
Additional Information
No.
Description
the Annual Report and Form 20-F of Petrobras and Petrobras International Finance Company, filed with the
Securities and Exchange Commission on April 2, 2012 (File Nos. 001-15106 and 001-33121)).
2.11
Indenture, dated as of August 29, 2012, between Petrobras Global Finance B.V. and The Bank of New York
Mellon, as Trustee (incorporated by reference to Exhibit 4.5 to the Registration Statement on Form F-3 of
Petrobras, Petrobras International Finance Company and Petrobras Global Finance B.V., filed with the
Securities and Exchange Commission on August 29, 2012 (File Nos. 333-183618, 333-183618-01 and 333-
183618-02)).
2.12
Third Supplemental Indenture, dated as of October 1, 2012, among Petrobras Global Finance B.V., Petrobras,
The Bank of New York Mellon, as Trustee, The Bank of New York Mellon, London Branch, as principal paying
agent, and The Bank of New York Mellon (Luxembourg) S.A., as Luxembourg paying agent, relating to the
5.375% Global Notes due 2029 (incorporated by reference to Exhibit 4.8 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on October 1, 2012 (File No. 001-15106)).
2.13
Guaranty for the 5.375% Global Notes due 2029, dated as of October 1, 2012, between Petrobras and The
Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.7 to Form 6-K of Petrobras,
furnished to the Securities and Exchange Commission on October 1, 2012 (File No. 001-15106)).
2.14
Seventh Supplemental Indenture, dated as of May 20, 2013, between Petrobras Global Finance B.V., Petrobras
and The Bank of New York Mellon, as Trustee, relating to the 5.625% Global Notes due 2043 (incorporated by
reference to Exhibit 4.11 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
May 20, 2013 (File No. 001-15106)).
2.15
Guaranty for the 5.625% Global Notes due 2043, dated as of May 20, 2013, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.10 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on May 20, 2013 (File No. 001-15106)).
2.16
Production Sharing Contract, dated as of December 2, 2013, among Petrobras, Shell Brasil Petróleo Ltda.,
Total E&P do Brasil Ltda., CNODC Brasil Petróleo e Gás Ltda. and CNOOC Petroleum Brasil Ltda., the Brazilian
federal government, Pré-Sal Petróleo S.A.—PPSA and the ANP (incorporated by reference to the Annual
Report on Form 20-F of Petrobras, filed with the Securities and Exchange Commission on April 30, 2014 (File
No. 001-15106)).
2.17
Thirteenth Supplemental Indenture, dated as of January 14, 2014, among Petrobras Global Finance B.V.,
Petrobras, The Bank of New York Mellon, as Trustee, The Bank of New York Mellon, London Branch, as
principal paying agent, and The Bank of New York Mellon (Luxembourg) S.A., as Luxembourg paying agent,
relating to the 6.625% Global Notes due 2034 (incorporated by reference to Exhibit 4.11 to Form 6-K of
Petrobras, furnished to the Securities and Exchange Commission on January 14, 2014 (File No. 001-15106)).
2.18
Guaranty for the 6.625% Global Notes due 2034, dated as of January 14, 2014, between Petrobras and The
Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.10 to Form 6-K of Petrobras,
furnished to the Securities and Exchange Commission on January 14, 2014 (File No. 001-15106)).
2.19
Seventeenth Supplemental Indenture, dated as of March 17, 2014, among Petrobras Global Finance B.V.,
Petrobras and The of New York Mellon, as Trustee, relating to the 7.250% Global Notes due 2044
(incorporated by reference to Exhibit 4.11 to Form 6-K of Petrobras, furnished to the Securities and Exchange
Commission on March 17, 2014 (File No. 001-15106)).
2.20
Guaranty for the 7.250% Global Notes due 2044, dated as of March 17, 2014, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.10 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on March 17, 2014 (File No. 001-15106)).
2.21
Fourteenth Supplemental Indenture, dated as of December 28, 2014, among Petrobras International Finance
Company S.A., Petrobras Global Finance B.V., Petrobras and The Bank of New York Mellon, as Trustee, relating
Annual Report and Form 20-F 2024 I 320
Additional Information
No.
Description
to, among others, the 6.875% Global Notes due 2040, and 6.750% Global Notes due 2041 (incorporated by
reference to Exhibit 4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
January 15, 2015 (File No. 001-15106)).
2.22
First Amendment to the Guaranties, dated as of December 28, 2014, between Petrobras and The Bank of New
York Mellon, as Trustee, relating to, among others, the 6.875% Global Notes due 2040, and 6.750% Global
Notes due 2041 (incorporated by reference to Exhibit 4.3 to Form 6-K of Petrobras, furnished to the Securities
and Exchange Commission on January 15, 2015 (File No. 001-15106)).
2.23
Twentieth Supplemental Indenture, dated as of June 5, 2015, among Petrobras Global Finance B.V., Petrobras
and The Bank of New York Mellon, as Trustee, relating to the 6.850% Global Notes due 2115 (incorporated by
reference to Exhibit 4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
June 5, 2015 (File No. 001-15106)).
2.24
Guaranty for the 6.850% Global Notes due 2115, dated as of June 5, 2015, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on June 5, 2015 (File No. 001-15106)).
2.25
Twenty-Second Supplemental Indenture, dated as of May 23, 2016, among Petrobras Global Finance B.V.,
Petrobras and The Bank of New York Mellon, relating to the 8.750% Global Notes due 2026 (incorporated by
reference to Exhibit 4.5 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
May 23, 2016 (File No. 01-15106)).
2.26
Guaranty for the 8.750% Global Notes due 2026, dated as of May 23, 2016, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.4 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on May 23, 2016 (File No. 01-15106)).
2.27
Amended and Restated Twenty-Second Supplemental Indenture, dated as of July 13, 2016, among Petrobras
Global Finance B.V., Petrobras and The Bank of New York Mellon, relating to the 8.750% Global Notes due
2026 (incorporated by reference to Exhibit 4.5 to Form 6-K of Petrobras, furnished to the Securities and
Exchange Commission on July 13, 2016 (File No. 01-15106)).
2.28
Amended and Restated Guaranty for the 8.750% Global Notes due 2026, dated as of July 13, 2016, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.4 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on July 13, 2016 (File No. 01-15106)).
2.29
Twenty-Fourth Supplemental Indenture, dated as of January 17, 2017, among Petrobras Global Finance B.V.,
Petrobras and The Bank of New York Mellon, relating to the 7.375% Global Notes due 2027 (incorporated by
reference to Exhibit 4.5 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
January 17, 2017 (File No. 01-15106)).
2.30
Amended and Restated Guaranty for the 7.375% Global Notes due 2027, dated as of May 22, 2017, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.4 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on May 22, 2017 (File No. 01-15106)).
2.31
Amended and Restated Twenty-Fourth Supplemental Indenture, dated as of May 22, 2017, among Petrobras
Global Finance B.V., Petrobras and The Bank of New York Mellon, relating to the 7.375% Global Notes due
2027 (incorporated by reference to Exhibit 4.5 to Form 6-K of Petrobras, furnished to the Securities and
Exchange Commission on May 22, 2017 (File No. 01-15106)).
2.32
Amended and Restated Seventeenth Supplemental Indenture, dated as of May 22, 2017, among Petrobras
Global Finance B.V., Petrobras and The Bank of New York Mellon, as Trustee, relating to the 7.250% Global
Notes due 2044 (incorporated by reference to Exhibit 4.8 to Form 6-K of Petrobras, furnished to the Securities
and Exchange Commission on May 22, 2017 (File No. 01-15106)).
Annual Report and Form 20-F 2024 I 321
Additional Information
No.
Description
2.33
Amended and Restated Guaranty dated as of May 22, 2017, of the Amended and Restated Guaranty of the
7.250% Global Notes due 2044, dated as of March 17, 2014, between Petrobras and The Bank of New York
Mellon, as Trustee (incorporated by reference to Exhibit 4.7 to Form 6-K of Petrobras, furnished to the
Securities and Exchange Commission on May 22, 2017 (File No. 001-15106)).
2.34
Indenture, dated as of September 27, 2017, among Petrobras Global Finance B.V., Petrobras and The Bank of
New York Mellon, as trustee, relating to the 5.999% Global Notes due 2028.
2.35
Twenty-Fifth Supplemental Indenture, dated as of February 1, 2018, among Petrobras Global Finance B.V.,
Petrobras and The Bank of New York Mellon, relating to the 5.750% Global Notes due 2029 (incorporated by
reference to Exhibit 4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
February 1, 2018 (File No. 001-15106)).
2.36
Guaranty for the 5.750% Global Notes due 2029, dated as of February 1, 2018, between Petrobras and The
Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to Form 6-K of Petrobras,
furnished to the Securities and Exchange Commission on February 1, 2018 (File No. 001-15106)).
2.37
Indenture, dated as of August 28, 2018 between Petrobras and The Bank of New York, as Trustee
(incorporated by reference to Exhibit 4.3 to the Registration Statement of Petrobras and Petrobras Global
Finance on Form F-3, filed with the Securities and Exchange Commission on August 28, 2018 (File Nos. 333-
227087 and 333-227087-01)).
2.38
Indenture, dated as of August 28, 2018 between Petrobras Global Finance B.V. and The Bank of New York, as
Trustee (incorporated by reference to Exhibit 4.4 to the Registration Statement of Petrobras and Petrobras
Global Finance B.V. on Form F-3, filed with the Securities and Exchange Commission on August 28, 2018 (File
Nos. 333-227087 and 333-227087-01)).
2.39
Amended And Restated Guaranty for the 5.750% Global Notes due 2029, dated as of March 19, 2019, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on March 19, 2019 (File No. 001-
15106)).
2.40
Amended And Restated Twenty-Fifth Supplemental Indenture for the 5.750% Global Notes due 2029, dated
as of March 19, 2019, between Petrobras and The Bank of New York Mellon, as Trustee (incorporated by
reference to Exhibit 4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
March 19, 2019 (File No. 001-15106)).
2.41
Guaranty for the 6.900% Global Notes due 2049, dated as of March 19, 2019, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.5 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on March 19, 2019 (File No. 001-15106)).
2.42
First Supplemental Indenture for the 6.900% Global Notes due 2049, dated as of March 19, 2019, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.6 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on March 19, 2019 (File No. 001-
15106)).
2.43
Indenture, dated as of September 18, 2019 between Petrobras Global Finance B.V. and The Bank of New York,
as Trustee (incorporated by reference to Exhibit 4.75 to the Registration Statement of Petrobras and
Petrobras Global Finance B.V. on Form F-4, filed with the Securities and Exchange Commission on July 6, 2020
(as amended on July 28, 2020) (File Nos. 333-239714 and 333-239714-01)).
2.44
Guaranty for the 5.093% Global Notes due 2030, dated as of September 18, 2019, between Petrobras and The
Bank of New York Mellon, as trustee (incorporated by reference to Exhibit 4.73 to Petrobras’ Registration
Annual Report and Form 20-F 2024 I 322
Additional Information
No.
Description
Statement on Form F-4, filed with the SEC on July 6, 2020 (as amended on July 28, 2020) (File No. 333-
239714)).
2.45
Second Supplemental Indenture for the 5.600% Global Notes due 2031, dated as of June 3, 2020, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.2 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on June 3, 2020 (File No. 001-15106)).
2.46
Guaranty for the 5.600% Global Notes due 2031, dated as of June 3, 2020, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on June 3, 2020 (File No. 001-15106)).
2.47
Third Supplemental Indenture for the 6.750% Global Notes due 2050, dated as of June 3, 2020, between
Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.5 to Form 6-
K of Petrobras, furnished to the Securities and Exchange Commission on June 3, 2020 (File No. 001-15106)).
2.48
Guaranty for the 6.750% Global Notes due 2050, dated as of June 3, 2020, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.4 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on June 3, 2020 (File No. 001-15106)).
2.49
Amended and Restated Second Supplemental Indenture for the 5.600% Global Notes due 2031, dated as of
October 21, 2020, between Petrobras and The Bank of New York Mellon, as Trustee (incorporated by
reference to Exhibit 4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on
October 21, 2020 (File No. 001-15106)).
2.50
Amended and Restated Guaranty for the 5.600% Global Notes due 2031, dated as of October 21, 2020,
between Petrobras and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to
Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on October 21, 2020 (File No.
001-15106)).
2.51
Fourth Supplemental Indenture for the 5.500% Global Notes due 2051, dated as of June 10, 2021, between
Petrobras, PGF and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.2 to Form
6-K of Petrobras, furnished to the Securities and Exchange Commission on June 10, 2021 (File No. 001-
15106)).
2.52
Guaranty for the 5.500% Global Notes due 2051, dated as of June 10, 2021, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.3 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on June 10, 2021 (File No. 001-15106)).
2.53
Fifth Supplemental Indenture for the 6.500% Global Notes due 2033, dated as of July 3, 2023, between
Petrobras, PGF and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.2 to Form
6-K of Petrobras, furnished to the Securities and Exchange Commission on July 3, 2023 (File No. 001-15106)).
2.54
Guaranty for the 6.500% Global Notes due 2033, dated as of July 3, 2023, between Petrobras and The Bank
of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.3 to Form 6-K of Petrobras, furnished
to the Securities and Exchange Commission on July 3, 2023 (File No. 001-15106)).
2.55
The Sixth Supplemental Indenture for the 6.000% Global Notes due 2035, date as of September 13, 2024,
between Petrobras, PGF and The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit
4.2 to Form 6-K of Petrobras, furnished to the Securities and Exchange Commission on September 9, 2024
(File No. 001-15106)).
2.56
Guaranty for the 6.000% Global Notes due 2035, date as of September 13, 2024, between Petrobras, PGF and
The Bank of New York Mellon, as Trustee (incorporated by reference to Exhibit 4.1 to Form 6-K of Petrobras,
furnished to the Securities and Exchange Commission on September 9, 2024 (File No. 001-15106)).
Annual Report and Form 20-F 2024 I 323
Additional Information
No.
Description
4.1
Form of Concession Agreement for Exploration, Development and Production of crude oil and natural gas
executed between Petrobras and the ANP (incorporated by reference to Exhibit 10.1 of Petrobras’
Registration Statement on Form F-1 filed with the Securities and Exchange Commission on July 14, 2000 (File
No. 333-12298)). This was a paper filing, and is not available on the SEC website.
4.2
Purchase and Sale Agreement of natural gas, executed between Petrobras and Yacimientos Petroliferos
Fiscales Bolivianos-YPFB (together with and English version) (incorporated by reference to Exhibit 10.2 to
Petrobras’ Registration Statement on Form F-1 filed with the Securities and Exchange Commission on July
14, 2000 (File No. 333-12298)). This was a paper filing, and is not available on the SEC website. Until the
moment thirteen GSA Amendments have been signed since the original execution of the GSA on August 16,
1996, so the GSA remains in effect.
8.1
List of Subsidiaries.
11.1
Policy on the Disclosure of Material Act or Fact and Securities Trading
12.1
Certifications Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
13.1
Certifications Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
15.1
Consent letter of KPMG Auditores Independentes Ltda.
15.2
Consent letter of DeGolyer and MacNaughton.
15.3
Hydrocarbon Production by Geographic Area.
15.4
List of Our Vessels.
17.1
Subsidiary Guarantors and Issuers of Guaranteed Securities (File No: 001-15106).
97.1
Petrobras’ Clawback Policy (incorporated by reference to Exhibit 97.1 to Petrobras’ Annual Report on Form
20-F filed on April 12, 2024 (File No. 001-15106)).
97.2
PGF’s Clawback Policy (incorporated by reference to Exhibit 97.2 to Petrobras’ Annual Report on Form 20-F
filed on April 12, 2024 (File No. 001-15106)).
99.1
Third Party Report of DeGolyer and MacNaughton.
101.INS
XBRL Instance Document.
101.SCH
XBRL Taxonomy Extension Schema Document.
101.CAL
XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF
XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB
XBRL Taxonomy Extension Label Linkbase Document.
101.PRE
XBRL Taxonomy Extension Presentation Linkbase Document.
Omitted from the exhibits filed with this annual report are certain instruments and agreements with respect
to long-term debt of Petrobras, none of which, individually, authorizes securities in a total amount that
exceeds 10% of the total assets of Petrobras. Petrobras hereby agrees to furnish to the SEC copies of any
such omitted instruments or agreements upon request.
Annual Report and Form 20-F 2024 I 324
Additional Information
Signatures
The registrant hereby certifies that it meets all the requirements for filing on Form 20-F and has duly caused
this annual report to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of
Rio de Janeiro, on April 3, 2025.
Petróleo Brasileiro S.A. — PETROBRAS
By: _/s/ Magda Maria de Regina Chambriard
Name: Magda Maria de Regina Chambriard
Title: Chief Executive Officer
By: _/s/ Fernando Sabbi Melgarejo
Name: Fernando Sabbi Melgarejo
Title: Chief Financial Officer and Chief Investor
Relations Officer
Annual Report and Form 20-F 2024 I 325
Additional Information
Abbreviations
bbl
Barrels
bbl/d
Barrels per day
bcf
Billion cubic feet
bn
Billion (thousand million)
bnbbl
Billion barrels
bncf
Billion cubic feet
bnm3
Billion cubic meters
bnboe
Billion barrels of oil equivalent
boe
Barrels of oil equivalent
boed
Barrels of oil equivalent per day
cf
Cubic feet
cmd
Cubic meters per day
GWh
One gigawatt of power supplied or demanded for one hour
kgCO2e/boe
Kilogram of carbon dioxide equivalent per barrel of oil equivalent
KgCO2e/CWT
Kilogram of carbon dioxide equivalent per complexity weighted ton
km
Kilometer
km2
Square kilometers
m3
Cubic meter
m3/d
Cubic meter per day
mbbl
Thousand barrels
mbbl/d
Thousand barrels per day
mboe
Thousand barrels of oil equivalent
mboed
Thousand barrels of oil equivalent per day
mcf
Thousand cubic feet
mcf/d
Thousand cubic feet per day
Annual Report and Form 20-F 2024 I 326
Additional Information
mm3
Thousand cubic meters
mm3/d
Thousand cubic meters per day
mm3/y
Thousand cubic meter per year
mmbbl
Million barrels
mmbbl/d
Million barrels per day
mmboe
Million barrels of oil equivalent
mmboed
Million barrels of oil equivalent per day
mmcf
Million cubic feet
mmcf/d
Million cubic feet per day
mmm3
Million cubic meters
mmm3/d
Million cubic meters per day
mmt
Million metric tons
mmt/y
Million metric tons per year
MW
Megawatts
MWavg
Amount of energy (in MWh) divided by the time (in hours) in which such energy is produced or consumed
MWh
One megawatt of power supplied or demanded for one hour
ppm
Parts per million
R$
Brazilian reais
t
Metric ton
tCO2e
Tonnes of carbon dioxide equivalent
t/d
Metric ton per day
Tcf
Trillion cubic feet
US$
United States dollars
/d
Per day
Annual Report and Form 20-F 2024 I 327
Additional Information
Conversion table
1 acre
=
43,560 square feet
=
0.004047 km2
1 barrel
=
42 U.S. gallons
=
Approximately 0.13 t of oil
1 boe
=
1 barrel of crude oil equivalent
=
5,615.65 cf of natural gas19F
1 m3 of natural gas
=
35.315 cf
=
0.0063 boe
1 km
=
0.6214 miles
1 meter
=
3.2808 feet
1 t of crude oil
=
1,000 kilograms of crude oil
=
Approximately 7.5 barrels of crude oil
(assuming an atmospheric pressure
index gravity of 37°API)
Annual Report and Form 20-F 2024 I 328
Additional Information
Cross-Reference to Form 20-F
Form 20-F
Captions
Location in this Annual Report
Pages
Disclaimer
6
Glossary of Certain Terms used in this Annual Report
9
About Us
26
Overview
27
PART 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
A. Reserved
Not applicable
B. Capitalization and indebtedness
Not applicable
C. Reasons for the offer and use of
proceeds
Not applicable
D. Risk factors
Risks (Risk Factors)
33
Item 4.
Information on the company
A. History and development of the
company
Disclaimer (Documents on Display);
About Us (About us; Overview)
6, 26, 27
B. Business overview
About Us (Overview); Our Business
(Exploration & Production; Refining,
Transportation & Marketing; Gas & Low
Carbon Energies; Mergers and
Acquisitions); Strategic Plan; Legal and
Tax (Regulation; Material Contracts)
27; 63, 102, 125, 144;
153; 278, 285
C. Organizational structure
About Us (Overview); Exhibit 8.1 – List
of Subsidiaries
27
D. Property, plants and equipment
Our Business; Strategic Plan; Legal and
Tax (Regulation)
62; 153; 278
Item 4A.
Unresolved Staff Comments
None
Item 5.
Operating and Financial Review and
Prospects
A. Operating results
Operating and Financial Review and
Prospects
190
B. Liquidity and capital resources
Operating and Financial Review and
Prospects (Liquidity and Capital
Resources)
200
C. Research and development, patents
and licenses, etc.
Environmental, Social and Governance
(Social Responsibility; Corporate
Governance)
176, 183
D. Trend information
Our Business; Risks; Operating and
Financial Review and Prospects
62; 32; 190
E. Critical Accounting Estimates
Operating and Financial Review and
Prospects (Liquidity and Capital
Resources)
200
Item 6.
Directors, Senior Management and
Employees
Annual Report and Form 20-F 2024 I 329
Additional Information
Form 20-F
Captions
Location in this Annual Report
Pages
A. Directors and senior management
Management and Employees
(Management)
215
B. Compensation
Management and Employees
(Management)
215
C. Board practices
Management and Employees
(Management)
215
D. Employees
Management and Employees
(Employees)
236
E. Share ownership
Shareholder Information (Listing;
Shares and Shareholders) and
Management and Employees
(Management)
256, 257; 215
F. Disclosure of a registrant’s action to
recover erroneously awarded
compensation
Not applicable
Item 7.
Major Shareholders and Related Party
Transactions
A. Major shareholders
Shareholder Information (Shares and
Shareholders)
257
B. Related party transactions
Compliance and Internal Controls
(Related Party Transactions)
251
C. Interests of experts and counsel
Not applicable
Item 8.
Financial Information
A. Consolidated Statements and Other
Financial Information
Financial Statements; Legal and Tax
(Legal Proceedings); Shareholder
Information
F-1; 289; 255
B. Significant Changes
Not applicable
Item 9.
The Offer and Listing
A. Offer and listing details
Not applicable
B. Plan of distribution
Not applicable
C. Markets
Shareholder Information (Listing)
256
D. Selling shareholders
Not applicable
E. Dilution
Not applicable
F. Expenses of the issue
Not applicable
Item 10.
Additional Information
Not applicable
A. Share capital
Not applicable
B. Memorandum and articles of
association
Environment, Social and Governance
(Corporate Governance); Management
and Employees; Shareholder
Information; Exhibit 1.1; Exhibit 2.4
183; 214; 255
C. Material contracts
Legal and Tax (Material Contracts)
285
D. Exchange controls
Shareholder Information (Additional
Information for Non-Brazilian
Shareholders)
274
E. Taxation
Legal and Tax (Tax)
296
F. Dividends and paying agents
Not applicable
G. Statement by experts
Not applicable
H. Documents on display
Disclaimer
6
Annual Report and Form 20-F 2024 I 330
Additional Information
Form 20-F
Captions
Location in this Annual Report
Pages
I. Subsidiary Information
Not applicable
J. Annual Report to Security Holders
Not applicable
Item 11.
Qualitative and Quantitative
Disclosures about Market Risk
Risks (Disclosures About Market Risk)
56
Item 12.
Description of Securities other than
Equity Securities
A. Debt Securities
Not applicable
B. Warrants and Rights
Not applicable
C. Other Securities
Not applicable
D. American Depositary Shares
Shareholder Information
255
PART II
Item 13.
Defaults, Dividend Arrearages and
Delinquencies
None
Item 14.
Material Modifications to the Rights of
Security Holders and Use of Proceeds
None
Item 15.
Controls and Procedures
Compliance and Internal Controls
(Controls and Procedures)
253
Item 16.
Reserved
Not applicable
A. Audit Committee Financial Expert
Management and Employees
(Management)
215
B. Code of Ethics
Compliance and Internal Controls
(Compliance)
246
C. Principal Accountant Fees and
Services
Management and Employees
(Management)
215
D. Exemptions from the Listing
Standards for Audit Committees
Management and Employees
(Management)
215
E. Purchases of Equity Securities by
the Issuer and Affiliated Purchasers
Shareholder Information (Shares and
Shareholders)
257
F. Change in Registrant’s Certifying
Accountant
Not applicable
G. Corporate Governance
Environment, Social
and Governance (Corporate
Governance)
183
H. Mine Safety Disclosure
Not applicable
I. Disclosure Regarding Foreign
Jurisdictions that Prevent Inspections
Not applicable
J. Insider Trading Policies
Compliance and Internal Controls
(Compliance)
246
K. Cybersecurity Disclosure
Risks (Cybersecurity Disclosure)
58
PART III
Item 17.
Financial Statements
Not applicable
Item 18.
Financial Statements
Financial Statements
F-1
Item 19.
Exhibits
Exhibits
318
Signatures
324
Abbreviations
325
Conversion Table
327
Cross Reference to Form 20-F
328
FINANCIAL
STATEMENTS
___
CONSOLIDATED
INDEX
Petróleo Brasileiro S.A. – Petrobras
Consolidated Statements of Financial Position .............................................................................................................................. F-3
Consolidated Statements of Income .................................................................................................................................................. F-4
Consolidated Statements of Comprehensive Income ................................................................................................................... F-5
Consolidated Statements of Cash Flows ........................................................................................................................................... F-6
Consolidated Statements of Changes in Shareholders’ Equity ................................................................................................. F-7
1.
The Company and its operations .............................................................................................................................................. F-8
2.
Basis of preparation ...................................................................................................................................................................... F-9
3.
Material accounting policies ....................................................................................................................................................... F-9
4.
Judgments and sources of estimation uncertainty ............................................................................................................ F-9
5.
Climate Change ............................................................................................................................................................................. F-16
6.
New standards and interpretations ....................................................................................................................................... F-22
7.
Capital Management ................................................................................................................................................................... F-23
8.
Cash and cash equivalents and marketable securities ..................................................................................................... F-23
9.
Sales revenues .............................................................................................................................................................................. F-24
10.
Costs and expenses by nature ............................................................................................................................................ F-27
11.
Other income and expenses, net ........................................................................................................................................ F-28
12.
Net finance income (expense) ............................................................................................................................................. F-28
13.
Information by operating segment................................................................................................................................... F-29
14.
Trade and other receivables ................................................................................................................................................ F-35
15.
Inventories ................................................................................................................................................................................ F-37
16.
Trade payables ........................................................................................................................................................................ F-38
17.
Taxes ........................................................................................................................................................................................... F-39
18.
Employee benefits .................................................................................................................................................................. F-45
19.
Provisions for legal proceedings, judicial deposits and contingent liabilities .................................................... F-59
20.
Provision for decommissioning costs ............................................................................................................................... F-70
21.
Other assets and liabilities .................................................................................................................................................. F-71
22.
The “Lava Jato (Car Wash) Operation” and its effects on the Company .............................................................. F-72
23.
Property, plant and equipment .......................................................................................................................................... F-73
24.
Intangible assets ..................................................................................................................................................................... F-76
25.
Impairment ............................................................................................................................................................................... F-78
26.
Exploration and evaluation of oil and gas reserves ..................................................................................................... F-85
27.
Consortia (partnerships) in E&P activities ...................................................................................................................... F-87
28.
Investments .............................................................................................................................................................................. F-90
29.
Disposal of assets and other transactions ..................................................................................................................... F-93
30.
Finance debt ............................................................................................................................................................................. F-96
31.
Lease liability .........................................................................................................................................................................F-100
32.
Equity .......................................................................................................................................................................................F-102
33.
Financial risk management ................................................................................................................................................F-108
34.
Related-party transactions ...............................................................................................................................................F-116
35.
Supplemental information on statement of cash flows ...........................................................................................F-120
36.
Subsequent events ...............................................................................................................................................................F-121
Supplementary information on Oil and Gas Exploration and Production (unaudited) ..................................................F-122
Management’s Report on Internal Control over Financial Reporting ..................................................................................F-134
Report of Independent Registered Public Accounting Firm ...................................................................................................F-135
F-3
Consolidated Statements of Financial Position
PETROBRAS
As of December 31, 2024 and December 31, 2023 (Expressed in millions of US Dollars, unless otherwise indicated)
Assets
Note
12.31.2024
12.31.2023
Cash and cash equivalents
8
3,271
12,727
Marketable securities
8
4,263
2,819
Trade and other receivables
14
3,566
6,135
Inventories
15
6,710
7,681
Recoverable income taxes
17
411
218
Other recoverable taxes
17
1,555
960
Others
21
1,550
1,570
21,326
32,110
Assets classified as held for sale
29
510
335
Current assets
21,836
32,445
Trade and other receivables
14
1,256
1,847
Marketable securities
8
582
2,409
Judicial deposits
19
11,748
14,746
Deferred income taxes
17
922
965
Other recoverable taxes
17
3,601
4,516
Others
21
2,501
2,315
Long-term receivables
20,610
26,798
Investments
28
659
1,358
Property, plant and equipment - PP&E
23
136,285
153,424
Intangible assets
24
2,255
3,042
Non-current assets
159,809
184,622
Total assets
181,645
217,067
Liabilities
Note
12.31.2024
12.31.2023
Trade payables
16
6,082
4,813
Finance debt
30
2,566
4,322
Lease liability
31
8,542
7,200
Income taxes payable
17
1,400
1,300
Other taxes payable
17
3,284
4,166
Dividends payable
32
2,657
3,539
Provision for decommissioning costs
20
1,696
2,032
Employee benefits
18
2,315
2,932
Others
21
2,205
3,015
30,747
33,319
Liabilities related to assets classified as held for sale
29
713
541
Current liabilities
31,460
33,860
Finance debt
30
20,596
24,479
Lease liability
31
28,607
26,599
Income taxes payable
17
530
299
Deferred income taxes
17
1,470
10,910
Employee benefits
18
10,672
15,579
Provisions for legal proceedings
19
2,833
3,305
Provision for decommissioning costs
20
24,507
21,171
Others
21
1,620
1,890
Non-current liabilities
90,835
104,232
Current and non-current liabilities
122,295
138,092
Share capital (net of share issuance costs)
32
107,101
107,101
Capital reserve and capital transactions
29
410
Profit reserves
32
61,446
72,641
Accumulated other comprehensive deficit
(109,470)
(101,569)
Attributable to the shareholders of Petrobras
59,106
78,583
Non-controlling interests
28
244
392
Equity
59,350
78,975
Total liabilities and equity
181,645
217,067
The notes form an integral part of these consolidated financial statements.
F-4
Consolidated Statements of Income
PETROBRAS
Years ended December 31, 2024, 2023 and 2022 (Expressed in millions of US Dollars, unless otherwise indicated)
Note
2024
2023
2022
Sales revenues
9
91,416
102,409
124,474
Cost of sales
10
(45,444)
(48,435)
(59,486)
Gross profit
45,972
53,974
64,988
Income (expenses)
Selling expenses
10
(4,874)
(5,038)
(4,931)
General and administrative expenses
10
(1,845)
(1,594)
(1,332)
Exploration costs
26
(913)
(982)
(887)
Research and development expenses
(789)
(726)
(792)
Other taxes
(1,251)
(890)
(439)
Impairment of assets, net
25
(1,531)
(2,680)
(1,315)
Other income and expenses, net
11
(7,893)
(4,031)
1,822
(19,096)
(15,941)
(7,874)
Income before net finance expense, results of equity-accounted investments and income taxes
26,876
38,033
57,114
Finance income
1,954
2,169
1,832
Finance expenses
(5,957)
(3,922)
(3,500)
Foreign exchange gains (losses) and inflation indexation charges
(11,104)
(580)
(2,172)
Net finance expense
12
(15,107)
(2,333)
(3,840)
Results of equity-accounted investments
28
(627)
(304)
251
Net income before income taxes
11,142
35,396
53,525
Income taxes
17
(3,537)
(10,401)
(16,770)
Net income for the year
7,605
24,995
36,755
Net income (loss) attributable to shareholders of Petrobras
7,528
24,884
36,623
Net income attributable to non-controlling interests
77
111
132
Basic and diluted earnings (losses) per common and preferred share - in U.S. dollars
32
0.58
1.91
2.81
The notes form an integral part of these consolidated financial statements.
F-5
Consolidated Statements of Comprehensive Income
PETROBRAS
Years ended December 31, 2024, 2023 and 2022 (Expressed in millions of US Dollars, unless otherwise indicated)
Note
2024
2023
2022
Net income for the year
7,605
24,995
36,755
Items that will not be reclassified to the statement of income:
Actuarial gains (losses) on post-employment defined benefit plans
18
Recognized in equity
3,279
(3,574)
(1,583)
Deferred income tax
(375)
271
212
2,904
(3,303)
(1,371)
Items that may be reclassified subsequently to the statement of income:
Unrealized gains (losses) on cash flow hedge - highly probable future exports
28
Recognized in equity
(15,627)
4,554
5,223
Reclassified to the statement of income
2,992
3,763
4,871
Deferred income tax
4,295
(2,830)
(3,432)
(8,340)
5,487
6,662
Translation adjustments (1)
Recognized in equity
(2,290)
1,186
975
Share of other comprehensive income (loss) in equity-accounted investments
28
Recognized in equity
(261)
267
219
Other comprehensive income (loss)
(7,987)
3,637
6,485
Total comprehensive income (loss)
(382)
28,632
43,240
Comprehensive income attributable to shareholders of Petrobras
(373)
28,502
43,084
Comprehensive income (loss) attributable to non-controlling interests
(9)
130
156
(1) It includes foreign exchange differences from associates and joint ventures.
The notes form an integral part of these consolidated financial statements.
F-6
Consolidated Statements of Cash Flows
PETROBRAS
Years ended December 31, 2024, 2023 and 2022 (Expressed in millions of US Dollars, unless otherwise indicated)
Note
2024
2023
2022
Cash flows from operating activities
Net income for the year
7,605
24,995
36,755
Adjustments for:
Pension and medical benefits
18
2,934
1,542
1,228
Results of equity-accounted investments
28
627
304
(251)
Depreciation, depletion and amortization
35
12,479
13,280
13,218
Impairment of assets (reversals), net
25
1,531
2,680
1,315
Inventory write down (write-back) to net realizable value
15
(42)
(7)
11
Allowance for credit loss on trade and other receivables, net
260
40
65
Exploratory expenditure write-offs
26
482
421
691
Gain on disposal/write-offs of assets
11
(228)
(1,295)
(1,144)
Foreign exchange, indexation and finance charges
15,407
2,498
4,557
Income taxes
17
3,537
10,401
16,770
Revision and unwinding of discount on the provision for decommissioning costs
3,584
2,052
745
PIS and COFINS recovery - exclusion of ICMS (VAT tax) from the basis of calculation
−
−
(1)
Results from co-participation agreements in bid areas
11
(259)
(284)
(4,286)
Early termination and cash outflows revision of lease agreements
11
(349)
(415)
(629)
Losses with legal, administrative and arbitration proceedings, net
11
996
797
1,362
Decrease (Increase) in assets
Trade and other receivables
1,822
88
355
Inventories
(295)
1,564
(1,217)
Judicial deposits
229
(1,723)
(1,709)
Other assets
(165)
324
(413)
Increase (Decrease) in liabilities
Trade payables
986
(954)
(359)
Other taxes payable
(2,988)
(431)
(2,441)
Pension and medical benefits
(1,001)
(927)
(2,130)
Provisions for legal proceedings
(467)
(591)
(380)
Other employee benefits
(80)
356
(182)
Provision for decommissioning costs
(977)
(902)
(602)
Other liabilities
(737)
(569)
(95)
Income taxes paid
(6,907)
(10,032)
(11,516)
Net cash provided by operating activities
37,984
43,212
49,717
Cash flows from investing activities
Acquisition of PP&E and intangible assets
(14,644)
(12,114)
(9,581)
Acquisition of equity interests
(22)
(24)
(27)
Proceeds from disposal of assets - Divestment
863
3,606
4,846
Financial compensation from co-participation agreements
397
391
7,284
Investment in marketable securities
(109)
98
(3,328)
Dividends received
146
88
374
Net cash used in investing activities
(13,369)
(7,955)
(432)
Cash flows from financing activities
Changes in non-controlling interest
(84)
1
63
Proceeds from finance debt
30
2,129
2,210
2,880
Repayment of principal - finance debt
30
(6,536)
(4,193)
(9,334)
Repayment of interest - finance debt
30
(1,918)
(1,978)
(1,850)
Repayment of lease liability
31
(7,895)
(6,286)
(5,430)
Dividends paid to Shareholders of Petrobras
32
(18,327)
(19,670)
(37,701)
Share repurchase program
32
(380)
(735)
−
Dividends paid to non-controlling interests
(77)
(49)
(81)
Net cash used in financing activities
(33,088)
(30,700)
(51,453)
Effect of exchange rate changes on cash and cash equivalents
(983)
174
(316)
Net change in cash and cash equivalents
(9,456)
4,731
(2,484)
Cash and cash equivalents at the beginning of the year
12,727
7,996
10,480
Cash and cash equivalents at the end of the year
3,271
12,727
7,996
The notes form an integral part of these consolidated financial statements.
F-7
Consolidated Statements of Changes in Shareholders’ Equity
PETROBRAS
Years ended December 31, 2024, 2023 and 2022 (Expressed in millions of US Dollars, unless otherwise indicated)
Share capital (net of share
issuance costs)
Accumulated other comprehensive income (deficit) and
deemed cost
Profit
Reserves
Share Capital
Share issuance
costs
Capital reserve,
Capital
Transactions
and Treasury
shares
Cumulative
translation
adjustments
Cash flow
hedge - highly
probable future
exports
Actuarial gains
(losses) on
defined benefit
pension plans
Other
comprehensive
income (loss)
and deemed
cost
Profit
Reserves
Retained
earnings
(losses)
Equity
attributable to
shareholders of
Petrobras
Non-
controlling
interests
Total
consolidated
equity
Balance at January 1, 2022
107,380
(279)
1,143
(75,122)
(24,169)
(11,205)
(1,152)
72,811
−
69,407
405
69,812
107,101
1,143
(111,648)
72,811
−
69,407
405
69,812
Capital transactions
−
−
1
−
−
−
−
−
−
1
(146)
(145)
Net income
−
−
−
−
−
−
−
−
36,623
36,623
132
36,755
Other comprehensive income (loss)
−
−
−
951
6,662
(1,371)
219
−
−
6,461
24
6,485
Additional dividends proposed
−
−
−
−
−
−
−
(6,688)
−
(6,688)
−
(6,688)
Expired unclaimed dividends
−
−
−
−
−
−
−
−
11
11
−
11
Appropriations:
Transfer to reserves
−
−
−
−
−
−
−
2,530
(2,530)
−
−
−
Dividends
−
−
−
−
−
−
−
(2,219)
(34,104)
(36,323)
(71)
(36,394)
Balance at December 31, 2022
107,380
(279)
1,144
(74,171)
(17,507)
(12,576)
(933)
66,434
−
69,492
344
69,836
107,101
1,144
(105,187)
66,434
−
69,492
344
69,836
Treasury shares
−
−
(735)
−
−
−
−
−
−
(735)
−
(735)
Capital transactions
−
−
1
−
−
−
−
−
−
1
1
2
Net income
−
−
−
−
−
−
−
−
24,884
24,884
111
24,995
Other comprehensive income (loss)
−
−
−
1,167
5,487
(3,303)
267
−
−
3,618
19
3,637
Additional dividends proposed
−
−
−
−
−
−
−
(6,864)
−
(6,864)
−
(6,864)
Expired unclaimed dividends
−
−
−
−
−
−
−
−
7
7
−
7
Appropriations:
Transfer to reserves
−
−
−
−
−
−
−
10,137
(10,137)
−
−
−
Dividends
−
−
−
−
−
−
−
2,934
(14,754)
(11,820)
(83)
(11,903)
Balance at December 31, 2023
107,380
(279)
410
(73,004)
(12,020)
(15,879)
(666)
72,641
−
78,583
392
78,975
107,101
410
(101,569)
72,641
−
78,583
392
78,975
Treasury shares
−
−
(381)
−
−
−
−
−
−
(381)
−
(381)
Capital transactions
−
−
−
−
−
−
−
−
−
−
(82)
(82)
Net income
−
−
−
−
−
−
−
−
7,528
7,528
77
7,605
Other comprehensive income (loss)
−
−
−
(2,204)
(8,340)
2,904
(261)
−
−
(7,901)
(86)
(7,987)
Additional dividends proposed
−
−
−
−
−
−
(7,178)
−
(7,178)
−
(7,178)
Expired unclaimed dividends
−
−
−
−
−
−
−
−
54
54
−
54
Appropriations:
Transfer to reserves
−
−
−
−
−
−
−
130
(130)
−
−
−
Dividends
−
−
−
−
−
−
−
(4,147)
(7,452)
(11,599)
(57)
(11,656)
Balance at December 31, 2024
107,380
(279)
29
(75,208)
(20,360)
(12,975)
(927)
61,446
−
59,106
244
59,350
107,101
29
(109,470)
61,446
−
59,106
244
59,350
The notes form an integral part of these consolidated financial statements.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-8
1.
The Company and its operations
Petróleo Brasileiro S.A. (Petrobras), hereinafter referred to as “Petrobras” or “Company,” is a partially state-owned
enterprise, controlled by the Brazilian Federal Government, of indefinite duration, governed by the terms and
conditions under the Brazilian Corporate Law (Law 6,404 of December 15, 1976), Law 13,303 of June 30, 2016 and its
Bylaws.
Petrobras’ shares are listed on the Brazilian stock exchange (B3) in the Level 2 of Corporate Governance special listing
segment and, therefore, the Company, its shareholders, its managers and fiscal council members are subject to
provisions under its regulation (Level 2 Regulation - Regulamento de Listagem do Nível 2 de Governança Corporativa
da Brasil Bolsa Balcão – B3). The provisions of the Level 2 Regulation shall prevail over statutory provisions in the event
of harm to the rights of public offers investors provided for in the Company's Bylaws, except when otherwise
determined by other regulation.
The Company is dedicated to prospecting, drilling, refining, processing, trading and transporting crude oil from
producing onshore and offshore oil fields and from shale or other rocks, as well as oil products, natural gas and other
liquid hydrocarbons. In addition, Petrobras carries out energy related activities, such as research, development,
production, transport, distribution and trading of all forms of energy, as well as other related or similar activities.
Petrobras may perform any of the activities related to its corporate purpose, directly, through its wholly-owned
subsidiaries, controlled companies, alone or through joint ventures with third parties, in Brazil or abroad.
The economic activities linked to its business purpose shall be undertaken by the Company in free competition with
other companies according to market conditions, in compliance with the other principles and guidelines of Laws no.
9,478/97 and 14,134/21 (oil and gas regulations, respectively). However, Petrobras may have its activities, provided
they are in compliance with its corporate purpose, guided by the Brazilian Federal Government to contribute to the
public interest that justified its creation, aiming to meet national energy policy objectives when:
I – established by law or regulation, as well as provided for under a contract, covenant, or adjustment agreed upon with
a public entity that is competent to establish such obligation, abiding by the broad publicity of such instruments; and
II – the cost and revenues thereof have been broken down and disseminated in a transparent manner.
In this case, the Company’s Investment Committee and Minority Shareholders Committee, exercising their advisory role
to the Board of Directors, shall assess and measure the difference between such market conditions and the operating
result or economic return of the transaction, based on technical and economic criteria for investment valuation and
specific operating costs and results under the Company's operations. In case a difference is identified, for every financial
year, the Brazilian Federal Government shall compensate the Company.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-9
2.
Basis of preparation
2.1. Statement of compliance and authorization of consolidated financial statements
These consolidated financial statements have been prepared and are being presented in accordance with the IFRS
accounting standards as issued by the International Accounting Standards Board (IASB).
The consolidated financial statements have been prepared under the historical cost convention, except when otherwise
indicated. The significant accounting policies used in the preparation of these financial statements are set out in their
respective explanatory notes.
The preparation of the financial statements requires the use of estimates based on assumptions and judgements, which
may affect the application of accounting policies and reported amounts of assets, liabilities, revenues and expenses.
Actual results may differ from these estimates. Relevant estimates and judgments with a higher level of complexity are
disclosed in explanatory note 4.
These consolidated financial statements were approved and authorized for issue by the Company’s Board of Directors
in a meeting held on April 3, 2025.
2.2. Functional and presentation currency
The functional currency of Petrobras and all of its Brazilian subsidiaries is the Brazilian Real. The functional currency of
the Petrobras direct subsidiaries that operate outside Brazil is the U.S. dollar.
Petrobras has selected the U.S. dollar as its presentation currency to facilitate a more direct comparison to other oil
and gas companies. The financial statements have been translated from the functional currency (Brazilian real) into the
presentation currency (U.S. dollar). All assets and liabilities are translated into U.S. dollars at the closing exchange rate
at the date of the financial statements; income and expenses, as well as cash flows are translated into U.S. dollars using
the average exchange rates prevailing during the period. All exchange differences arising from the translation of the
consolidated financial statements from the functional currency into the presentation currency are recognized as
cumulative translation adjustments (CTA) within accumulated other comprehensive income in the consolidated
statements of changes in shareholders’ equity.
U.S. Dollar / Brazilian Real
Dec/24
Sep/24
Jun/24
Mar/24
Dec/23
Sep/23
Jun/23
Mar/23
Dec/22
Sep/22
Jun/22
Mar/22
Quarterly average exchange rate
5.84
5.55
5.21
4.95
4.96
4.88
4.95
5.20
5.26
5.25
4.93
5.23
Period-end exchange rate
6.19
5.45
5.56
5.00
4.84
5.01
4.82
5.08
5.22
5.41
5.24
4.74
3.
Material accounting policies
To aid cohesion and comprehension, the significant accounting policies are set out at the end of each explanatory note
to which they relate.
4.
Judgments and sources of estimation uncertainty
The preparation of the consolidated financial information requires the use of estimates and judgments for certain
transactions. The following are the key judgments and the main sources of estimation uncertainty with a significant risk
of causing material adjustments to the Company's key accounting estimates over the next fiscal year.
4.1. Recognition of exploration costs and oil and natural gas reserve estimates
After obtaining the legal rights to explore a specific area, the Company uses the successful efforts method to recognize
costs incurred in connection with the exploration and evaluation of mineral resources, before demonstrating technical
and commercial feasibility of extracting those resources. This method requires a direct relationship between costs
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-10
incurred and mineral resources for these costs to be characterized as assets. The types of exploration costs and their
respective recognition are presented in note 26.
The moment in which the technical and commercial feasibility of extracting a mineral resource is determined requires
management judgments. An internal commission of technical executives of the Company periodically reviews the
conditions of each well, by analysis of geological, geophysical and engineering data, as well as economic conditions,
operating methods and government regulations.
The Company considers that the technical and commercial feasibility of a mineral resource can be demonstrated when
the project has all the necessary information to characterize the reservoir as a proved reserve. Costs associated with
non-commercial mineral resources are recognized as expenses in the period when identified.
According to the definitions prescribed by the SEC, proved oil and natural gas reserves are those quantities of oil and
gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be
economically feasible from a given date, from known reservoirs and under existing economic conditions, operating
methods and government regulation.
The Company also determines reserves according to the criteria of the National Agency for Petroleum, Natural Gas and
Biofuels / Society of Petroleum Engineers (ANP/SPE). The main differences between these criteria and the SEC criterion
are related to the use of different economic assumptions and the possibility of considering as reserves, in the ANP/SPE
criteria, the volumes expected to be produced beyond the concession contract expiration date in fields in Brazil,
according to the ANP technical reserves regulations.
4.2. Impairment testing
4.2.1. Sources of estimation uncertainty related to impairment testing
Impairment testing involves uncertainties mainly related to: (a) the average Brent prices and to the Brazilian real/U.S.
dollar average exchange rate, whose estimates are relevant to virtually all of the Company's operating segments;
(b) discount rates; and (c) estimated proved and probable reserves (according to the criteria established by the
ANP/SPE, as described in note 4.1). A significant number of interdependent variables used to determine value in use
are derived from these key assumptions, and their application in impairment testing involves a high degree of
complexity. Value in use represents the present value of estimated future cash flows originating from an asset or a
cash-generating units (CGU).
A sensitivity analysis for assets or CGUs most sensitive to future impairment losses or reversals in the next year is
presented in note 25.
Average Brent prices and average exchange rate
The markets for crude oil and natural gas have a history of significant price volatility and, although prices can drop or
increase precipitously, industry prices over the long term tend to be driven by market supply and demand
fundamentals.
Brent prices and exchange rate projections are derived from the Strategic Plan and are consistent with market evidence,
such as independent macro-economic forecasts, industry analysts and experts. Backtesting analysis and feedback
processes in order to continually improve forecast techniques are also performed.
The Company’s oil price forecast model is based on a nonlinear relationship between variables reflecting market supply
and demand fundamentals. This model also takes into account other relevant factors, such as the effects of the
Organization of the Petroleum Exporting Countries (OPEC) decisions on the oil market, industry costs, idle capacity, oil
and gas production forecasted by specialized firms, and the relationship between the oil price and the Brazilian
Real/U.S. dollar exchange rate.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-11
The process of projecting Brazilian real/U.S. dollar exchange rate is based on econometric models that consider long-
term assumptions involving observable inputs, such as commodity prices, country risk, interest rates in the U.S. and the
value of the U.S. dollar relative to a basket of foreign currencies (U.S. dollar Index – USDX).
Changes in the economic environment may result in changing assumptions and, consequently, the recognition of
impairment losses or reversals on certain assets or CGUs. For example, the Company’s sales revenues and refining
margins are directly impacted by Brent price variations, as well as Brazilian Real/U.S. dollar exchange rate variations,
which also impacts our capital and operating expenditures.
Note 25 presents Brent prices and exchange rate estimates of the Company.
Discount rates
The discount rates used in impairment tests reflect specific risks associated with the estimated cash flows of the assets
or CGUs. For example, changes in the economic and political environment may result in higher country risk projections,
causing increases in the discount rates used in impairment tests, as well as investment decisions that result in the
postponement or interruption of projects considering specific risks related to non-completion or delayed start of
operations.
Note 25 presents the main discount rates applied in impairment tests.
Estimated proved and probable reserves
Reserves estimates, according to the criteria established by the ANP/SPE (as set out in note 4.1) are revised at least
annually, based on updated geological and production data of reservoirs, as well as on changes in prices and costs used
in these estimates. Revisions may also result from significant changes in the Company’s strategy for development
projects or in the production capacity.
Although the Company is reasonably certain that proved reserves will be produced, the timing and amount recovered
can be affected by a sort of factors including completion of development projects, reservoir performance, regulatory
aspects and significant changes in long-term oil and gas price levels.
4.2.2. Identifying cash-generating units for impairment testing
A cash-generating unit (CGU) represents the smaller identifiable group of assets that generate cash inflows, which are
largely independent of the cash inflows of other assets or groups of assets. Identifying CGUs requires management
assumptions and judgment, based on the Company’s business and management model. The level of asset
disaggregation in CGUs can reach the limit of assets being tested individually.
Changes in CGUs resulting from the review of investment, strategic or operational factors, may result in changes in the
interdependencies of assets and, consequently, alter the aggregation or breakdown of assets that were part of certain
CGUs, which may influence their ability to generate cash and cause additional losses or reversals in the recovery of such
assets. If the approval for the sale of a CGU’s component occurs between the reporting date and the date of the issuance
of the consolidated financial statements, the Company reassesses whether the value in use of this component,
estimated with the information existing at the reporting date, reasonably represents its fair value, net of disposal
expenses. Such information must include evidence of the stage at which management was committed to the sale of the
CGU’s component.
The primary considerations in identifying the CGUs are set out as follows:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-12
a) Exploration and Production (E&P) CGUs:
i)
Crude oil and natural gas producing properties - individual CGUs: comprise assets related to exploration and
production development of a field or a cluster (group of two or more fields) in Brazil and abroad. At December
31, 2024, there are 30 fields and 15 clusters representing different Exploration and Production CGUs in Brazil.
ii)
Equipment not related to crude oil and natural gas producing properties: comprise assets that ceased
operation, such as platforms, drilling rigs and other assets which are not part of any CGU and are assessed for
impairment separately.
b) Refining, transportation and marketing (RT&M) CGUs:
i) CGU Set of refining and logistics assets: comprises refineries, terminals and pipelines, as well as logistics assets
operated by Transpetro. The combined and centralized operation of such assets aims at serving the market at the
lowest overall costs and preserving the strategic value of the whole set of assets in the long term. The operational
planning is made in a centralized manner and these assets are not managed, measured or evaluated by their individual
results. Refineries do not have autonomy to choose the oil to be processed, the mix of oil products to produce, the
markets in which these products will be traded, which amounts will be exported, which intermediaries will be received
and to decide the sale prices of oil products. Operational decisions are analyzed through an integrated model of
operational planning for market supply, considering all the options for production, imports, exports, logistics and
inventories, seeking to maximize the Company’s global performance. The decision on new investments is not based on
the individual assessment of the asset where the project will be installed, but on the additional result for the CGU as a
whole. The model that supports the entire planning, used in technical and economic feasibility studies of new
investments in refining and logistics, seeks to allocate a certain type of oil, or a mix of oil products, define market supply
(area of influence), aiming at achieving the best integrated results. Pipelines and terminals are a complementary and
interdependent portion of the refining assets, required to supply the market.
ii) CGU Boaventura Energy Complex - Utilities: composed of assets that supports the natural gas processing plant
(UPGN) of the route 3 integrated project;
iii) CGU Boaventura Energy Complex - Refining: set of assets that remain in hibernation and are being evaluated for use
in other projects.
iv) CGU Second Refining Unit of RNEST: comprises assets of the second refining unit of Abreu e Lima refinery and
associated infrastructure;
v) CGU Transportation: comprises assets relating to Transpetro’s fleet of vessels;
vi) CGU Hidrovia: comprises the fleet of vessels under construction of the Hidrovia project (transportation of ethanol
along the Tietê River);
vii) Nitrogen fertilizer plants: each plant represents individual CGUs, whether it is hibernated or in operation; and
viii) Other RT&M CGUs: operations abroad defined as the smallest group of assets that generates independent cash
flows.
c) Gas and Low Carbon Energies (G&LCE) CGUs:
i) CGU Integrated Systems: set of assets formed by natural gas processing plants in Itaboraí, Cabiúnas and
Caraguatatuba, grouped together due to the contractual characteristics of the Integrated Processing System and the
Integrated Transportation System;
ii) CGUs of Natural Gas Processing Plants: each remaining natural gas processing plant represents a separate CGU;
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-13
iii) CGU Set of thermoelectric power generation plants (UTEs): the operation and trade of energy of this CGU are carried
out and coordinated in an integrated manner. The economic results of each of these plants in the integrated portfolio
are highly dependent on each other, due to operational optimization aimed at maximizing the overall result;
iv) CGU Biodiesel: set of assets comprising the biodiesel plants, reflecting the production planning and operation
process, that takes into consideration domestic market conditions, the production capacity of each plant, as well as the
results of biofuels auctions and raw materials supply;
v) CGU Quixadá: comprises the assets of biofuel plant located in the city of Quixadá, state of Ceará;
vii) Other G&LCE CGUs: operations abroad defined as the smallest group of assets that generates largely independent
cash flows.
Further information on impairment testing is set out in note 25.
4.3. Sources of estimation uncertainty related to depreciation, depletion and amortization
As presented in note 23, assets directly related to the oil and gas production are depleted using the units of production
method, calculated by monthly production over the respective developed proved reserves, except for the signature
bonuses, which are calculated over total proved reserves.
Proved developed reserves are those for which recovery can be expected: (i) through existing wells, equipment and
operating methods, or in which the cost of the required equipment is relatively minor compared to the cost of a new
well; and (ii) through extraction equipment and operational infrastructure installed at the time of the reserves estimate,
if the extraction is carried out by means that do not involve a well.
Estimates of proved reserves volumes used in the units of production method are prepared by Company’s technicians
according to the SEC definitions (as described in note 4.1). Revisions to the Company’s proved developed and
undeveloped reserves impact prospectively the amounts of depreciation, depletion and amortization recognized in the
statement of income and the carrying amounts of oil and gas properties assets. Information on uncertainties related to
reserve volume estimates are presented in note 4.1.
Therefore, assuming all other variables remain constant, a decrease in estimated proved reserves would increase,
prospectively, depreciation, depletion and amortization expense, while an increase in reserves would reduce
depreciation, depletion and amortization.
4.4. Sources of estimation uncertainty related to pension plan and other post-employment
benefits
The net actuarial liability represents the Company's actuarial obligations, net of fair value of plan assets (when
applicable), at present value, as described in note 18.3.2.
The actuarial obligations and net expenses related to defined benefit pension and health care post-employment plans
are computed based on several financial and demographic assumptions, of which the most significant are:
a) Discount rate: comprises the projected future inflation in addition to an equivalent discounted interest rate that
matches the duration of the pension and health care obligations with the future yield curve of long-term Brazilian
Government Bonds; and
b) Medical and hospital costs changes rate: comprise the projected growth rates based on per capita health care
benefits paid over the last five years, which are used as a basis for projections, converged to the general price inflation
index within 30 years.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-14
These and other actuarial assumptions are revised at least annually and may differ materially from actual results due
to changes in market and economic conditions.
The measurement uncertainties associated with the defined benefit obligation and a sensitivity analysis of discount
rates and changes in medical costs are disclosed in notes 18.3.6 and 18.3.7, respectively.
4.5. Sources of estimation uncertainty related to provisions for legal proceedings and
contingencies
The Company is part in arbitrations and in legal and administrative proceedings involving civil, tax, labor and
environmental issues arising from the normal course of its business and makes use of estimates to recognize the
amounts and the probability of outflow of resources, based on reports and technical assessments from legal advisors
and on management’s assessment.
These estimates are performed individually, or aggregated if there are cases with similar characteristics, primarily
considering factors such as assessment of the plaintiff’s demands, consistency of the existing evidence, jurisprudence
on similar cases and doctrine on the subject. Specifically for lawsuits by outsourced employees, the Company estimates
the expected loss based on a statistical procedure, due to the number of actions with similar characteristics.
Arbitral, legal and administrative decisions against the Company, new jurisprudence and changes of existing evidence
can result in changes on the probability of outflow of resources and on the estimated amounts, according to the
assessment of the legal basis.
Note 19 provides further detailed information about contingencies and legal proceedings.
4.6. Sources of estimation uncertainty related to decommissioning costs
The Company has legal obligations to remove equipment and restore onshore and offshore areas at the end of
operations. Its most significant asset removal obligations relate to offshore areas. Estimates of costs for future
environmental cleanup and remediation activities are based on current information about costs and expected plans for
remediation. The timing of abandonment and dismantling of areas is based on the length of reserves depletion, in
accordance with the ANP/SPE definitions (as described in note 4.1). Therefore, revisions to reserves estimates that
result in changes in the timing of reserves depletion may impact the provision for decommissioning cost. For additional
information about revisions to the Company’s reserves estimates, see note 4.1.
These obligations are recognized at present value, using a risk-free discount rate, adjusted to the Company's credit risk.
Changes in the discount rate can cause significant variations in the recognized amount, due to the long-term nature
until abandonment. A sensitivity analysis of discount rates used in the calculation of the provision for decommissioning
costs is presented in note 20.
The calculation to determine the amounts to be provisioned are complex, since: i) the obligations are long-term; ii) the
contracts and regulations contain subjective definitions of the removal and remediation practices and criteria involved
when the events occur; and iii) asset removal technologies and costs are constantly changing, along with regulations,
environmental, safety and public relations considerations. Additionally, abandonment costs are mostly denominated in
U.S. dollars, which may result in significant changes in the estimates due to changes in the exchange rates overtime.
The Company constantly conducts studies to incorporate technologies and procedures to optimize the process of
abandonment, considering industry best practices. However, the timing and amounts of future cash flows are subject
to significant uncertainty.
In the event of a total or partial sale of interest in E&P contracts, the Company remains jointly liable for
decommissioning costs after its production has ceased, if the purchaser fails to comply with this obligation, as
determined by the ANP.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-15
Note 20 provides further information about provision for decommissioning costs.
4.7. Sources of estimation uncertainty related to leases
The Company uses incremental borrowing rates to determine the present value of the lease payments, when the
interest rate implicit in the lease cannot be readily determined.
The determination of incremental rates requires estimates based on corporate funding rates (obtained from the yields
on bonds issued by Petrobras), which take into account the risk-free rate and the Company's credit risk premium,
adjusted to reflect the specific conditions and characteristics of the lease, such as the risk of the country's economic
environment, guarantees, currency and duration of the payment flow.
The present value of lease liabilities is determined based on the incremental rates estimated at the start date of each
lease. Therefore, even in cases where lease agreements have similar characteristics, their cash flows may be discounted
at significantly different incremental rates depending on the Company's corporate funding rates on the start date of
each lease.
Note 31 presents information on lease arrangements by class of underlying assets.
4.8. Sources of estimation uncertainty related to cash flow hedge accounting involving the
Company’s future exports
The Company determines its “highly probable future exports” based on its current Business Plan and on short-term
estimates on a monthly basis. The highly probable future exports are determined by a percentage of projected export
revenues.
The estimate of the amount of highly probable future exports considers future uncertainty regarding the Brent oil
prices, oil production and demand for products in a model which optimizes the Company's operations and investments,
in addition to considering the historical profile of exported volume in relation to total oil production.
As described in note 33.4.1, foreign exchange gains and losses relating to the effective portion of hedging instruments
are recognized in other comprehensive income and reclassified to the statement of income within finance income
(expense) in the periods when the hedged item affects the statement of income. However, if future exports for which
foreign exchange gains and losses hedging relationship has been designated is no longer expected to occur, any related
cumulative foreign exchange gains or losses that have been recognized in other comprehensive income from the date
the hedging relationship was designated to the date the Company revoked the designation is immediately recycled
from other comprehensive income to the statement of income.
For the long-term, future exports forecasts are reviewed whenever the Company reviews its Strategic Plan
assumptions, while for the short-term future exports are reviewed monthly. The approach for determining highly
probable future exports is reviewed annually, at least.
See note 33.4.1 for more detailed information about cash flow hedge accounting and a sensitivity analysis of the cash
flow hedge involving future exports.
4.9. Sources of estimation uncertainty related to income taxes
Income taxes rules and regulations may be interpreted differently by tax authorities, and situations may arise in which
these interpretations differ from the Company's understanding.
Uncertainties over income taxes treatments represent the risks that the tax authority does not accept a certain tax
treatment applied by the Company, mainly related to different interpretations of deductions and additions to the
income taxes (Imposto de Renda sobre Pessoa Jurídica - IRPJ and Contribuição Social sobre Lucro Líquido – CSLL)
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-16
calculation basis. The Company evaluates each uncertain tax treatment separately or in a group where there is
interdependence in relation to the expected result.
The Company estimates the probability of acceptance of an uncertain tax treatment by the tax authority based on
technical assessments by its legal advisors, considering precedent jurisprudence applicable to current tax legislation,
which may be impacted mainly by changes in tax rules or court decisions which may affect the analysis of the
fundamentals of uncertainty. The tax risks identified are evaluated, treated and, when applicable, follows a pre-
determined tax risk management methodology.
If it is probable that the tax authorities will accept an uncertain tax treatment, the amounts recorded in the financial
statements are consistent with the tax records and, therefore, no uncertainty is reflected in the measurement of current
or deferred income taxes. If it is not probable that the tax authorities will accept an uncertain tax treatment, the
uncertainty is reflected in the measurement of current or deferred income taxes in the financial statements.
The effect of uncertainty for each uncertain tax treatment is estimated by using the method that provides the best
prediction of the resolution of the uncertainty. The most probable amount method provides as an estimate the single
most probable amount in a set of possible outcomes, while the expected amount method represents the sum of the
amounts weighted by the probability in relation to a range of possible outcomes.
Additional information on uncertainty over income taxes treatments is disclosed in Note 17.1.
4.10. Sources of estimation uncertainty related to expected credit losses
Credit losses correspond to the difference between all contractual cash flows owed to the Company and all cash flows
that the entity expects to receive, discounted at the original effective interest rate. The expected credit loss of a
financial asset corresponds to the average of expected credit losses weighted by the respective default risks.
Expected credit losses on financial assets are based on assumptions relating to risk of default, the determination of
whether or not there has been a significant increase in credit risk, expectation of recovery, among others. The Company
uses judgment for such assumptions in addition to information from credit rating agencies and inputs based on
collection delays.
Notes 14.2 and 14.3 provide details on the expected credit losses recognized by the Company.
4.11. Sources of estimation uncertainty related to the compensation for the surplus volume for
the Transfer of Rights Agreement
As a result of the Second Bidding Round for the Surplus Volume of the Transfer of Rights Agreement under the
Production Sharing regime, the Company signed amendments and new agreements in 2022 with partners in the Atapu
and Sépia fields. These agreements provide, in addition to the compensation already received upon signature, possible
additional amounts receivable that may be owed to the Company, according to the conditions described in note 29.3.
Additionally, over the last few years the Company has sold assets considered non-strategic and established
partnerships in E&P assets aiming, among other objectives, at sharing risks and developing new technologies. Such
transactions were carried out through partnerships (note 27) and divestments, with procedures aligned with current
legislation and regulatory bodies. In some of these transactions, contingent receipts are also provided for, subject to
contractual clauses (note 29.3).
5. Climate Change
Climate change may result in both negative and positive effects for the Company. Potential negative effects of climate
change for the Company are referred to as climate-related risks (climate risks). Conversely, potential positive effects
arising from climate change for the Company are referred to as climate-related opportunities.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-17
Climate risks are categorized as: (i) climate-related transition risks (transition risks); and (ii) climate-related physical
risks (physical risks).
5.1. Potential effects of climate risks on accounting estimates
Accounting estimates are monetary amounts in financial statements that are subject to measurement uncertainty.
The following information used in relevant accounting estimates of the Company is largely determined based on the
assumptions and projections of the Petrobras Business Plan (PN):
•
value in use for impairment of assets testing purposes (note 4.2.1);
•
timing and costs used in measuring the provision for decommissioning costs (note 4.6);
•
highly probable future exports used in cash flow hedge accounting involving the Company’s future exports
(note 4.8); and
•
useful life of PP&E and intangible assets used in measuring depreciation, depletion and amortization expenses
(notes 23 and 24).
As presented in the following topic, the Company considered the effects related to climate risks in its Business Plan
approved by the Board of Directors, which is updated annually, including actions to achieve its climate commitments
and its long-term ambition to neutralize Greenhouse Gas (GHG) emissions in activities under its control (scopes 11 and
22) by 2050.
The aforementioned ambition and commitments are not guarantees of future performance by the Company and are
subject to assumptions that may prove incorrect and to risks and uncertainties that are difficult to predict.
a) Transition risk to low carbon economy
Transition risks arise from efforts to the transition to a low-carbon economy. In this category, the Company has
identified the following risks that can reasonably be expected to affect its cash flows, access to financing or cost of
capital:
1 direct GHG emissions, which occur from energy sources that are owned or controlled by the Company.
2 Indirect GHG emissions, which come from energy sources purchased and consumed by the Company, which occur at the facilities
where the energy sources are generated.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-18
Risk
Description
Time length (2)
Market
Increasing demand for energy and products with lower carbon
intensity leading to a reduction in oil demand, a consequent decline
in prices of fossil fuel products. Preference for fossil fuel products
with lower GHG intensity in production processes.
In Brazil: the demand for our products may be affected, for example,
by the increase in demand for alternative fuels, also stimulated by
public policies such as the Fuel of the Future Law(1) program, among
others.
Medium
to
long-
term
Technological
Loss of competitiveness due to the non-implementation or
implementation of inefficient or non-effective technologies to
reduce emissions from our operations and products.
Medium
to
long-
term
Regulatory
Stricter regulations for controls over GHG emissions and other
requirements related to climate change, which may cause operational
restrictions and financial penalties for our activities.
In Brazil, one example is the regulation for the adoption of a carbon
pricing instrument, considering Law No. 15,042 in 2024, which
establishes the Brazilian Greenhouse Gas Emissions Trading System
(SBCE), resulting in additional costs for our operations.
Medium
to
long-
term
Legal and Reputational
Litigation and/or reputational damage due to non-compliance with
climate commitments.
Medium-term
(1) Legislation that aligns a series of initiatives to stimulate and guide the production of biofuels and reduce greenhouse gas (GHG) emissions, encompassing the
National Program for Sustainable Aviation Fuel (ProBioQAV), the National Green Diesel Program (PNDV), and the National Decarbonization Program for Natural Gas
Producers and Importers and Incentives for Biomethane. Additionally, it modifies the maximum and minimum limits of the ethanol blend in gasoline and the biodiesel
blend in diesel fuel and provides for the regulation and oversight of carbon dioxide capture and geological storage activities, as well as the regulation of synthetic fuel
production and commercialization. It also promotes the integration of initiatives and measures adopted under the National Biofuels Policy (RenovaBio), the Green and
Innovation Mobility Program (Programa Mover), the Brazilian Vehicle Labeling Program (PBEV), and the Vehicle Emissions Control Program (Proconve).
(2) Criteria adopted for the time horizon: short term (1 year), medium term (between 1 and 5 years), and long term (more than 5 years).
The risks above were considered in the development of the Company's Business Plan 2025-2029 (PN 25-29). Such
consideration was based on the following external environment assumptions that reflect the dynamics of the energy
sector:
•
Moderate economic growth compared to the recent past;
•
Shifts in consumption habits and behaviors;
•
Public policies focusing on mobility, air quality and adaptation of urban infrastructure to climate change;
•
International coordination in efforts to reduce GHG emissions;
•
Reduction in the GHG emissions;
•
Regulations in favor of energy transition and decarbonization, which will drive the reduction of fossil fuel
consumption; and
•
Diffusion of end-use technologies that reduce the need for fossil fuel consumption.
As a result of this, demand and prices, both domestic and international, of the main products considered in the PN 25-
29 are negatively affected.
In 2024, the Company adopted three distinct scenarios that are used for different purposes in its planning activities.
These scenarios are called Adaptation, Negotiation, and Commitment. In all of them, there is a slowdown and
subsequent contraction of fossil fuel sources. The Negotiation scenario, which is used as a reference scenario for
quantifying the Company's Business Plan, considers that fossil fuels, which currently represent approximately 80% of
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-19
the world’s primary energy sources, will represent around 48% by 2050. The share of oil will decrease from the current
30% to around 20% of the world’s primary energy sources.
The Brent price considered in the reference scenario of the Business Plan decreases from US$80 per barrel in 2024 to
US$65 per barrel in 2050. For additional information about the behavior of the Brent price, considered in the Company's
Business Plan reference scenario, please see note 25. The following table compares the oil price used in the reference
scenario of the Strategic Plan for the years 2030 and 2050 with those projected in the Announced Pledges Scenario
(APS) and Net Zero Emission (NZE) scenarios by the International Energy Agency (IEA), even though they are not directly
used by the Company:
Brent price US$/Barrel
2030
2050
PN
65
65
APS
72
58
NZE
42
25
According to the IEA, the APS scenario considers that all climate commitments made by governments around the world,
including Nationally Determined Contributions (NDCs), as well as long-term net-zero targets, will be met in full and on
time, with an increase of approximately 1.7oC in temperature by 2100 (with a 50% probability of occurrence). As for the
NZE scenario, according to the IEA, it presents a pathway for the global energy sector to achieve net-zero CO2 emissions
by 2050, consistent with limiting the temperature increase to 1.5 °C (with at least a 50% probability of occurrence).
The Business Plan also includes Company's actions to achieve the carbon sustainability commitments, such as low-
carbon Research and Development (R&D) projects and decarbonization projects for operations. These actions aim to
address transition risks as well as reflect climate opportunities.
The Company's accounting estimates did not incorporate the effect of carbon pricing. Currently, there are uncertainties
regarding the structure and dynamics of a future carbon market in Brazil, and there is no sufficient and reliable
information available to assess the effects of carbon price.
The Company's accounting estimates did not incorporate the effect of carbon pricing. Currently, due to uncertainties
regarding the implementation and dynamics of the carbon market in Brazil, the Company considers it necessary to await
the regulation of Law No. 15,042 in 2024, which establishes the SBCE. This regulation will provide the necessary and
sufficient details to reliably and reasonably assess the impact on the cash flows of Petrobras's assets and its CGUs.
a.1) Potential effects on the value in use in impairment tests
When measuring the value in use of its assets, the Company bases its cash flow projections on reasonable and
supportable assumptions that represent management's best estimate of the range of economic conditions.
A faster transition to a low-carbon economy than projected in the Business Plan could result in Brent prices and demand
for the Company’s products that are lower than the ones considered to estimate the value in use of the Company’s
assets for impairment testing purposes.
The reduction in the value in use of the Company's assets may result in the recognition of losses due to the non-
recoverability of the carrying amounts of these assets.
Given that the oil price is a variable that decisively influences the recoverable amount of assets, the Company carried
out a sensitivity analysis of the effect of using the Brent prices considered in the APS and NZE scenarios, for the
impairment test of the Company's E&P assets in Brazil.
Using the prices in the APS and NZE scenarios to perform a sensitivity analysis on projected gross revenues deducted
of production taxes, net of income taxes, and keeping unchanged all other components, variables, assumptions and
data for calculating the recoverable amount, the Company's E&P segment, regarding the impairment loss recognized
by the Company, as disclosed in note 25, would have additional impairment reversal of US$ 438 in the APS scenario and
additional impairment losses US$ 11,224 in the NZE scenario, concentrated in the Campos basin fields.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-20
The Company does not consider this sensitivity analysis, based on APS and NZE Brent price scenarios, to be the best
estimates to determine expected effects on the recoverable amount of assets, sales revenues or net income.
Considering that the Company did not incorporate in its accounting estimates the carbon price effects, the Company
carried out a sensitivity analysis of the effect of GHG emissions pricing costs on the impairment test of assets in the
E&P segment in Brazil, considering a monetary charge per ton of CO2 emission starting from 2030, and the existence of
free emission allowances.
In this context, using a base price of US$ 10/CO2 in 2030, US$ 49.7/CO2 in 2035, US$ 68/CO2 in 2040, US$ 84.8/CO2 in
2045, and US$ 100.3/CO2 in 2050, including gradual emission exemptions, to simulate additional cash outflows (net of
income taxes), and keeping all other components, variables, assumptions and data for the calculation of recoverable
amount unchanged, the E&P segment would have an additional US$ 232 impairment loss.
The Company does not consider this sensitivity analysis of the effect of greenhouse gas emissions pricing costs on the
impairment test of assets to be the best estimate to determine expected effects on the recoverable amount, neither
the estimated effects on expenses nor net income.
a.2) Potential effects on decommissioning costs
Due to its operations, the Company has legal obligations to remove equipment and restore onshore and offshore areas.
On December 31, 2024, the provision for decommissioning costs recognized by the Company totaled US$ 26,203, as set
out in Note 20. On an undiscounted basis the nominal amount would be US$ 51,953.
The estimated timing used by the Company to account for decommissioning costs are consistent with the useful lives
of the related assets. The average decommissioning period of oil and gas assets weighted by the carrying amounts of
such assets is 14 years.
During 2024, there were no issuances of government regulations related to climate matters that changed or had
potential to change the period for decommissioning the Company's assets, as well as no identification any triggers that
would accelerate the expected dates for decommissioning the Company's assets due to the Company’s climate goals
and ambition to neutralize GHG emissions in activities under its control (scopes 1 and 2) by 2050.
A transition to a low-carbon economy that is faster than anticipated by the Company may accelerate the timing to
remove equipment and restore onshore or offshore areas. Such acceleration would increase the present value of the
decommissioning obligations recognized by the Company.
To illustrate the effect of a possible acceleration of the transition to a low-carbon economy, the Company estimates
that the provision for decommissioning costs would increase by US$ 1,096, US$ 3,553 and US$ 5,913 if the timing
currently used were brought forward by one, three and five years, respectively. This sensitivity analysis assumed that
all other components, variables, assumptions and data for calculating the provision remained unchanged. The year
ranges used are not intended to be predictions of likely future events or outcomes.
a.3) Potential effects on “highly probable future exports” used in cash flow hedge accounting involving the
Company's future exports
A transition to a low-carbon economy that is faster than it was anticipated by the Company may negatively effect the
Company's future exports. Such effect may result in certain exports, whose foreign exchange gains or losses were
designated for hedge accounting, no longer be considered highly probable, but remain forecasted, or, depending on
the magnitude of the transition and its speed, cease to be considered forecasted. The consequences of such effects are
described in the accounting policy of note 33.4.1 (a) involving the Company's future exports.
The calculation of “highly probable future exports” is based on the projected exports in the Strategic Plan, as set out in
note 4.8. The Company considers only a portion of its projected exports as “highly probable future exports”. When
determining future exports as highly probable, and therefore eligible as a hedged item for application of cash flow
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-21
hedge accounting, the Company considers the effects related to the transition to a low-carbon economy. Carbon prices
were not incorporated in such estimates.
Using the prices in the APS and NZE scenarios we carried out a sensitivity analysis to simulate the need to reclassify the
foreign exchange gains or losses recorded in equity to the statement of income. Such analysis simulated a new future
cash flow from exports, changing only the oil price, keeping all other components, variables, assumptions and data
unchanged. In such an analysis, it would be necessary to reclassify the foreign exchange losses, in the amount of US$ 10
(R$ 61 million), recorded in equity to the statement of income in the NZE scenario.
The simulations used to perform such sensitivity analysis, based on Brent prices of the scenarios APS and NZE, are not
considered by the Company as the best estimates to determine expected effects of the reclassification of foreign
exchange variation recorded in equity to the statement of income.
a.4) Potential effects on the useful lives of PP&E
A transition to a low-carbon economy that is faster than the Company anticipates may reduce the useful life of its
assets, which could lead to an increase in annual depreciation, depletion and amortization expenses.
Assets directly related to the production of oil and gas in a contracted area are depleted using the units of production
method and depreciated or amortized using the straight-line method. As of December 31, 2024, the carrying amount
of these assets in operation in Brazil is US$ 90,452. Such assets do not have a useful life ending in or after 2050.
As mentioned in item “Transition risk to low carbon economy”, the reference scenario of the Strategic Plan indicates
that there will be persistent global demand for oil in the coming decades. Additionally, calculations of expected
production and oil and gas reserves in this scenario consider the effects of the transition to a low-carbon economy.
The Company's refining plants consist of 10 refineries in Brazil. Based on the current depreciation rates of the assets in
operation applied to the respective carrying amounts at December 31, 2024, which amounts to US$ 9,220, and assuming
no additional investment, these refineries would have no material depreciation amounts after 2050.
The Company estimates persistent demand for oil products in the coming decades, although decreasing, which should
be progressively supplied by models with lower carbon intensity. Thus, the depreciation rates used by the Company for
the refining plants are in line with the transition to a low-carbon economy.
The Gas and Energy assets in Brazil, including thermoelectric power plants, are depreciated using the linear method.
Based on the current depreciation rates of the assets in operation applied to their respective carrying amounts as of
December 31, 2024, totaling US$ 3,457, and assuming no additional investment, these assets would have no material
depreciation amounts after 2050.
In this context, based on available information, the Company does not foresee significant changes in the useful life of
its refineries, assets directly related to oil and gas production and those related to the Gas and Energy arising from the
transition to a low-carbon economy. Such assets represent 92% of the Company's total assets in operation.
b) Physical Risks
Physical risks result from climate change that can be event-driven (acute physical risk) or from long-term shifts in
climate patterns (chronic physical risk). In this category, the Company does not foresee that changes caused by climate
change will have a material effect on accounting estimates, considering the risks currently identified.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-22
6. New standards and interpretations
6.1. New International Financial Reporting Standards not yet adopted
Standard
Description
Effective on
Lack of Exchangeability -
Amendments to IAS 21
The amendments establish that when one currency is not exchangeable for another on
the measurement date, the spot exchange rate must be estimated. In addition, they
provide guidance on how to assess exchangeability between currencies and how to
determine the spot exchange rate when exchangeability is absent.
When the spot exchange rate is estimated because a currency is not exchangeable for
another currency, information must be disclosed to allow the understanding of how the
currency not exchangeable for another currency affects, or is expected to affect, the
statements of income, the statement of financial position and the statement of cash
flows.
January 1, 2025,
with specific
transition rules.
Annual Improvements –
Volume 11
The amendments alter certain requirements related to: transaction price and
derecognition of lease liabilities (IFRS 9 - Financial Instruments); cost method (IAS 7 -
Statement of Cash Flows); disclosure of gain or loss on derecognition of assets; and credit
risk disclosures (IFRS 7 - Financial Instruments: Disclosures); determination of a ‘de facto
agent’ (IFRS 10 - Consolidated Financial Statements); and hedge accounting by a first-
time adopter (IFRS 1 - First-time Adoption of International Financial Reporting
Standards).
January 1, 2026,
with specific
transition rules.
Amendments to the
Classification and
Measurement of Financial
Instruments -
Amendments to IFRS 9
and IFRS 7
The amendments to IFRS 9 provide clarifications on: assessment of contractual cash
flows for asset classification; financial assets with non-recourse features, and
contractually linked instruments.
They also provide clarifications on the date of initial recognition or derecognition of
financial assets and financial liabilities, and the possibility of derecognizing financial
liabilities that will be settled in cash through an electronic payment system before the
settlement date, provided that certain criteria are met.
The amendments to IFRS 7 introduce new disclosure requirements.
January 1, 2026,
retrospective
application with
specific
transition rules.
Nature-dependent
Electricity Contracts -
Amendments to IFRS 9
and IFRS 7
The amendments introduce changes to IFRS 9 and IFRS 7 to help companies better report
nature-dependent electricity contracts. These amendments comprise: clarifying the
application of the ‘own-use’ requirements; permission of hedge accounting if these
contracts are used as hedging instruments; and additional disclosure requirements.
January 1, 2026,
retrospective
application with
specific
transition rules.
IFRS 18 - Presentation
and Disclosure in
Financial Statements
IFRS 18 establishes new requirements for the presentation and disclosure of financial
statements, replacing IAS 1 - Presentation of Financial Statements. Among others, new
requirements were included on:
a. Presentation of the statement of income, including the obligation to classify all income
and expenses into one of five categories: operating, investing, financing, income taxes
and discontinued operations;
b. Disclosure of performance measures defined by management;
c. Guidance on aggregation or disaggregation of information; and
d. New disclosure requirements.
In addition, certain changes were made to other standards, including accounting
requirements related to the statement of cash flows, such as the exclusion of the
optionality of the classification of cash flows from dividends and interest.
January 1, 2027,
retrospective
application with
specific
transition rules.
IFRS 19 - Subsidiaries
without Public
Accountability:
Disclosures
IFRS 19 is a voluntary standard that enables eligible entities to provide reduced
disclosures when applying IFRS accounting standards in their financial statements.
To be eligible, at the end of the reporting period, an entity must be a subsidiary as defined
in IFRS 10, must not have a public accountability and must have a parent company
(ultimate or intermediate) that prepares consolidated financial statements, available for
public use and complying with IFRS accounting standards.
January 1, 2027,
with specific
transition rules.
Regarding the amendment effective as of January 1, 2025, according to the assessment made, the Company estimates
that there will be no significant effects arising from the initial application on its consolidated financial statements.
In relation to the amendments effective as of January 1, 2026, the Company is assessing the effects that they will have
on its consolidated financial statements.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-23
7. Capital Management
The Company’s objective in its capital management is to maintain its capital structure at an adequate level in order to
continue as a going concern, maximizing value to shareholders and investors. In 2023 and 2022, its main source of
funding was cash provided by its operating activities.
The financial strategy of the Strategic Plan 2025-2029 (“Strategic Plan”) is focused on:
• cash generation greater than investments and financial liabilities;
• high-return investments approved by management only when a positive net present value is expected when using
a brent oil price scenario of US$45 per barrel;
• efficient and more flexible capital structure, with low leverage in challenging scenarios; and
• distribution of dividends according to the current shareholders remuneration policy, with the possibility of
extraordinary payments.
For the gross debt (composed of current and non-current finance debt and lease liability) the ceiling target was
increased to US$ 75,000, converging to US$ 65,000 in the long-term.
As of December 31, 2024, gross debt decreased to US$ 60,311, from US$ 62,600 as of December 31, 2023, remaining
within the range defined in the Company’s Strategic Plan.
This measure is not defined according to the International Financial Reporting Standards - IFRS and should not be
considered in isolation or as a replacement for debt metrics under the IFRS, nor should it be used as a basis for
comparison with the indicators of other companies.
8. Cash and cash equivalents and marketable securities
8.1. Cash and cash equivalents
They include cash, available bank deposits and short-term financial investments with high liquidity, which meet the
definition of cash equivalents.
12.31.2024
12.31.2023
Cash at bank and in hand
136
103
Short-term financial investments
- In Brazil
Brazilian interbank deposit rate investment funds and other short-term deposits
1,453
1,742
Other investment funds
186
279
1,639
2,021
- Abroad
Time deposits
728
7,737
Automatic investing accounts and interest checking accounts
726
2,852
Other financial investments
42
14
1,496
10,603
Total short-term financial investments
3,135
12,624
Total cash and cash equivalents
3,271
12,727
Short-term financial investments in Brazil primarily consist of investments in funds holding Brazilian Federal
Government Bonds that can be redeemed immediately, as well as reverse repurchase agreements that mature within
three months as of the date of their acquisition. Short-term financial investments abroad comprise time deposits that
mature in three months or less from the date of their acquisition, highly-liquid automatic investment accounts, interest
checking accounts and other short-term fixed income instruments.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-24
The main use of these funds in 2024 were for payment of dividends and share repurchase program of US$ 18,784,
repayment of principal and interests related to finance debt and repayment of lease liability, amounting to US$ 16,349,
as well as for acquisition of PP&E and intangible assets in the amount of US$ 14,644.
Cash and cash equivalents were mainly provided by operating activities (US$ 37,984), proceeds from finance debt
(US$ 2,129), proceeds from disposal of assets - divestment (US$ 863) and financial compensation from co-participation
agreements (US$ 397).
Accounting policy for cash and cash equivalents
Cash and cash equivalents comprise cash on hand, term deposits with banks and short-term highly-liquid financial
investments that are readily convertible to known amounts of cash, are subject to insignificant risk of changes in value
and have a maturity of three months or less from the date of acquisition.
8.2. Marketable securities
12.31.2024
12.31.2023
In Brazil
Abroad
Total
In Brazil
Abroad
Total
Fair value through profit or loss
531
−
531
926
−
926
Amortized cost - Bank Deposit Certificates and time deposits
2,263
2,006
4,269
4,249
−
4,249
Amortized cost - Others
45
−
45
53
−
53
Total
2,839
2,006
4,845
5,228
−
5,228
Current
2,257
2,006
4,263
2,819
−
2,819
Non-current
582
−
582
2,409
−
2,409
Marketable securities classified as fair value through profit or loss refer mainly to investments in Brazilian Federal
Government Bonds (amounts determined by level 1 of the fair value hierarchy). These financial investments have
maturities of more than three months.
Securities classified as amortized cost refer to investments in Brazil in floating rate Bank Deposit Certificates with daily
liquidity, with initial maturities between one and two years, and to investments abroad in time deposits with maturities
of more than three months from the contracting date.
Accounting policy for marketable securities
The amounts invested in operations with terms of more than three months, as from the date of the agreement, are
initially measured at fair value and subsequently according to their respective classifications, which are based on the
way in which these funds are managed and their features of contractual cash flows:
•
Amortized cost – financial assets that give rise, on specified dates, to cash flows represented exclusively by
payments of principal and interest on the outstanding principal amount, the purpose of which is to receive its
contractual cash flows. They are presented in current and in non-current assets according to their expectation
of realization. Interest income from these investments is calculated using the effective interest rate method.
•
Fair value through profit or loss – financial assets whose purpose is to receive from its sale. They are presented
in current assets due to the expectation of realization within 12 months of the reporting date.
9.
Sales revenues
9.1. Revenues from contracts with customers
Revenues from contracts with customers derive from different products sold by the Company’s operating segments,
taking into consideration specific characteristics of the markets where they operate. For additional information about
the operating segments of the Company, its activities and its respective products sold, see note 13.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-25
The determination of transaction prices derives from methodologies and policies based on the parameters of these
markets, reflecting operating risks, level of market share, changes in exchange rates and international commodity
prices, including Brent oil prices, oil products such as diesel and gasoline, and the Henry Hub Index.
2024
2023
2022
Diesel
27,522
32,260
40,149
Gasoline
12,692
14,309
16,175
Liquefied petroleum gas
3,166
3,506
5,121
Jet fuel
4,518
5,015
5,423
Naphtha
1,869
1,837
2,396
Fuel oil (including bunker fuel)
976
1,158
1,411
Other oil products
4,273
4,428
5,536
Subtotal oil products
55,016
62,513
76,211
Natural gas
4,707
5,632
7,673
Crude oil
4,334
5,475
7,719
Renewables and nitrogen products
223
94
283
Breakage
439
860
669
Electricity
744
657
694
Services, agency and others
812
1,059
1,043
Domestic market
66,275
76,290
94,292
Exports
24,251
25,012
27,497
Crude oil
18,290
18,447
19,332
Fuel oil (including bunker fuel)
4,775
5,114
7,399
Other oil products and other products
1,186
1,451
766
Sales abroad (1)
890
1,107
2,685
Foreign market
25,141
26,119
30,182
Sales revenues
91,416
102,409
124,474
(1) Sales revenues from operations outside of Brazil, including trading and excluding exports.
As of December 31, 2024, the composition of sales revenues by shipping destination is presented as follows:
2024
2023
2022
Domestic market
66,275
76,290
94,292
China
7,701
7,232
6,389
Americas (except United States)
3,610
4,846
7,166
Europe
5,440
5,534
5,932
Asia (except China and Singapore)
1,989
1,447
1,505
United States
3,471
3,924
4,914
Singapore
2,883
3,063
4,271
Others
47
73
5
Foreign market
25,141
26,119
30,182
Sales revenues
91,416
102,409
124,474
In 2024, sales to two clients of the refining, transportation and marketing (RT&M) segment represented individually
15% and 10% of the Company’s sales revenues; in 2023, sales to two clients of the RT&M segment represented
individually 16% and 11% of the Company’s sales revenues; and in 2022, sales to two clients of the RT&M segment
represented individually 15% and 11% of the Company’s sales revenues.
9.2. Remaining performance obligations
The Company is party to sales contracts signed through December 31, 2024 with original expected duration of more
than 1 year, which define the volume and timing of goods or services to be delivered during the term of the contract,
and the payment terms for these future sales.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-26
The estimated remaining values of these contracts in 2024 presented below are based on the contractually agreed
future sales volumes, as well as prices prevailing at December 31, 2024 or practiced in recent sales reflecting more
directly observable information:
Expected
recognition
within 1
year
Expected
recognition
after 1 year
Total
Domestic market
Gasoline
10,466
88
10,554
Diesel
22,885
-
22,885
Natural gas
6,584
26,764
33,348
Liquefied petroleum gas
2,929
-
2,929
Services and others
1,416
917
2,333
Ethanol, nitrogen products and renewables
47
-
47
Naphtha
1,379
-
1,379
Electricity
270
3,736
4,006
Other oil products
1,448
2,250
3,698
Jet fuel
991
-
991
Foreign market
Exports
2,815
2,685
5,500
Total
51,230
36,440
87,670
Revenues are recognized once goods are transferred and services are provided to the customers and their
measurement and timing of recognition will be subject to future demands, changes in commodities prices, exchange
rates and other market factors.
The table above does not include information on contracts with original expected duration of less than one year, such
as spot-market contracts, variable considerations which are constrained, and information on contracts only
establishing general terms and conditions (Master Agreements), for which volumes and prices will only be defined in
subsequent contracts.
In addition, electricity sales are mainly driven by demands to generate electricity from thermoelectric power plants, as
and when requested by the Brazilian National Electric System Operator (ONS). These requests are substantially affected
by Brazilian hydrological conditions. Thus, the table above presents mainly fixed amounts for the electricity to be
available to customers in these operations.
9.3. Contract liabilities
The balance of contract liabilities carried on the statement of financial position in 2024 amounted to US$ 64 (US$ 115
in 2023). This amount is classified as other current liabilities and primarily comprises advances from customers in ship
and take or pay contracts to be recognized as revenue based on future sales of natural gas or following the non-exercise
of the right by the customer.
Accounting policy for revenues
The Company evaluates contracts with customers for the sale of oil and oil products, natural gas, electricity, services
and other products, which will be subject to revenue recognition, and identifies the distinct goods and services promised
in each of them.
Sales revenues are recognized when control is transferred to the client, which usually occurs upon delivery of the
product or when the service is provided. At this moment, the Company satisfies the performance obligation.
Performance obligations are considered to be promises to transfer to the client: (i) good or service (or group of goods
or services) that is distinct; and (ii) a series of distinct goods or services that have the same characteristics or are
substantially the same and that have the same pattern of transfer to the client.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-27
Revenue is measured based on the amount of consideration to which the Company expects to be entitled in exchange
for transfers of promised goods or services to the customer, excluding amounts collected on behalf of third parties.
Transaction prices are based on contractually stated prices, which reflect the Company's pricing methodologies and
policies based on market parameters.
Invoicing occurs in periods very close to deliveries and rendering of services, therefore, significant changes in
transaction prices are not expected to be recognized in revenues for periods subsequent to satisfaction of the
performance obligation, except for some exports in which final price formation occurs after the transfer of control of
the products and are subject to the variation in the value of the commodity.
Sales are carried out in short terms of receipt, thus there are no significant financing components.
10. Costs and expenses by nature
10.1. Cost of sales
2024
2023
2022
Raw material, products for resale, materials and third-party services (1)
(22,368)
(21,912)
(33,196)
Acquisitions
(16,278)
(16,198)
(26,609)
Crude oil imports
(9,458)
(9,358)
(11,212)
Oil products imports
(5,080)
(4,649)
(8,869)
Natural gas imports
(1,740)
(2,191)
(6,528)
Third-party services and others
(6,090)
(5,714)
(6,587)
Depreciation, depletion and amortization
(9,777)
(10,779)
(10,514)
Production taxes
(11,392)
(12,108)
(14,953)
Employee compensation
(1,888)
(1,690)
(1,665)
Inventory turnover
(19)
(1,946)
842
Total
(45,444)
(48,435)
(59,486)
(1) It Includes short-term leases.
10.2. Selling expenses
2024
2023
2022
Materials, third-party services, freight, rent and other related costs
(4,080)
(4,296)
(3,987)
Depreciation, depletion and amortization
(670)
(609)
(789)
Reversal (allowance) for expected credit losses
2
(22)
(58)
Employee compensation
(126)
(111)
(97)
Total
(4,874)
(5,038)
(4,931)
10.3. General and administrative expenses
2024
2023
2022
Employee compensation
(1,204)
(1,036)
(865)
Materials, third-party services, rent and other related costs
(495)
(435)
(362)
Depreciation, depletion and amortization
(146)
(123)
(105)
Total
(1,845)
(1,594)
(1,332)
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-28
11. Other income and expenses, net
2024
2023
2022
Stoppages for asset maintenance and pre-operating expenses
(2,617)
(2,205)
(1,834)
Losses on decommissioning of returned/abandoned areas
(2,584)
(1,195)
(225)
Pension and medical benefits - retirees
(2,196)
(1,172)
(1,015)
Losses with legal, administrative and arbitration proceedings
(996)
(797)
(1,362)
Variable compensation programs (1)
(932)
(1,011)
(678)
Allowance (reversals) for credit loss on trade and other receivables, net
(260)
(18)
3
Institutional relations and cultural projects
(224)
(156)
(103)
Operating expenses with thermoelectric power plants
(221)
(189)
(150)
Expenses with contractual fines received
(136)
(199)
(91)
Compensation for the termination of vessel charter agreements
(19)
(331)
(13)
Collective bargaining agreement
(8)
(217)
-
Gains (losses) with commodities derivatives
42
11
(256)
Amounts recovered from Lava Jato investigation
60
109
96
Government grants
161
315
471
Ship/take or pay agreements
219
238
105
Results on disposal/write-offs of assets
228
1,295
1,144
Fines imposed on suppliers
249
239
228
Results from co-participation agreements in bid areas
259
284
4,286
Results of non-core activities
261
170
168
Early termination and changes to cash flow estimates of leases
349
415
629
Reimbursements from E&P partnership operations
493
571
683
Others
(21)
(188)
(264)
Total
(7,893)
(4,031)
1,822
(1) It comprises Profit Sharing (PLR) and Performance Award Program (PRD), as described in note 18.
12. Net finance income (expense)
2024
2023
2022
Finance income
1,954
2,169
1,832
Income from investments and marketable securities (Government Bonds)
1,507
1,657
1,159
Other finance income
447
512
673
Finance expenses
(5,957)
(3,922)
(3,500)
Interest on finance debt
(2,146)
(2,264)
(2,363)
Unwinding of discount on lease liability
(2,265)
(1,785)
(1,340)
Capitalized borrowing costs
1,570
1,290
1,032
Unwinding of discount on the provision for decommissioning costs
(1,000)
(857)
(519)
Tax settlement programs - federal taxes (1)
(1,785)
−
−
Other finance expenses
(331)
(306)
(310)
Foreign exchange gains (losses) and indexation charges
(11,104)
(580)
(2,172)
Foreign exchange gains (losses) (2)
(8,459)
2,268
1,022
Real x U.S. dollar
(8,503)
2,396
1,089
Other currencies
44
(128)
(67)
Reclassification of hedge accounting to the Statement of Income (2)
(2,992)
(3,763)
(4,871)
Tax settlement programs - federal taxes (1)
(267)
−
−
Indexation to the Selic interest rate of anticipated dividends and dividends payable
(282)
(299)
994
Legal agreement with Eletrobras - compulsory loans
−
236
−
Recoverable taxes inflation indexation income
92
204
86
Other foreign exchange gains and indexation charges, net
804
774
597
Total
(15,107)
(2,333)
(3,840)
(1) For more information, see note 17.
(2) For more information, see notes 33.4.1.a and 33.4.1.c.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-29
13.
Information by operating segment
13.1. Net income by operating segment
2024
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Eliminations
Total
Sales revenues
60,516
85,281
9,518
319
(64,218)
91,416
Intersegments
60,208
1,035
2,969
6
(64,218)
−
Third parties
308
84,246
6,549
313
-
91,416
Cost of sales
(24,823)
(78,836)
(5,031)
(294)
63,540
(45,444)
Gross profit (loss)
35,693
6,445
4,487
25
(678)
45,972
Income (expenses)
(7,639)
(3,257)
(3,497)
(4,703)
−
(19,096)
Selling expenses
(1)
(1,928)
(2,936)
(9)
-
(4,874)
General and administrative expenses
(64)
(356)
(115)
(1,310)
-
(1,845)
Exploration costs
(913)
-
-
-
-
(913)
Research and development expenses
(629)
(6)
(4)
(150)
-
(789)
Other taxes
(692)
(47)
(18)
(494)
-
(1,251)
Impairment (losses) reversals, net
(1,244)
(300)
-
13
-
(1,531)
Other income and expenses, net
(4,096)
(620)
(424)
(2,753)
-
(7,893)
Income (loss) before net finance expense, results of
equity-accounted investments and income taxes
28,054
3,188
990
(4,678)
(678)
26,876
Net finance expense
-
-
-
(15,107)
-
(15,107)
Results of equity-accounted investments
76
(780)
80
(3)
-
(627)
Net income / (loss) before income taxes
28,130
2,408
1,070
(19,788)
(678)
11,142
Income taxes
(9,540)
(1,084)
(335)
7,190
232
(3,537)
Net income (loss) for the year
18,590
1,324
735
(12,598)
(446)
7,605
Attributable to:
Shareholders of Petrobras
18,593
1,324
682
(12,625)
(446)
7,528
Non-controlling interests
(3)
-
53
27
-
77
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-30
2023
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Eliminations
Total
Sales revenues
66,880
94,868
11,109
365
(70,813)
102,409
Intersegments
66,113
1,404
3,285
11
(70,813)
−
Third parties
767
93,464
7,824
354
-
102,409
Cost of sales
(27,239)
(85,699)
(5,685)
(370)
70,558
(48,435)
Gross profit (loss)
39,641
9,169
5,424
(5)
(255)
53,974
Income (expenses)
(5,615)
(4,086)
(3,384)
(2,857)
1
(15,941)
Selling expenses
(12)
(2,156)
(2,838)
(33)
1
(5,038)
General and administrative expenses
(74)
(327)
(80)
(1,113)
-
(1,594)
Exploration costs
(982)
-
-
-
-
(982)
Research and development expenses
(569)
(16)
(3)
(138)
-
(726)
Other taxes
(454)
(27)
(49)
(360)
-
(890)
Impairment (losses) reversals, net
(2,105)
(524)
(81)
30
-
(2,680)
Other income and expenses, net
(1,419)
(1,036)
(333)
(1,243)
-
(4,031)
Income (loss) before net finance expense, results of
equity-accounted investments and income taxes
34,026
5,083
2,040
(2,862)
(254)
38,033
Net finance expense
-
-
-
(2,333)
-
(2,333)
Results of equity-accounted investments
(7)
(318)
10
11
-
(304)
Net income / (loss) before income taxes
34,019
4,765
2,050
(5,184)
(254)
35,396
Income taxes
(11,571)
(1,729)
(693)
3,506
86
(10,401)
Net income (loss) for the year
22,448
3,036
1,357
(1,678)
(168)
24,995
Attributable to:
Shareholders of Petrobras
22,453
3,036
1,286
(1,723)
(168)
24,884
Non-controlling interests
(5)
-
71
45
-
111
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-31
2022
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Eliminations
Total
Sales revenues
77,890
113,531
15,068
511
(82,526)
124,474
Intersegments
76,579
1,950
3,991
6
(82,526)
−
Third parties
1,311
111,581
11,077
505
-
124,474
Cost of sales
(30,465)
(99,154)
(10,518)
(522)
81,173
(59,486)
Gross profit (loss)
47,425
14,377
4,550
(11)
(1,353)
64,988
Income (expenses)
907
(3,132)
(2,965)
(2,671)
(13)
(7,874)
Selling expenses
(22)
(1,841)
(2,979)
(76)
(13)
(4,931)
General and administrative expenses
(46)
(275)
(62)
(949)
-
(1,332)
Exploration costs
(887)
-
-
-
-
(887)
Research and development expenses
(678)
(6)
(5)
(103)
-
(792)
Other taxes
(79)
(31)
(44)
(285)
-
(439)
Impairment (losses) reversals, net
(1,218)
(97)
1
(1)
-
(1,315)
Other income and expenses, net
3,837
(882)
124
(1,257)
-
1,822
Income (loss) before net finance expense, results of
equity-accounted investments and income taxes
48,332
11,245
1,585
(2,682)
(1,366)
57,114
Net finance expense
-
-
-
(3,840)
-
(3,840)
Results of equity-accounted investments
170
3
83
(5)
-
251
Net income / (loss) before income taxes
48,502
11,248
1,668
(6,527)
(1,366)
53,525
Income taxes
(16,433)
(3,822)
(540)
3,559
466
(16,770)
Net income (loss) for the year
32,069
7,426
1,128
(2,968)
(900)
36,755
Attributable to:
Shareholders of Petrobras
32,073
7,426
1,038
(3,014)
(900)
36,623
Non-controlling interests
(4)
-
90
46
-
132
Other income and expenses, net by segment
2024
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Total
Stoppages for asset maintenance and pre-operating expenses
(2,419)
(80)
(98)
(20)
(2,617)
Losses on decommissioning of returned/abandoned areas
(2,584)
-
-
-
(2,584)
Pension and medical benefits - retirees
-
-
-
(2,196)
(2,196)
Losses with legal, administrative and arbitration proceedings
(386)
(411)
(30)
(169)
(996)
Variable compensation programs
(407)
(227)
(47)
(251)
(932)
Operating expenses with thermoelectric power plants
-
-
(221)
-
(221)
Ship/take or pay agreements
5
79
132
3
219
Results on disposal/write-offs of assets
234
51
18
(75)
228
Results from co-participation agreements in bid areas
259
-
-
-
259
Others
1,202
(32)
(178)
(45)
947
Total
(4,096)
(620)
(424)
(2,753)
(7,893)
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-32
Other income and expenses, net by segment
2023
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Total
Stoppages for asset maintenance and pre-operating expenses
(2,105)
(21)
(52)
(27)
(2,205)
Losses on decommissioning of returned/abandoned areas
(1,195)
-
-
-
(1,195)
Pension and medical benefits - retirees
-
-
-
(1,172)
(1,172)
Variable compensation programs
(416)
(268)
(53)
(274)
(1,011)
Losses with legal, administrative and arbitration proceedings
(300)
(391)
(9)
(97)
(797)
Operating expenses with thermoelectric power plants
-
-
(189)
-
(189)
Ship/take or pay agreements
4
40
192
2
238
Results from co-participation agreements in bid areas
284
-
-
-
284
Results on disposal/write-offs of assets
1,370
(35)
(48)
8
1,295
Others
939
(361)
(174)
317
721
Total
(1,419)
(1,036)
(333)
(1,243)
(4,031)
Other income and expenses, net by segment
2022
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Total
Stoppages for asset maintenance and pre-operating expenses
(1,743)
(23)
(31)
(37)
(1,834)
Losses with legal, administrative and arbitration proceedings
(461)
(428)
(72)
(401)
(1,362)
Pension and medical benefits - retirees
-
-
-
(1,015)
(1,015)
Variable compensation programs
(279)
(144)
(36)
(219)
(678)
Losses on decommissioning of returned/abandoned areas
(225)
-
-
-
(225)
Operating expenses with thermoelectric power plants
-
-
(150)
-
(150)
Ship/take or pay agreements
2
32
70
1
105
Results on disposal/write-offs of assets
868
100
164
12
1,144
Results from co-participation agreements in bid areas
4,286
-
-
-
4,286
Others
1,389
(419)
179
402
1,551
Total
3,837
(882)
124
(1,257)
1,822
The amount of depreciation, depletion and amortization by segment is set forth as follows:
Exploration
and Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and Low
Carbon
Energies
(G&LCE)
Corporate and
other
businesses
Total
2024
9,292
2,495
557
135
12,479
2023
10,230
2,410
525
115
13,280
2022
10,415
2,248
448
107
13,218
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-33
13.2. Assets by operating segment
Exploration
and
Production
(E&P)
Refining,
Transportation
& Marketing
(RT&M)
Gas and
Low
Carbon
Energies
(G&LCE)
Corporate
and other
businesses
Elimina-
tions
Total
Consolidated assets by operating segment - 12.31.2024
Current assets
2,697
9,017
379
13,923
(4,180)
21,836
Non-current assets
122,854
18,708
4,881
13,366
−
159,809
Long-term receivables
7,056
2,217
91
11,246
−
20,610
Investments
299
114
182
64
−
659
Property, plant and equipment
113,761
16,257
4,541
1,726
−
136,285
Operating assets
91,895
14,828
3,936
1,242
−
111,901
Under construction
21,866
1,429
605
484
−
24,384
Intangible assets
1,738
120
67
330
−
2,255
Total Assets
125,551
27,725
5,260
27,289
(4,180)
181,645
Consolidated assets by operating segment - 12.31.2023
Current assets
2,804
11,002
370
23,547
(5,278)
32,445
Non-current assets
136,064
23,800
6,406
18,352
−
184,622
Long-term receivables
9,028
2,068
83
15,619
−
26,798
Investments
344
811
145
58
−
1,358
Property, plant and equipment
124,254
20,786
6,101
2,283
−
153,424
Operating assets
108,405
18,128
3,605
1,770
−
131,908
Under construction
15,849
2,658
2,496
513
−
21,516
Intangible assets
2,438
135
77
392
−
3,042
Total Assets
138,868
34,802
6,776
41,899
(5,278)
217,067
Accounting policy for operating segments
The information related to the Company’s operating segments is prepared based on available financial information
directly attributable to each segment, or items that can be allocated to each segment on a reasonable basis. This
information is presented by business activity, as used by the Company’s Board of Executive Officers (Chief Operating
Decision Maker – CODM) in the decision-making process of resource allocation and performance evaluation.
The measurement of segment results includes transactions carried out with third parties, including associates and joint
ventures, as well as transactions between operating segments. Transfers between operating segments are recognized
at internal transfer prices derived from methodologies that considers market parameters and are eliminated only to
provide reconciliations to the consolidated financial statements.
The Company's business segments disclosed separately are:
Exploration and Production (E&P): this segment covers the activities of exploration, development and production of
crude oil, NGL (natural gas liquid) and natural gas in Brazil and abroad, for the primary purpose of supplying its domestic
refineries. The E&P segment also operates through partnerships with other companies and includes holding interest in
foreign entities operating in this segment.
As an energy Company with a focus on oil and gas, intersegment sales revenue refers mainly to oil transfers to the
Refining, Transportation and Marketing segment, aiming to supply the Company's refineries and meet the domestic
demand for oil products. These transactions are measured by internal transfer prices based on international oil prices
and their respective exchange rate impacts, taking into account the specific characteristics of the transferred oil stream.
In addition, the E&P segment revenues include transfers of natural gas to the natural gas processing plants within Gas
and Low Carbon Energies segment. These transactions are measured at internal transfer prices based on the
international prices of this commodity.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-34
Revenue from sales to third parties mainly reflects services rendered relating to E&P activities, sales of the E&P’s
natural gas processing plants, as well as the oil and natural gas operations carried out by subsidiaries abroad.
Refining, Transportation and Marketing (RT&M): this segment covers the refining, logistics, transport, acquisition and
exports of crude oil, as well as trading of oil products, in Brazil and abroad. This segment also includes the petrochemical
operations (which comprehends holding interests in petrochemical companies in Brazil), and fertilizer production.
This segment carries out the acquisition of crude oil from the E&P segment, imports oil for refinery slate, and acquires
oil products in international markets taking advantage of the existing price differentials between the cost of processing
domestic oil and that of importing oil products. This segment also performs the acquisition of natural gas from the
G&LCE segment.
Intersegment revenues primarily reflect the sale of oil products to the distribution business at market prices and the
operations for the G&LCE and E&P segments at internal transfer price.
Revenues from sales to third parties primarily reflect the trading of oil products in Brazil and the export and trade of oil
and oil products by foreign subsidiaries.
Gas and Low Carbon Energies (G&LCE): this segment covers the activities of logistic and trading of natural gas and
electricity, the transportation and trading of liquefied natural gas (LNG), the generation of electricity by means of
thermoelectric power plants, as well as natural gas processing. It also includes renewable energy businesses, low carbon
services (carbon capture, utilization and storage) and the production of biodiesel and its co-products.
Intersegment revenues primarily reflect the transfers of natural gas processed, liquefied petroleum gas (LPG) and NGL
to the RT&M segment. These transactions are measured at internal transfer prices.
This segment purchases national natural gas from the E&P segment, from partners and third parties, imports natural
gas from Bolivia and LNG to meet national demand.
Revenues from sales to third parties primarily reflect natural gas processed to distributors and to free consumers, as
well as generation and trading of electricity.
Corporate and other businesses: comprise items that cannot be attributed to business segments, including those with
corporate characteristics, in addition to distribution business. Corporate items mainly include those related to
corporate financial management, trade and other receivables, allowance for credit losses, gains (losses) with derivatives
(except those with commodity derivatives included in their respective segments), corporate overhead and other
expenses, including actuarial expenses related to pension and health care plans for beneficiaries. Other businesses
include the distribution of oil products abroad (South America).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-35
14. Trade and other receivables
14.1. Trade and other receivables
12.31.2024
12.31.2023
Receivables from contracts with customers
Third parties
3,779
6,038
Related parties
Investees (note 34.1)
117
140
Subtotal
3,896
6,178
Other trade receivables
Third parties
Receivables from divestments and Transfer of Rights Agreement
1,677
2,162
Lease receivables
298
352
Other receivables
592
627
Related parties
Petroleum and alcohol accounts - receivables from Brazilian Federal Government
−
278
Subtotal
2,567
3,419
Total trade and other receivables, before ECL
6,463
9,597
Expected credit losses (ECL) - Third parties
(1,639)
(1,613)
Expected credit losses (ECL) - Related parties
(2)
(2)
Total trade and other receivables
4,822
7,982
Current
3,566
6,135
Non-current
1,256
1,847
Trade and other receivables are generally classified as measured at amortized cost, except for receivables with final
prices linked to changes in commodity price after their transfer of control, which are classified as measured at fair value
through profit or loss, amounting to US$ 416 as of December 31, 2024 (US$ 503 as of December 31, 2023).
The balance of receivables from divestment and Transfer of Rights Agreement is mainly related to the earnout of the
Sépia and Atapu fields, totaling US$ 508 (US$ 611 as of December 31, 2023), from the sale of the Roncador field, totaling
US$ 353 (US$ 360 as of December 31, 2023), the Potiguar cluster, totaling US$ 217 (US$ 265 as of December 31, 2023);
and the Albacora Leste field, totaling US$ 174 (US$ 60 as of December 31, 2023).
On June 26, 2024, the second and final installment of the judicialized debts with the Brazilian Federal Government
(precatórios), arising from of Petroleum and Alcohol Account, was released to the Company and immediately deposited
in guarantee of a tax lawsuit. The deposit amounts to US$ 224 as of December 31, 2024.
In 2024, the average term for trade receivables from third parties in the domestic market is approximately 2 days (same
term in 2023) for the sale of derivatives and 20 to 27 days for the sale of crude oil (same term as in 2023). Fuel oil exports
have an average receipt term between 11 and 15 days, while oil exports have a term between 9 and 13 days (in 2023,
exports have average terms ranging from 11 days to 14 days for fuel oil and from 8 to 12 days for oil).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-36
14.2. Aging of trade and other receivables – third parties
12.31.2024
12.31.2023
Trade and
other
receivables
Expected
credit
losses
Trade and
other
receivables
Expected
credit
losses
Current
4,513
(168)
6,948
(34)
Overdue:
1-90 days (1)
213
(75)
472
(43)
91-180 days
63
(23)
19
(10)
181-365 days
30
(18)
63
(57)
More than 365 days
1,527
(1,355)
1,677
(1,469)
Total
6,346
(1,639)
9,179
(1,613)
(1) On January 10, 2024, Petrobras received US$ 298 from Carmo Energy as the last installment relating to the sale of the Carmópolis cluster, which
was due on December 20, 2023.
14.3. Provision for expected credit losses – third parties and related parties
Changes
12.31.2024
12.31.2023
Opening balance
1,615
1,536
Additions
328
170
Write-offs
(12)
(66)
Reversals
(62)
(94)
Translation adjustment
(228)
69
Closing balance
1,641
1,615
Current
305
285
Non-current
1,336
1,330
Accounting policy for trade and other receivables
Trade and other receivables are generally classified at amortized cost, except for certain receivables classified at fair
value through profit or loss, whose cash flows are distinct from the receipt of principal and interest, including
receivables with final prices linked to changes in commodity price after their transfer of control.
When the Company is the lessor in a finance lease, a receivable is recognized at the amount of the net investment in the
lease, consisting of the lease payments receivable and any unguaranteed residual value accruing to the Company,
discounted at the interest rate implicit in the lease.
The Company measures expected credit losses (ECL) for short-term trade receivables using a provision matrix which is
based on historical observed default rates adjusted by current and forward-looking information when applicable and
available without undue cost or effort.
ECL is the weighted average of historical credit losses with the respective default risks, which may occur according to
the weightings. The credit loss on a financial asset is measured by the difference between all contractual cash flows due
to the Company and all cash flows the Company expects to receive, discounted at the original effective interest rate.
The Company measures the allowance for ECL of other trade receivables based on their 12-month expected credit
losses unless their credit risk increases significantly since their initial recognition, in which case the allowance is based
on their lifetime ECL.
When determining whether there has been a significant increase in credit risk, the Company compares the risk of default
on initial recognition and at the reporting date.
Regardless of the assessment of credit risk, a 30-day period of default triggers the definition of significant increase in
credit risk on a financial asset, unless otherwise demonstrated by reasonable and supportable information, such as the
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-37
existence of contractual or financial guarantees, which have the potential to influence credit risk, thus affecting the
application of the risk matrix percentages.
The Company assumes that the credit risk on the trade receivable has not increased significantly since initial recognition
if the receivable is considered to have low credit risk at the reporting date. Low credit risk is determined based on
external credit ratings or internal methodologies.
In the absence of controversy or other issues that may result in the suspension of collection, the Company assumes
that a default occurs whenever the counterparty does not comply with the legal obligation to pay its debts when due
or, depending on the instrument, when it is at least 90 days past due.
15. Inventories
12.31.2024
12.31.2023
Crude oil
2,645
3,375
Oil products
2,161
2,196
Intermediate products
424
635
Natural gas and Liquefied Natural Gas (LNG)
101
78
Biofuels
22
13
Fertilizers
1
1
Total products
5,354
6,298
Materials, supplies and others
1,356
1,383
Total
6,710
7,681
Crude oil can be traded or used for production of oil products.
Oil products mainly include diesel, gasoline, jetfuel and naphta, and are generally traded.
Intermediate products are those product streams that have been through at least one of the refining processes, but
still need further treatment, processing or converting to be available for sale.
Natural gas is initially processed, and its derivatives are subsequently traded or transferred to thermoelectric power
plants and refineries, while LNG can be traded or converted to natural gas.
Biofuels mainly include ethanol and biodiesel inventories.
Materials, supplies and others mainly comprise production supplies and operating materials used in the operations of
the Company, stated at the average purchase cost, not exceeding replacement cost.
In 2024, the Company recognized a US$ 42 reversal of cost of sales, adjusting inventories to net realizable value (a US$ 7
reversal of cost of sales in 2023), primarily due to changes in international prices of crude oil and oil products.
At December 31, 2024, the Company had pledged crude oil and oil products volumes as collateral for the Term of
Financial Commitment (TFC) related to Pension Plans PPSP-R, PPSP-R Pre-70 and PPSP-NR Pre-70 signed by Petrobras
and Fundação Petrobras de Seguridade Social – Petros Foundation in 2008, in the estimated amount of US$ 761 (US$
986 at December 31, 2023).
Accounting policy for inventories
Inventories are determined by the weighted average cost method adjusted to the net realizable value when it is lower
than their carrying amount.
Net realizable value is the estimated selling price of inventory in the ordinary course of business, less estimated cost of
completion and estimated expenses to complete its sale, considering the purpose for which the inventories are held.
Inventories with identifiable sales contracts have a net realizable value based on the contracted price, as, for example,
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-38
in offshore operations (without physical tanking, with loading onto the ship and direct unloading at the customer) or
auctions. Other items in inventory have a net realizable value based on general selling prices, considering the most
reliable evidence available at the time of the estimate.
The net realizable value of inventories is determined by grouping similar items with the same characteristic or purpose.
Changes in sales prices after the reporting date of the financial statements are considered in the calculation of the net
realizable value if they confirm the conditions existing on that reporting date.
16. Trade payables
12.31.2024
12.31.2023
Third parties in Brazil
3,657
3,624
Third parties abroad
2,409
1,176
Related parties
16
13
Total
6,082
4,813
Forfaiting
The Company has a program to encourage the development of the oil and gas production chain called “Mais Valor”
(More Value), operated by a partner company on a 100% digital platform.
By using this platform, the suppliers who want to anticipate their receivables may launch a reverse auction, in which the
winner is the financial institution which offers the lowest discount rate. The financial institution becomes the creditor
of invoices advanced by the supplier, and Petrobras pays the invoices on the same date and under the conditions
originally agreed with the supplier.
Invoices are advanced in the “Mais Valor” program exclusively at the discretion of the suppliers and do not change the
terms, prices and commercial conditions contracted by Petrobras with such suppliers, as well as it does not add financial
charges to the Company, therefore, the classification is maintained as Trade payables in Statements of Cash Flows
(Cash flows from operating activities).
As of December 31, 2024, the balance advanced by suppliers, within the scope of the program, is US$ 134 (US$ 110 as
of December 31, 2023) and has a payment term from 7 to 92 days and a weighted average term of 58 days (payment
term from 7 to 92 days and a weighted average term of 57 days in 2023), after the contracted commercial conditions
have been met.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-39
17. Taxes
17.1. Income taxes
Current taxes
Current assets
Current liabilities
Non-current liabilities
12.31.2024
12.31.2023
12.31.2024
12.31.2023
12.31.2024
12.31.2023
Taxes in Brazil
Income taxes (1)
405
199
698
989
330
−
Income taxes - Tax settlement programs
−
−
49
58
200
299
405
199
747
1,047
530
299
Taxes abroad
6
19
653
253
−
−
Total
411
218
1,400
1,300
530
299
(1) It includes uncertain tax treatments (see note 17.1).
Income taxes are calculated based on a 15% rate plus additional 10% on the taxable income for the IRPJ, and 9% on
taxable income for the CSLL, considering the offset of tax loss carryforwards and negative basis of the CSLL, limited to
30% of the taxable income of the year. As of 2015, due to the release of Law No. 12,973/2014, the net income obtained
abroad by a direct or indirect subsidiary, or by an associated company, adjusted by dividends and by the result of equity
accounted investments, multiplied by the income taxes rates existing in Brazil, comprise the income taxes expenses.
Income taxes assets refer mainly to tax credits resulting from the monthly process for estimation and payment of
income taxes, in addition to the negative balance of IRPJ and CSLL related to 2017, 2018, 2019 and 2021. Income taxes
within current liabilities refer to the current portion of IRPJ and CSLL to be paid.
Tax settlement programs mainly relate to a notice of deficiency issued by the Brazilian Federal Revenue Service due to
the treatment of expenses arising from the Terms of Financial Commitment (TFC). These amounts are deductible in
determining taxable profit for the calculation of income taxes. The payment term is 145 monthly installments, indexed
by the Selic interest rate, as of January 2018.
Reconciliation between statutory income tax rate and effective income tax rate
The following table provides the reconciliation of Brazilian statutory tax rate to the Company’s effective rate on income
before income taxes:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-40
2024
2023
2022
Net income before income taxes
11,142
35,396
53,525
Nominal income taxes computed based on Brazilian statutory corporate tax rates (34%)
(3,787)
(12,036)
(18,197)
Adjustments to arrive at the effective tax rate:
Tax benefits from the deduction of interest on capital distributions
1,319
1,329
1,234
Different jurisdictional tax rates for companies abroad
969
579
822
Brazilian income taxes on income of companies incorporated outside Brazil (1)
(502)
(530)
(763)
Tax incentives
101
303
187
Effects of the global minimum tax
(91)
-
-
Internal transfer prices adjustments for operations between related parties abroad (2)
(92)
-
-
Tax loss carryforwards (unrecognized tax losses) (3)
93
23
221
Enrollment in the tax settlement program (4)
(145)
-
-
Post-employment benefits (5)
(1,280)
(348)
(394)
Results of equity-accounted investments in Brazil and abroad
(233)
(88)
87
Non-incidence of income taxes on indexation (SELIC interest rate) of undue paid taxes
113
54
33
Others
(2)
313
-
Income taxes
(3,537)
(10,401)
(16,770)
Deferred income taxes
4,046
(876)
(906)
Current income taxes
(7,583)
(9,525)
(15,864)
Effective tax rate of income taxes
31.7%
29.4%
(31.3)%
(1) It relates to Brazilian income taxes on earnings of offshore investees, as established by Law No. 12,973/2014.
(2) Law 14,596/23 effective as of January 1, 2024.
(3) In 2024, Petrobras recognized a tax loss and a negative basis of the CSLL of a subsidiary in the amount of US$ 53, within the scope of the incentivized self-regulation
program for taxes administered by the Federal Revenue of Brazil (Law No. 14.740/23 and RFB Normative Instruction No. 2.168/23), to settle a debt amounting to US$ 112,
with a US$ 59 down payment.
(4) It arises from non-deductible expenses with fines related to the enrollment to the tax settlement program. For more information, see note 17.3.
(5) It includes uncertain tax treatments (see note 17.1.1).
Deferred income taxes - non-current
The changes in the deferred income taxes are presented as follows:
2024
2023
Opening balance
(9,945)
(5,918)
Recognized in the statement of income for the period
4,046
(876)
Recognized in shareholders’ equity
3,920
(2,559)
Translation adjustment
1,439
(602)
Use of tax loss carryforwards
(6)
-
Others
(2)
10
Closing balance
(548)
(9,945)
The composition of deferred tax assets and liabilities is set out in the following table:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-41
Nature
Realization basis
12.31.2024
12.31.2023
PP&E - Exploration and decommissioning costs
Depreciation, amortization and write-offs of assets
(6,286)
(6,296)
PP&E - Impairment
Amortization, impairment reversals and write-offs of
assets
3,462
4,203
PP&E - Right-of-use assets
Depreciation, amortization and write-offs of assets
(8,518)
(9,369)
PP&E - depreciation methods and capitalized borrowing
Depreciation, amortization and write-offs of assets
(16,043)
(18,784)
Loans, trade and other receivables / payables and financing
Payments, receipts and considerations
2,636
(2,479)
Leasings
Appropriation of the considerations
10,829
9,240
Provision for decommissioning costs
Payments and use of provisions
9,118
8,010
Provision for legal proceedings
Payments and use of provisions
818
954
Tax loss carryforwards
Taxable income compensation
976
1,140
Inventories
Sales, write-downs and losses
424
411
Employee Benefits
Payments and use of provisions
1,191
2,036
Others
845
989
Total
(548)
(9,945)
Deferred tax assets
922
965
Deferred tax liabilities
(1,470)
(10,910)
Timing of reversal of deferred income taxes
Deferred tax assets were recognized based on projections of taxable profit in future periods supported by the
assumptions within the Company’s Business Plan 2025-2029, whose pillars are the preservation of financial strength,
financial and environment resilience of projects, and focus on value creation.
Management considers that the deferred tax assets will be realized to the extent the deferred tax liabilities are reversed
and expected taxable events occur based on its Business Plan 2025-2029.
The estimated schedule of recovery/reversal of net deferred tax assets and liabilities as of December 31, 2024 is set
out in the following table:
Assets
Liabilities
2025
125
(635)
2026
53
(1,070)
2027
56
(809)
2028
76
685
2029
64
705
2030 and thereafter
548
2,594
Recognized deferred tax assets
922
1,470
In addition, the Company has tax loss carryforwards arising from offshore subsidiaries, for which no deferred taxes were
recognized.
Assets
12.31.2024
12.31.2023
Brazil
4
368
Abroad
635
780
Unrecognized deferred tax assets
639
1,148
These unrecognized deferred tax assets arise mainly from subsidiaries operating in the oil and gas exploration and
production and refining activities in the United States.
An aging of the unrecognized deferred tax assets from companies abroad is set out below:
2026-2029
2030-2032
2033-2035
2036-2038
Undefined
expiration
Total
Unrecognized deferred tax assets
14
147
292
130
52
635
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-42
17.1.1. Uncertain tax treatments on income taxes
As of December 31, 2024, the Company has US$ 767 (US$ 330 as of December 31, 2023) of uncertain tax treatments,
provisioned in the statement of financial position, mainly related to the deduction of amounts paid in the basis of
calculation of income taxes in Brazil, as well as to the incidence of Corporate Income Tax (CIT) on transactions abroad,
related to judicial and administrative proceedings. In addition, the Company has US$ 5,229 of uncertain tax treatments
(US$ 6,982 as of December 31, 2023), unprovisioned, in Brazil and abroad, on income taxes related to judicial and
administrative proceedings (see note 19.3).
As of December 31, 2024, the Company has other positions that can be considered as uncertain tax treatments on
income taxes amounting to US$ 4,274 (US$ 4,063 as of December 31, 2023), given the possibility of different
interpretation by the tax authority. These uncertain tax treatments are supported by technical assessments and tax
risk assessment methodology. Therefore, Petrobras believes that such positions are likely to be accepted by the tax
authorities (including judicial courts).
Thus, as of December 31, 2024, the total amount of uncertain tax treatments amounts to US$ 10,270 (US$ 11,375 as of
December 31, 2023), for which Petrobras will continue to defend its position.
Accounting policy for income taxes
The Company calculates income taxes in accordance with current legislation and applying the rates in effect at the end
of reporting period. Income taxes expense for the period are recognized in the statement of income of the period, except
when the tax arises from a transaction or event which is recognized directly in equity.
a) Current income taxes
Current income taxes are offset when they relate to income taxes levied on the same taxable entity and by the same tax
authority, when there is a legal right and the entity has the intention to set off current tax assets and current tax
liabilities, simultaneously.
Uncertain tax treatments are periodically assessed, considering the probability of acceptance by the tax authority.
b) Deferred income taxes
Deferred income taxes are generally recognized on temporary differences between the tax base of an asset or liability
and its carrying amount. They are measured at the tax rates that are provided for in the specific legislation to apply to
the period when the asset is realized or the liability is settled.
Deferred tax assets and liabilities are recognized for all deductible temporary differences and carryforward of unused
tax losses or credits to the extent that it is probable that taxable profit will be available against which those deductible
temporary differences can be utilized. When there are insufficient taxable temporary differences relating to the same
taxation authority and the same taxable entity, a deferred tax is recognized to the extent that it is probable that the
entity will have sufficient taxable profit in future periods, based on projections approved by management and
supported by the Company’s Strategic Plan.
Deferred tax assets and liabilities are offset when they relate to income taxes levied on the same taxable entity, when a
legally enforceable right to set off current tax assets and current tax liabilities exists and when the deferred tax assets
and deferred tax liabilities relate to taxes levied by the same tax authority on the same taxable entity.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-43
17.2. Other taxes
Current assets
Non-current assets
Current liabilities
Non-current liabilities (1)
12.31.2024 12.31.2023 12.31.2024 12.31.2023 12.31.2024 12.31.2023
12.31.2024
12.31.2023
Taxes in Brazil
Current / Non-current ICMS (VAT)
461
592
599
607
916
1,032
−
−
Current / Non-current PIS and COFINS
1,043
304
2,044
2,876
373
265
134
141
Claim to recover PIS and COFINS
−
−
590
733
−
−
−
−
Production taxes
−
−
−
−
1,509
2,094
87
145
Withholding income taxes
−
−
−
−
294
272
−
−
Others
45
58
344
290
169
443
80
90
Total in Brazil
1,549
954
3,577
4,506
3,261
4,106
301
376
Taxes abroad
6
6
24
10
23
60
−
−
Total
1,555
960
3,601
4,516
3,284
4,166
301
376
(1) Other non-current taxes are classified within other non-current liabilities in the statement of financial position.
(2) At December 31, 2024, current assets comprises deferred PIS and COFINS amounts reclassified from non-current assets, as well as tax credits arising from the
enrollment to the tax settlement program (see note 17.3).
Current and non-current ICMS (VAT) credits arise from requests for extemporaneous and overpaid tax, offset in
accordance with the legislation of each state. They also arise on the acquisition of assets for property, plant and
equipment, which are offset in a straight line over 4 years.
Current and non-current PIS/COFINS credits mainly refer to the acquisition of goods and services for assets under
construction, since their use is permitted only after these assets enter into production. These credits also refer to
extemporaneous tax credits requested to the Brazilian Federal Revenue Service from 2017 to 2024, for which the
Company has been filing lawsuits to speed up the analysis by the Brazilian Federal Revenue Service, of which the amount
of US$ 62 was allowed and used in the basis of calculation of PIS and COFINS for 2024.
Production taxes are financial compensation due by companies that explore and produce oil and natural gas in Brazilian
territory. They are composed of royalties, special participations, signature bonuses and payment for retention or
occupation of area. They include the amounts referring to an agreement with the ANP to close a legal proceeding
involving the recalculation of royalties and special participations relating to oil production in the Jubarte field, from
August 2009 to February 2011 and from December 2012 to February 2015.
Claim to recover PIS and COFINS
The Company filed civil lawsuits against the Brazilian Federal Government, claiming to recover PIS and COFINS paid over
finance income and foreign exchange variation gains, from February 1999 to January 2004.
The court granted to the Company, in all the lawsuits, the definitive right to recover those taxes. Regarding two actions
relating to Petroquisa, a former subsidiary that had been incorporated by the Company, the corresponding amounts
were paid by the Brazilian Federal Government in previous years. In relation to the two remaining cases, both had rulings
by the court favorable to the Company and, in one of them, the Brazilian Federal Government has already expressed its
agreement and there was a decision in favor of the Company, still subject to appeal. Regarding the other lawsuit, there
is no court decision at this point.
17.3. Enrollment to the tax settlement program
In June 2024, Petrobras enrolled to a Transaction Notice published in the same month by the Attorney General's Office
of the Brazilian National Treasury (PGFN) and the Brazilian Federal Revenue (RFB), for the settlement of relevant
litigation related to the taxation of remittances abroad, arising from the bipartition of the legal transaction agreed in a
chartering contract for vessels and platforms, and in another contract for services.
The Transaction Notice provided for the settlement of debts under dispute relating to the taxation of CIDE, PIS and
COFINS, from 2008 to 2013, whose updated amount on June 28, 2024, date of the enrollment, was US$ 8,087. For more
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-44
information on the balance of the contingent liability related to the taxation of remittances abroad, which includes the
debts relating to the taxation of CIDE, PIS and COFINS, see note 19.3.
The enrollment to this program brings economic benefits, as continuing the discussions would require further financial
effort to provide and maintain judicial guarantees related to the Negotiated Legal Proceeding (NJP) agreed with the
PGFN, in addition to other procedural costs and expenses.
The Transaction Notice provided for a 65% discount on the debt in Brazilian reais, after the conversion of related judicial
deposits into definitive payment. Therefore, on the enrollment date, the Company recognized a US$ 3,571 liability in
the statement of financial position, within other taxes payable, relating to CIDE, PIS, and COFINS. The settlement of this
tax liability is defined as follows:
12.31.2024
Enrollment to the program
3,571
Use of judicial deposits
(1,197)
Use of tax credits
(233)
Indexation to the Selic interest rate
47
Down payment and monthly installments
(2,154)
Translation adjustment
(34)
Balance at December 31, 2024
−
As part of this tax transaction is related to projects in which the Company operates in partnership in E&P consortia,
Petrobras started negotiations with its partners for the reimbursement of the corresponding amounts to their
respective interests, in the expected amount of US$ 476, which were recognized and received in 2024.
Effects or the tax transaction in the statement of income
Jan-
Dec/2024
Principal and fines
1,640
Indexation to the SELIC interest rate as of the enrollment
2,043
Total debt enrolled in the tax settlement program (1)
3,683
PIS and COFINS tax credits after enrolling the program (2)
(538)
Use of tax loss carryforwards
(240)
Indexation to the Selic interest rate of Judicial deposits, taxes over tax credits and others
289
Income taxes (3)
(932)
Effect in the statement of income
2,262
Reimbursements approved by partners in joint ventures until December 31, 2024
(476)
Income taxes (3)
143
Total effect on the statement of income
1,929
Other taxes
669
Net finance income (expense)
2,050
Income taxes
(789)
Total effect on the statement of income
1,930
(1) Amounts differ from the previous table due to different exchange rates on translation of liabilities (closing exchange rate) and income and expenses (average
exchange rate).
(2) It arises from the debts included in the tax transaction, after discount applied, as provided for in the transaction notice, recognized in the statement of financial
position, within other recoverable taxes, and used in the calculation of these taxes for January and February 2025.
(3) Tax effects resulting from the tax transaction.
17.4. Global Minimum Tax (Pillar II)
In December 2021, the Organization for Economic Cooperation and Development (OECD) released the Pillar II model
rules to ensure that multinationals companies with annual revenues exceeding €750 million pay a minimum 15% tax on
income in each jurisdiction where they operate (Global Minimum Tax).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-45
The Pillar II provides that, if the Parent Entity is located in a jurisdiction that has not implemented these set of rules,
this tax will be levied on the next entity in the organizational structure (Intermediate Parent Entity) located in a
jurisdiction that has implemented it, following a top-down approach.
The Netherlands and Spain enacted new tax legislation to implement the Pillar II rules, effective January 2024.
Singapore also implemented it, effective January 2025.
Brazil has implemented the Domestic Minimum Top-up Tax, effective January 2025, known as "additional to CSLL",
applicable only to Brazilian companies. Petrobras is in the process of assessing if there is any exposure arising from this
legislation and expects to complete the assessment during 2025.
Considering that, in 2024, Brazil had not implemented any Top-up tax legislation and following the top-down approach,
Petrobras was subject to the Top-up Tax through its Intermediate Parent Entity, Petrobras International Braspetro B.V.
(PIBBV), based in the Netherlands. Thus, in 2024, a US$ 94 Top-up expense was recognized within income taxes, related
to the Netherlands jurisdiction, where the effective tax rate did not reach the minimum 15% threshold provided for the
Pillar II legislation. No material tax liability is expected in the other jurisdictions where the PIBBV has investments.
Petrobras applied the temporary relief of deferred tax assets or liabilities arising from this new taxation, permitted by
the amendments to the IAS 12 - Income taxes. Accordingly, the Top-up income taxes are recognized as current income
taxes when incurred, without recognizing deferred tax assets or liabilities related to the Pillar II.
18. Employee benefits
Employee benefits are all forms of consideration given by the Company in exchange for service rendered by employees
or for the termination of employment. It also includes expenses with directors and management. Such benefits include
salaries, post-employment benefits, termination benefits and other benefits.
12.31.2024
12.31.2023
Liabilities
Short-term employee benefits
1,517
1,986
Termination benefits
72
143
Post-employment benefits
11,398
16,382
Total
12,987
18,511
Current
2,315
2,932
Non-current
10,672
15,579
18.1. Short-term employee benefits
12.31.2024
12.31.2023
Profit sharing
384
605
Performance award program
349
464
Accrued vacation
519
574
Salaries and related charges and other provisions
265
343
Total
1,517
1,986
Current
1,486
1,944
Non-current (1)
31
42
(1) Remaining balance relating to the four-year deferral of the PPP portion of executive officers and the upper management.
The Company recognized the following amounts in the statement of income:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-46
Expenses recognized in the statement of income
2024
2023
2022
Salaries, accrued vacations and related charges
(3,652)
(3,478)
(3,006)
Management fees and charges
(14)
(14)
(14)
Variable compensation programs (1)
(932)
(1,011)
(678)
Performance award program (2)
(468)
(416)
(547)
Profit sharing (2)
(464)
(595)
(131)
Total
(4,598)
(4,503)
(3,698)
(1) It includes adjustments to provisions related to previous years.
(2) Amount recognized as other income and expenses - see note 11.
18.1.1. Variable compensation programs
The Company recognizes the contribution of employees to the results achieved through two programs: Profit sharing
and results sharing and Performance award program.
For 2024, the variable compensation programs are limited to 5% of the adjusted EBITDA.
Profit Sharing (Participações nos lucros ou resultados - PLR)
Profit sharing (PLR) is a variable remuneration mechanism that aims to share the Company's results with its employees.
From 2023, considering the change implemented in the Company's variable compensation programs, the PLR also
included employees with managerial functions, becoming the main variable compensation program of the Company.
For the payment of PLR (approved by the Secretariat of Management and Governance of State-owned Companies -
SEST), the Company needs to meet the following triggers:
•
Declaration and payment of distribution to shareholders approved by the Company’s Board of Directors;
•
Net income for the year and achieving at least 80% of the weighted average of a set of proposed indicators;
•
The total amount is limited to the lower of 6.25% of the net income and to 25% of the dividends distributed to
shareholders. In 2024, the PLR calculated corresponded to 6.19% of the net income of the year, according to
the average percentage of achievement of the indicators.
In relation to the PLR, in 2024, the Company:
•
Settled US$ 577, considering the agreement and individual limits according to their remuneration.
•
Provisioned US$ 464 referring to 2024 (US$ 591 in 2023), recorded in other income and expenses.
Performance award program (Programa de Prêmio por Desempenho - PRD)
The PRD intends to recognize the effort and individual performance of each employee to achieve the Company’s results.
The amounts to be paid to each employee continues to be defined by the achievement of the key metrics (which
currently are Delta Valor Petrobras - VALOR, Greenhouse Gas Emissions Target Achievement Indicator - IAGEE, and
Indicator of Commitment to the Environment - ICMA) and of the individual goals (performance management score for
all employees, with exception of executive managers, for whom the scorecard of their respective departments will be
considered).
The PRD establishes that, in order to trigger this payment, it is necessary to have a declaration and payment of
distribution to shareholders approved by the Company’s Board of Directors, as well as net income for the year. The total
amount is limited to a percentage of the net income or the Adjusted EBITDA for the year (a non-GAAP measure defined
as net income plus net finance income (expense); income taxes; depreciation, depletion and amortization; results in
equity-accounted investments; impairment of assets; results on disposal/write-offs of assets; and results from co-
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-47
participation agreements in bid areas). This program was revised in 2023, replacing the Programa de Prêmio por
Performance (PPP), to complement the PLR.
In relation to the PRD, in 2024, the Company:
•
Settled US$ 498, of which US$ 412 in relation to 2023, since the metrics relating to the Company’s and
individual performance were achieved in that year, and US$ 86 as an advance made in December 2024 relating
to the program for 2024;
•
Provisioned US$ 468 referring to 2024 (US$ 415 for the same period of 2023), recorded in other income and
expenses, including variable compensation programs from consolidated companies.
Accounting policy for variable compensation programs (PLR and PRD)
The provisions for variable compensation programs are recognized on an accrual basis, during the periods in which the
employees provided services. They represent the estimates of future disbursements arising from past events, based
on the criteria and metrics of the PRD and PLR, provided that the requirements for activating these programs are met
and that the obligation can be reliably estimated.
18.2. Termination benefits
Termination benefits are employee benefits provided in exchange for the termination of labor contract as a result of
either: i) the Company’s decision to terminate the labor contract before the employee’s normal retirement date; or ii)
an employee’s decision to accept an offer of benefits in exchange for the termination of their employment.
Voluntary severance programs
The Company has voluntary severance programs (PDV), specific for employees of the corporate segment and of
divestment assets, which provide for the same legal and indemnity advantages. These programs are currently closed
for enrollment.
Recognition of the liability and the expense for termination benefits occur as employees enroll to the programs.
The Company disburses the severance payments in two installments, one at the time of termination and the remainder
one year after the termination.
As of December 31, 2024, termination liabilities amounts to US$ 72, relating to 743 employees enrolled in voluntary
severance programs with expected termination by December 2027, in addition to the second installment of 23 retired
employees.
18.3. Post-employment benefits
The Company maintains a health care plan for its employees in Brazil (active and retiree) and their dependents (Saúde
Petrobras - AMS), and five other major plans of post-employment benefits (collectively referred to as “pension plans”).
The following table presents the balance of post-employment benefits:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-48
12.31.2024
12.31.2023
Liabilities
Health Care Plan - Saúde Petrobras
7,499
9,662
Petros Pension Plan - Renegotiated (PPSP-R)
2,289
4,221
Petros Pension Plan - Non-renegotiated (PPSP-NR)
779
1,338
Petros Pension Plan - Renegotiated - Pre-70 (PPSP-R Pre 70)
395
519
Petros Pension Plan - Non-renegotiated - Pre-70 (PPSP-NR Pre 70)
379
461
Petros 2 Pension Plan (PP-2)
57
181
Total
11,398
16,382
Current
808
907
Non-current
10,590
15,475
18.3.1. Nature and risks associated with defined benefit plans
Health Care Plan
The health care plan Saúde Petrobras – AMS is managed and run by Petrobras Health Association (Associação Petrobras
de Saúde – APS), a nonprofit civil association, and includes prevention and health care programs. The plan offers
assistance to all employees, retirees, pensioners and eligible family members, according to the rules of the plan and in
the Collective Bargaining Agreement (ACT) and is open to new employees.
Sponsored by Petrobras, Transpetro, PBIO, TBG and Termobahia, this plan is primarily exposed to the risk of increase
in medical costs due to inflation, new technologies, new types of coverage and an increase in the utilization of medical
benefits. The Company continuously improves the quality of its technical and administrative processes, as well as the
health programs offered to beneficiaries in order to mitigate such risks.
Employees, retirees and pensioners make monthly fixed contributions to cover high-risk procedures and variable
contributions for the cost of medical procedures, both based on the contribution tables of the plan, which are
determined based on certain parameters, such as salary and age levels. The plan also includes assistance towards the
purchase of certain medicines through reimbursement or acquisition and home delivery, with co-participation of
beneficiaries.
Benefits are paid by the Company based on the costs incurred by the beneficiaries. The financial participation of the
Company and the beneficiaries on the expenses are provided for in the plan rules and in the ACT, being 60% by the
Company and 40% by the participants until March 31, 2024.
As provided in clause 37, paragraph 2 of the ACT, if the resolutions No. 42/2022 and No. 49/2023 of the Commission on
Corporate Governance and the Administration of Corporate Holdings of the Brazilian Federal Government (Comissão
de Governança Corporativa e de Administração de Participações Societárias da União – CGPAR) were revoked or
amended, allowing adjustments in the cost-sharing of health care plans, the Company and the labor unions would
discuss a new cost-sharing arrangement, in order to minimize the impact on the income of its beneficiaries.
On April 26, 2024, the aforementioned resolutions were revoked and, for this reason, the Company and the unions
entered into an agreement, in June 2024, via amendment to the current collective bargaining agreement, to resume the
costing relationship previously practiced, with 70% covered by Petrobras and 30% by the beneficiaries, effective since
April 2024. Due to this change, the Company carried out an intermediate remeasurement of the actuarial liabilities of
this plan.
Intermediate remeasurement on the health care plan
The intermediate remeasurement of this post-employment plan made in June 2024 resulted in a US$ 23 increase in
actuarial liabilities, as follows: (i) a US$ 1,291 expense within other income and expenses, due to the change in the
benefit costing; (ii) a US$ 1,265 gain within other comprehensive income due to the revision of actuarial assumptions,
mainly the increase in the discount rate applied to the actuarial liability, from 5.45% as of December 31, 2023 to 6.48%
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-49
as of June 30, 2024, and to the reduction in the estimated changes in medical and hospital costs, from 13.11% as of
December 31, 2023 to 12.70% as of June 30, 2024; and (iii) a US$3 gain within translation adjustments.
The other actuarial assumptions used to carry out the intermediate remeasurement in the second quarter of 2024 had
no change in relation to those used in the annual remeasurement made as of December 31, 2023.
Annual revision of the health care plan
At December 31, 2024, this obligation was revised using the updated actuarial assumptions, which results are shown in
note 18.3.2.
Pension plans
The Company’s post-retirement plans are managed by Petros Foundation (Fundação Petrobras de Seguridade Social),
a nonprofit legal entity governed by private law with administrative and financial autonomy.
Pension plans in Brazil are regulated by the National Council for Supplementary Pension (Conselho Nacional de
Previdência Complementar – CNPC), which establishes all guidelines and procedures to be adopted by the plans for their
management and relationship with stakeholders.
Petros Foundation periodically carries out revisions of the plans and, when applicable, establishes measures aiming at
maintaining the financial sustainability of the plans.
The net obligation with pension plans recorded by the Company is measured in accordance with the requirements of
IFRS which has a different measurement methodology to that applicable to pension funds in Brazil, which are regulated
by the CNPC.
The main difference between these methodologies is that, in the CNPC criterion, Petros Foundation considers the future
cash flows of normal and extraordinary sponsor’s contributions, discounted to present value, while the Company
considers these cash flows as they are realized. In addition, Petros Foundation sets the real interest rate based on
profitability expectations and on parameters set by PREVIC - Superintendência Nacional de Previdência Complementar
(National Supplementary Pension Authority), while the Company uses a rate that combines the maturity profile of the
obligations with the yield curve of government bonds. Regarding the plan assets, Petros Foundation marks government
bonds at market or on the curve, while the Company marks them at market value.
The major post-retirement pension benefits sponsored by the Company are:
•
Petros Plan - Renegotiated (PPSP-R);
•
Petros Plan - Renegotiated - Pre-70 (PPSP-R Pre-70);
•
Petros Plan - Non-renegotiated (PPSP-NR);
•
Petros Plan - Non-renegotiated - Pre-70 (PPSP-NR Pre-70);
•
Petros 2 Plan (PP-2); and
•
Petros 3 Plan (PP-3)
PPSP-R, PPSP-NR, PPSP-R Pre-70, PPSP-NR Pre-70 and PP-3 are sponsored by Petrobras, and PP-2 by Petrobras,
Transpetro, PBIO, TBG, Termobahia and Termomacaé.
The PPSP-R and PPSP-NR were created in 2018 as a split of Petros Plan (PPSP) originally established by the Company
in July 1970. On January 1, 2020, PPSP-R Pre-70 and PPSP-NR Pre-70 were created as a split of PPSP-R and PPSP-NR,
respectively.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-50
Pension plans supplement the income of their participants during retirement, in addition to guaranteeing a pension for
the beneficiaries in case of the death of a participant. The benefit consists of a monthly income supplementing the
benefit granted by the Brazilian Social Security Institute.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-51
The following table provides other characteristics of these plans:
PPSP-R
PPSP-R
PPSP-NR
PPSP-NR
PP-2
PP-3
Pre-70
Pre-70
Modality
Defined Benefit
Defined Benefit
Defined Benefit
Defined Benefit
Variable Contribution
(defined benefit and
defined contribution
portions)
Defined Contribution
Participants of the plan
Generally covers
employees and former
employees who joined
the company after
1970 that agreed with
changes proposed by
the Company in its
original pension plan
(P0) and amendments.
Generally covers
employees and former
employees hired prior
to July 1, 1970, who
enrolled in the P0 until
January 1, 1996 and
remained continuously
linked to the original
sponsor obtaining the
condition of assisted.
Generally covers
employees and former
employees who joined
the company after
1970 that did not agree
with changes proposed
by the Company in its
original pension plan
(P0) and amendments
Generally covers
employees and former
employees hired prior to
July 1, 1970, who enrolled
in the P0 until January 1,
1996 and remained
continuously linked to the
original sponsor obtaining
the condition of assisted
and did not agreed with
changes in in its original
pension plan (P0) and
amendments.
This Plan was established
in 2007, covering
employees and former
employees coming from
new contests that moved
from other existing plans.
This plan was
implemented in 2021,
exclusive option for
voluntary migration of
employees and retirees
from the PPSP-R and
PPSP-NR plans.
New enrollments
Closed
Closed
Closed
Closed
Open
Closed
Retirement payments
Lifetime monthly payments supplementing the benefit granted by the Brazilian National Institute of
Social Security.
Lifetime defined benefit
monthly payments or
non- defined benefit
monthly payments in
accordance with the
participant's election.
Undefined benefit with
monthly payments, in
accordance with the
participant election.
Other general benefits
Lump sum death benefit (insured capital) and monthly payments related to the following events: death, disability, sickness, and
seclusion.
Lump sum death benefit
(insured capital) and
monthly payments
related to the following
events: death, disability,
sickness, and seclusion.
Indexation of Retirement
payments by the plan
Based on the Nationwide Consumer Price Index.
Based on the current index levels applicable to
active employees’ salaries and the indexes set out
by the Brazilian National Institute of Social Security.
Lifetime defined benefit
monthly payments: based
on the Nationwide
Consumer Price Index.
Undefined benefit
monthly payments:
based on the variation of
individual account
quota.
Undefined benefit
monthly payments: based
on the variation of the
individual account quota.
Undefined benefit
monthly payments:
based on the variation of
individual account
quota.
Parity contributions made by
participants and the
Company to the plans
It is comprised of:
It is comprised of:
It is comprised of:
It is comprised of:
It is comprised of:
Regular parity
contributions during the
employment
relationship, saving for
the undefined benefit,
accumulated in
individual accounts
i) normal contributions
that cover expected
cost of the plans in the
long term; and
normal contributions
that cover expected
cost of the plans in the
long term.
i) normal contributions
that cover expected
cost of the plans in the
long term; and
normal contributions that
cover expected cost of the
plans in the long term.
i) normal contributions
that cover expected cost
of the plans in the long
term; and
ii) extraordinary
contributions that
cover additional costs
that are generally
derived from actuarial
deficits.
Participants are
exempt from paying
any extraordinary
contributions in case of
deficit until the
settlement of the TFC.
ii) extraordinary
contributions that
cover additional costs
that are generally
derived from actuarial
deficits.
Participants are exempt
from paying any
extraordinary
contributions in case of
deficit until the
settlement of the TFC.
ii) extraordinary
contributions that cover
additional costs derived
from actuarial deficits (as
provided for in the plan
rules for the defined
benefit portion of the
plan.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-52
Deficit Settlement Plan (PED)
(1)
Petros' Foundation
Deliberative Council
approved a plan to
settle the deficit
registered by the
PPSP-R in 2021. On
April 1, 2023, this plan
was implemented,
following a favorable
decision held on March
17, 2023 by the SEST.
N/A
Petros' Foundation
Deliberative Council
approved a plan to
settle the deficit
registered by the
PPSP-NR in 2022. On
April 1, 2024, this plan
was implemented,
following a favorable
decision held on April,
09, 2024 by the SEST.
N/A
N/A
N/A
Debt Assumption Instrument
relating to Deficit Settlement
Plan 2015 (PED 2015) -
referring these contributions
were not previously made due
to court injunctions. Amounts
to be paid to Petros
Foundation (1).
Financial obligations
with a principal
amounting to US$89 at
12/31/2024.
N/A
Financial obligations
with a principal
amounting to US$32 at
12/31/2024.
N/A
N/A
N/A
Terms of Financial
Commitment - TFC (debt
agreements) assumed by the
Company to settle the
deficits. Amounts to be paid
to Petros Foundation (1)
Financial obligations
amounting to US$93 at
12/31/2024.
Financial obligations
amounting to US$475
at 12/31/2024.
Financial obligations
settled early in 2021.
Financial obligations
amounting to US$410 at
12/31/2024.
N/A
N/A
Annually remeasured in accordance with actuarial assumptions, with semi-annual payment of interest
based on the updated balance and maturing in 2028.
(1) This obligation is recorded in these financial statements, within actuarial liabilities.
18.3.2. Net actuarial liabilities and expenses, and fair value of plans assets
a) Changes in the actuarial liabilities recognized in the statement of financial position
Net actuarial liabilities represent the obligations of the Company, net of the fair value of plan assets (when applicable),
at present value.
For information on actuarial assumptions used to determine the defined benefit obligation, see the table in Note 18.3.6.
Changes in the actuarial liabilities related to pension and healthcare plans with defined benefit characteristics is
presented as follows:
2024
Pension Plans
Health Care
Plan
Total
PPSP-R (1) PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Amounts recognized in the Statement of Financial Position
Present value of obligations
9,992
3,233
874
7,498
21,597
(-) Fair value of plan assets
(7,308)
(2,075)
(816)
−
(10,199)
Net actuarial liability as of December 31, 2024
2,684
1,158
58
7,498
11,398
Changes in the net actuarial liability
Balance as of January 1, 2024
4,740
1,799
181
9,662
16,382
Recognized in the Statement of Income
399
153
13
2,369
2,934
Past service cost (2)
−
−
−
1,291
1,291
Current service cost
10
2
−
198
210
Net interest
389
151
13
880
1,433
Recognized in Equity - other comprehensive income
(1,053)
(281)
(84)
(1,861)
(3,279)
(Gains)/losses arising from the remeasurement (2)
(1,053)
(281)
(84)
(1,861)
(3,279)
Cash effects
(382)
(121)
(13)
(485)
(1,001)
Contributions paid
(355)
(108)
(13)
(485)
(961)
Payments related to Term of financial commitment (TFC)
(27)
(13)
−
−
(40)
Other changes
(1,020)
(392)
(39)
(2,187)
(3,638)
Translation Adjustment
(1,020)
(392)
(39)
(2,187)
(3,638)
Balance at December 31, 2024
2,684
1,158
58
7,498
11,398
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
(2) It includes effects of the intermediate remeasurement on the health care plan, which changed the benefit costing.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-53
2023
Pension Plans
Health
Care Plan
Total
PPSP-R (1)
PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Amounts recognized in the Statement of Financial Position
Present value of obligations
14,941
4,806
1,357
9,662
30,766
(-) Fair value of plan assets
(10,201)
(3,007)
(1,176)
−
(14,384)
Net actuarial liability as of December 31, 2023
4,740
1,799
181
9,662
16,382
Changes in the net actuarial liability
Balance as of January 1, 2023
3,890
1,380
163
5,813
11,246
Recognized in the Statement of Income
490
169
30
853
1,542
Current service cost
11
2
10
144
167
Net interest
479
167
20
709
1,375
Recognized in Equity - other comprehensive income
433
253
(14)
2,902
3,574
(Gains)/losses arising from the remeasurement (2)
433
253
(14)
2,902
3,574
Cash effects
(385)
(115)
(12)
(415)
(927)
Contributions paid
(357)
(103)
(12)
(415)
(887)
Payments related to Term of financial commitment (TFC)
(28)
(12)
−
−
(40)
Other changes
312
112
14
509
947
Others
−
−
−
1
1
Translation Adjustment
312
112
14
508
946
Balance at December 31, 2023
4,740
1,799
181
9,662
16,382
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
(2) It includes a complement of US$ 109 related to 2022.
b) Changes in present value of the obligation
2024
Pension Plans
Health Care
Plan
Total
PPSP-R (1) PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Present value of obligations at the beginning of the year
14,941
4,806
1,357
9,662
30,766
Recognized in the Statement of Income
1,241
397
112
2,369
4,119
Interest expense
1,231
395
112
880
2,618
Service cost
10
2
−
1,489
1,501
Recognized in Equity - other comprehensive income
(1,949)
(577)
(233)
(1,861)
(4,620)
Remeasurement: Experience (gains) / losses
(8)
15
190
(464)
(267)
Remeasurement: (gains) / losses - demographic assumptions
−
−
7
1
8
Remeasurement: (gains) / losses - financial assumptions
(1,941)
(592)
(430)
(1,398)
(4,361)
Others
(4,241)
(1,393)
(362)
(2,672)
(8,668)
Benefits paid, net of assisted contributions
(999)
(354)
(79)
(488)
(1,920)
Contributions paid by participants
24
5
16
−
45
Translation Adjustment
(3,266)
(1,044)
(299)
(2,184)
(6,793)
Present value of obligations at the end of the year
9,992
3,233
874
7,498
21,597
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-54
2023
Pension Plans
Health
Care Plan
Total
PPSP-R (*)
PPSP-NR (*)
Petros 2
Saúde
Petrobras-AMS
Present value of obligations at the beginning of the year
12,771
4,119
1,102
5,813
23,805
Recognized in the Statement of Income
1,559
496
141
853
3,049
Interest expense
1,548
494
131
709
2,882
Service cost
11
2
10
144
167
Recognized in Equity - other comprehensive income
737
274
73
2,902
3,986
Remeasurement: Experience (gains) / losses (2)
(318)
(107)
(94)
54
(465)
Remeasurement: (gains) / losses - demographic assumptions
929
80
(1)
127
1,135
Remeasurement: (gains) / losses - financial assumptions (2)
126
301
168
2,721
3,316
Others
(126)
(83)
41
94
(74)
Benefits paid, net of assisted contributions
(1,165)
(413)
(61)
(413)
(2,052)
Contributions paid by participants
25
6
9
−
40
Translation Adjustment
1,014
324
93
507
1,938
Present value of obligations at the end of the year
14,941
4,806
1,357
9,662
30,766
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
(2) It includes a complement of US$ 109 related to 2022.
c) Changes in the fair value of plan assets
Petrobras has four pension plans (PPSP-R, PPSP-NR, PPSP-R Pre-70) which are currently making use of plan assets,
and one plan (PP-2) in which most of participants are in the phase of accumulating funds.
Therefore, changes to the fair value of plan assets reflect these effects, including inflows of contributions, outflows of
funds for payment of benefits, and the return of these assets.
2024
Pension Plans
Health Care
Plan
Total
PPSP-R (1) PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Fair value of plan assets at the beginning of the year
10,201
3,007
1,176
−
14,384
Recognized in the Statement of Income
842
244
99
−
1,185
Interest income
842
244
99
−
1,185
Recognized in Equity - other comprehensive income
(896)
(296)
(149)
−
(1,341)
Cash effects
382
121
13
485
1,001
Contributions paid by the sponsor (Company)
355
108
13
485
961
Term of financial commitment (TFC) paid by the Company
27
13
−
−
40
Other Changes
(3,221)
(1,001)
(323)
(485)
(5,030)
Contributions paid by participants
24
5
16
−
45
Benefits paid, net of assisted contributions
(999)
(354)
(79)
(488)
(1,920)
Translation Adjustment
(2,246)
(652)
(260)
3
(3,155)
Fair value of plan assets at the end of the year
7,308
2,075
816
−
10,199
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-55
2023
Pension Plans
Health
Care Plan
Total
PPSP-R (1)
PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Fair value of plan assets at the beginning of the year
8,881
2,739
939
−
12,559
Recognized in the Statement of Income
1,069
327
111
−
1,507
Interest income
1,069
327
111
−
1,507
Recognized in Equity - other comprehensive income
304
21
87
−
412
Remeasurement: Higher/(lower) return on plan assets compared to
discount rate
304
21
87
−
412
Cash effects
385
115
12
415
927
Contributions paid by the sponsor (Company)
357
103
12
415
887
Term of financial commitment (TFC) paid by the Company
28
12
−
−
40
Other Changes
(438)
(195)
27
(415)
(1,021)
Contributions paid by participants
25
6
9
−
40
Benefits paid, net of assisted contributions
(1,165)
(413)
(61)
(413)
(2,052)
Translation Adjustment
702
212
79
(2)
991
Fair value of plan assets at the end of the year
10,201
3,007
1,176
−
14,384
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
Investment management of pension plan assets
Petros Foundation prepares annually Investment Policies (PI) specific to each plan, following two models:
(i) for Petros 2, the achievement of the actuarial goal with the lowest value at risk; and
(ii) for defined benefit plans, the minimal mismatch in net cash flows, conditioned to the achievement of the actuarial
target.
Pension plans assets follow a long-term investment strategy based on the risks assessed for each different class of
assets and provide for diversification, in order to lower portfolio risk. The portfolio profile must comply with the
Brazilian National Monetary Council (Conselho Monetário Nacional – CMN) regulations.
Petros Foundation establishes investment policies for 5-year periods, reviewed annually, using an asset liability
management model (ALM) to address net cash flow mismatches of the benefit plans, based on liquidity and solvency
parameters.
Pension plan assets by type of asset are set out as follows:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-56
2024
2023
Type of asset
Quoted
prices in
active
markets
Unquoted
prices
Total fair
value
%
Total fair
value
%
Receivables
−
954
954
9%
1,466
10%
Fixed income
1,780
6,150
7,930
78%
10,910
75%
Government bonds
5
6,148
6,153
−
9,450
−
Fixed income funds
1,162
−
1,162
−
786
−
Other investments
613
2
615
−
674
−
Variable income
324
155
479
3%
945
5%
Common and preferred shares
324
−
324
−
735
−
Other investments
−
155
155
−
210
−
Structured investments
151
22
173
4%
216
4%
Real estate properties
−
418
418
4%
541
4%
2,255
7,699
9,954
98%
14,078
98%
Loans to participants
−
245
245
2%
306
2%
Fair value of plan assets at the end of the year
2,255
7,944
10,199
100%
14,384
100%
There is no plan asset for the health care plan. Loans to participants of pension plans are measured at amortized cost,
which is considered an appropriate estimate of fair value.
As of December 31, 2024, the investment portfolio included Company’s common shares in the amount of US$ 1
(US$ 1 in 2023) and real estate properties leased by the Company in the amount of US$ 21 (US$ 26 in 2023).
d) Net expenses relating to benefit plans
Pension Plans
Health Care
Plan
Total
PPSP-R (1) PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Related to active employees (cost of sales and expenses)
(34)
(10)
(2)
(692)
(738)
Related to retirees (other income and expenses)
(365)
(143)
(11)
(1,677)
(2,196)
Net expenses for 2024
(399)
(153)
(13)
(2,369)
(2,934)
Net expenses for 2023
(490)
(169)
(30)
(853)
(1,542)
Net expenses for 2022
(457)
(129)
(33)
(609)
(1,228)
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
18.3.3. Contributions
In 2024, the Company contributed US$ 1,001 to the defined benefit plans (US$ 927 in 2023), reducing the balance of
obligations of these plans, as presented in note 18.3.2. In addition, the Company contributed with US$ 239 and US$ 2,
respectively, to the defined contribution portions of PP-2 and PP-3 plans (US$ 232 for PP-2 and US$ 2 for PP-3 in 2023),
which were recognized in the statement of income.
For 2025, the expected contributions for the PPSP-R, PPSP-NR, PPSP-R pre-70, PPSP-NR pre-70 and for the defined
benefit portion of PP-2, amounts to US$ 432, while for the defined contribution portion of PP-2 amounts to US$ 232.
18.3.4. Expected future cash flows
The estimate below reflects only the expected future cash flows to meet the defined benefit obligation recognized at
the end of the reporting period.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-57
2024
2023
Pension Plan
Health Care
Plan
Total
Total
PPSP-R (1) PPSP-NR (1)
Petros 2
Saúde
Petrobras-AMS
Up to 1 Year
911
313
71
381
1,676
1,084
1 to 5 Years
3,820
1,221
286
1,909
7,236
8,955
6 to 10 Years
2,511
769
192
1,713
5,185
6,970
11 To 15 Years
1,593
458
126
1,293
3,470
5,112
Over 15 Years
1,157
472
199
2,202
4,030
8,645
Total
9,992
3,233
874
7,498
21,597
30,766
(1) It includes the balance of PPSP-R pre-70 and PPSP-NR pre-70.
18.3.5. Future payments to participants of defined benefit plans that are closed to new members
The following table provides the period during which the defined benefit obligation associated with these plans are
expected to continue to affect the Company's financial statements.
PPSP-R
PPSP-R
Pré-70
PPSP-NR
PPSP-NR
Pré-70
Number of years during which benefits must be paid to participants of defined benefit
plans
9.71
6.52
9.51
6.45
18.3.6. Measurement uncertainties associated with the defined benefit obligation
The significant financial and demographic actuarial assumptions used to determine the defined benefit obligation are
presented in the following table:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-58
2024
Pension Plans
Health Care Plan
Assumptions
PPSP-R
PPSP-NR
PPSP-R
Pré-70
PPSP-NR
Pré-70
PP2
Saúde
Petrobras-AMS
Nominal discount rate
(including inflation) (1)
12.95%
12.95%
13.07%
13.07%
12.95%
12.93%
Real discount rate
7.48%
7.48%
7.59%
7.59%
7.48%
7.46%
Nominal expected salary
growth (including inflation)
(2)
6.16%
6.15%
n/a
6.15%
8.72%
n/a
Expected changes in medical
and hospital costs (3)
n/a
n/a
n/a
n/a
n/a
13.69% a 3.25%
p.a.
Mortality table
Petros
Experience 2016
Petros
Experiences 2025
Petros
Experiences 2020
Petros
Experiences 2023
AT-2012 IAM
basic fem 10%
smoothed
Employees:
according to
pension plan
Assisted: Petros
2016
Disability table
American group
American group
n/a
n/a
Disability
Experience PP-2
2022
Disability
Experience PP-2
2022
Mortality table for disabled
participants
AT-49 male
AT-83 Basic by
gender
MI 2006, by
gender, 20%
smoothed
Petros
Experience 2014
MI-85, male, 10%
smoothed
AT-49 male
Age of retirement
Male, 56,36 years
Female, 55,42
years
Male, 57,71 years
Female, 55,88
years
Male, 56,36 years
Female, 55,42
years
Male, 57,71 years
Female, 55,88
years
1st eligibility
according to
RGPS Male, 65
years / Female,
60 years
Male, 56,86 years
Female, 55,75
years
(1) Inflation reflects market projections: 5.09% for 2025 and converging to 3.25% in 2029 onwards.
(2) Expected salary growth only of Petrobras, the sponsor, based on the Salaries and Benefits Plan.
(3) Decreasing rate, converging in 30 years to the long-term expected inflation. Refers only to Petrobras (sponsor) rate.
2023
Pension Plans
Health Care Plan
Assumptions
PPSP-R
PPSP-NR
PPSP-R Pre-70
PPSP-NR Pre-70
PP2
Saúde
Petrobras-AMS
Nominal discount rate
(including inflation) (1)
9.53%
9.52%
9.46%
9.46%
9.56%
9.56%
Real discount rate
5.42%
5.41%
5.35%
5.35%
5.45%
5.45%
Nominal expected salary
growth (including inflation)
(2)
4.89%
4.63%
4.89%
4.63%
7.07%
n/a
Expected changes in medical
and hospital costs (3)
n/a
n/a
n/a
n/a
n/a
13.11% a 3.75%
p.a.
Mortality table
Petros
Experience 2016
Petros
Experiences 2025
Petros
Experiences 2020
Petros
Experiences 2023
AT-2012 IAM
basic fem 10%
smoothed
Employees:
according to
pension plan
Assisted: PPSP-
R: Ex Petros 2016
Disability table
American group
American group
n/a
n/a
Disability
Experience PP-2
2022
Assets: PP-2:
Disability
Experience PP-2
Mortality table for disabled
participants
AT-49 male
AT-83 Basic by
gender
MI 2006, by
gender, 20%
smoothed
Petros
Experience 2014
IAPB-57 strong,
30% smoothed
PPSP-R: AT-49
male
Age of retirement
Male, 56 years /
Female, 55 years
Male, 58 years /
Female, 56 years
Male, 56 years /
Female, 55 years
Male, 58 years /
Female, 56 years
1st eligibility
according to
RGPS Male, 65
Male, 56 years /
Female, 55 years
(1) Inflation reflects market projections: 3.90% for 2024 and converging to 3.75% in 2031 onwards.
(2) Expected salary growth only of Petrobras, the sponsor, based on the Salaries and Benefits Plan.
(3) Decreasing rate, converging in 30 years to the long-term expected inflation. Refers only to Petrobras (sponsor) rate.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-59
The most significant assumptions are described in Note 4.4.
18.3.7. Sensitivity analysis of the defined benefit plans
The effect of a 100 basis points (bps) change in the discount rate and in the estimated future medical and hospital costs
is set out below:
Discount Rate
Expected changes in
medical and hospital
costs
Pension Benefits
Medical Benefits
Medical Benefits
+100 bps
-100 bps
+100 bps
-100 bps
+100 bps
-100 bps
Pension Obligation
(1,045)
1,169
(722)
868
911
(762)
Current Service cost and interest cost
(12)
6
(51)
61
150
(63)
Accounting policy for post-employment defined benefits
The obligations related to post-employment defined benefit plans and health-care plans are recognized as liabilities in
the statement of financial position based on actuarial calculations which are revised annually by an independent
qualified actuary (updating for material changes in actuarial assumptions and estimates of expected future benefits),
using the projected credit unit method, net of the fair value of plan assets, when applicable, from which the obligations
are to be directly settled.
Under the projected credit unit method, each period of service gives rise to an additional unit of benefit entitlement
and each unit is measured separately to determine the final obligation. Actuarial assumptions include demographic and
financial assumptions, medical costs estimate, historical data related to benefits paid and employee contributions, as
set out in note 4.
Service cost are accounted for within the statement of income and comprises: (i) current service cost, which is the
increase in the present value of the defined benefit obligation resulting from employee service in the current period; (ii)
past service cost, which is the change in the present value of the defined benefit obligation for employee service in prior
periods, resulting from a plan amendment (the introduction, modification, or withdrawal of a defined benefit plan) or a
curtailment (a significant reduction by the entity in the number of employees covered by a plan); and (iii) any gain or
loss on settlement.
Net interest on the net defined benefit liability is the change during the period in the net defined benefit liability that
arises from the passage of time. Such interest is accounted for in the statement of income.
Remeasurement of the net defined benefit liability is recognized in shareholders’ equity, in other comprehensive
income, and comprises: (i) actuarial gains and losses and; (ii) return on plan assets, excluding net interest on the net
defined liability, net of defined benefit plan assets.
The Company also contributes to defined contribution plans, on a parity basis in relation to the employee's contribution,
that are expensed when incurred.
19. Provisions for legal proceedings, judicial deposits and contingent liabilities
19.1. Provisions for legal proceedings
The Company recognizes provisions for legal, administrative and arbitral proceedings, based on the best estimate of
the costs, for which it is probable that an outflow of resources embodying economic benefits will be required and that
can be reliably estimated. These proceedings mainly include:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-60
•
Labor claims, in particular: (i) several individual and collective labor claims; (ii) opt-out claims related to a review of
the methodology by which the minimum compensation based on an employee's position and work schedule
(Remuneração Mínima por Nível e Regime - RMNR) is calculated; and (iii) actions of outsourced employees.
•
Tax claims including: (i) tax notices for alleged non-compliance with ancillary obligations; (ii) claims relating to
benefits previously taken for Brazilian federal tax credits applied that were subsequently alleged to be
disallowable, including disallowance of PIS and COFINS tax credits; and (iii) claims for alleged non-payment of
social security contributions on allowances and bonuses.
•
Civil claims, in particular: (i) lawsuits related to contracts; (ii) lawsuits that discuss matters related to pension plans
managed by Petros; and (iii) legal and administrative proceedings involving fines applied by the ANP - Brazilian
Agency of Petroleum, Natural Gas and Biofuels (Agência Nacional de Petróleo, Gás Natural e Biocombustíveis),
mainly relating to production measurement systems.
•
Environmental claims, specially: (i) fines relating to an environmental accident in the State of Paraná in 2000;
(ii) fines relating to the Company’s offshore operation; and (iii) public civil action for oil spill in 2004 in Serra do
Mar-São Paulo State Park.
Provisions for legal proceedings are set out as follows:
Non-current liabilities
12.31.2024
12.31.2023
Labor claims
636
806
Tax claims
400
544
Civil claims
1,605
1,614
Environmental claims
192
341
Total
2,833
3,305
2024
2023
Opening Balance
3,305
3,010
Additions, net of reversals
478
389
Use of provision
(730)
(709)
Revaluation of existing proceedings and interest charges
541
376
Others
16
(5)
Translation adjustment
(777)
244
Closing Balance
2,833
3,305
In preparing its consolidated financial statements of 2024, the Company considered all available information
concerning legal proceedings in which the Company is a defendant, in order to estimate the amounts of obligations and
probability that outflows of resources will be required.
19.2. Judicial deposits
The Company makes deposits in judicial phases, mainly to suspend the chargeability of the tax debt and to maintain its
tax compliance. Judicial deposits are set out in the table below according to the nature of the corresponding lawsuits:
Non-current assets
12.31.2024
12.31.2023
Tax
8,187
10,607
Labor
777
979
Civil
2,694
2,977
Environmental and others
90
183
Total
11,748
14,746
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-61
2024
2023
Opening Balance
14,746
11,053
Additions
1,010
1,735
Use (1)
(1,526)
(148)
Accruals and charges
737
1,167
Others
9
(7)
Translation adjustment
(3,228)
946
Closing Balance
11,748
14,746
(1) It includes, in 2024, US$ 1.276 referring to the nominal values of deposits used when enrolling to the tax settlement program, in the second quarter of 2024, on the
incidence of CIDE, PIS and Cofins on remittances abroad under a vessel and platform charter agreement as detailed in note 17.
The Company maintains a Negotiated Legal Proceeding (NJP) agreement with the Brazilian National Treasury Attorney
General's Office (PGFN), aiming to postpone judicial deposits related to federal tax lawsuits with values exceeding
US$ 32 (R$ 200 million), which allows judicial discussion without the immediate disbursement.
To achieve this, the Company makes production capacity available as a guarantee from the Tupi, Sapinhoá, and
Roncador fields. As the judicial deposits are made, the mentioned capacity is released for other processes that may be
included in the NJP.
The Company’s management understands that the mentioned NJP provides greater cash predictability and ensures the
maintenance of federal tax regularity. As of December 31, 2024, the balance of production capacity held in guarantee
in the NJP is US$ 2,158 (US$ 7,997 as of December 31, 2023), whose reduction is due to the Company's enrollment to
the tax settlement program in June 2024.
19.3. Contingent liabilities
Contingent liabilities for which either the Company is unable to make a reliable estimate of the expected financial effect
that might result from resolution of the proceeding, or a cash outflow is not probable, are not recognized as liabilities
in the financial statements but are disclosed in the notes to the financial statements, unless the likelihood of any
outflow of resources embodying economic benefits is considered remote.
The estimates of contingent liabilities are indexed to inflation and updated by applicable interest rates. As of December
31, 2024, estimated contingent liabilities for which the possibility of loss is classified as possible are set out in the
following table:
Nature
12.31.2024
12.31.2023
Tax
21,307
37,189
Labor
6,465
10,150
Civil
10,910
11,455
Environmental and others
1,298
1,427
Total
39,980
60,221
19.3.1. Information on contingent liabilities
The tables below detail the main causes of tax, civil, environmental and labor nature, whose expectations of losses are
classified as possible:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-62
Estimate
Description of tax matters
12.31.2024 12.31.2023
Plaintiff: Federal Revenue of Brazil
1) Income from foreign subsidiaries located outside Brazil not included in the computation of taxable income (IRPJ and
CSLL).
Current status: This claim involves lawsuits in different administrative and judicial stages, remaining a possible loss due
to there being manifestations in favor of the Company's understanding in the Superior Courts. In 2024, there was a
reduction in the ex officio fine and the addition of active debt registration in one of the processes.
3,418
4,260
2) Disallowance of credits and deduction of the PIS and COFINS tax base, including in ship or pay contracts and charters of
aircraft and vessels.
Current status: The claims involve lawsuits in different administrative and judicial stages. In 2024, the increase refers, in
particular, to the adjustment of the subject “PIS/COFINS – Disallowance of credits” and the receipt of a new infraction
notice.
2,887
1,370
3) Withholding income tax (IRRF), Contribution of Intervention in the Economic Domain (CIDE) and Social Integration
Program (PIS) - Imports on remittances for payments of vessel charters.
Current status: The claim about the incidence of withholding income tax (Imposto de Renda Retido na Fonte- IRRF),
occurred from 1999 to 2002, involves the legality of the normative rule issued by the Federal Revenue of Brazil, which
ensured no taxation over those remittances. The reduction in the value in 2024 occurred due to the payment of the
processes that dealt with CIDE and PIS/COFINS Import, after adhesion to the tax transaction notice PGFN-RFB 6/2024,
detailed in Note 17.3 (Enrollment to the Tax Settlement Program). The remaining value of the matter refers to the
incidence of IRRF, which is a discussion still ongoing in a process.
1,702
11,409
4) Collection of IRPJ and CSLL - Transfer price - Charter contracts
Current status: The processes are in the administrative level. There are two decisions, one favorable and the other
unfavorable to Petrobras in the first instance. The appeals from the Company and the Brazilian Federal Government are
awaited. In 2024, the Company received a new infraction notice, referring to the 2019 calendar year. The increase in value
was offset by a favorable decision to Petrobras, in the process referring to the 2017 calendar year, handed down by the
Conselho Administrativo de Recursos Fiscais - CARF, which became definitive.
1,207
1,418
5) Collection of PIS/COFINS – Incidences on Amnesties.
Current status: Collection of social contributions PIS/COFINS, resulting from the tax transaction provided for in article 3
of Law 13,586/2017. The Embargoes on Execution are in the stage of producing expert evidence. In 2024, the increase
refers, in particular, to monetary indexation and receipt of a new infraction notice.
1,129
1,263
6) Incidence of social security contributions over contingent bonuses paid to employees.
Current status: Awaiting defense judgment and appeals at the administrative and judicial levels. In 2024, the increase
occurred, in particular, due to the receipt of new infraction notices and active debt registration in one of the processes.
1,090
1,064
7) Income taxes (IRPJ and CSLL) - Capital gains and Amortization of goodwill on the acquisition of equity interests.
Current status: This claim involves lawsuits in different administrative stages. In March 2025, in one of the processes, CARF
ruled in favor of Petrobras in a claim related to the capital gain from the disposal of an equity interest.
313
578
8) Collection of Contribution of Intervention in the Economic Domain (CIDE) on transactions with fuel retailers and service
stations protected by judicial injunctions determining that fuel sales were made without gross-up of such tax.
Current status: This claim involves lawsuits in different judicial stages.
436
544
9) Requests to compensate federal taxes disallowed by the Brazilian Federal Tax Authority
Current status: This claim involves lawsuits in different administrative and judicial stages. The reduction in value, in 2024,
occurred, in particular, due to the transfer of amounts to the subject “Disallowance of credits and deduction from the PIS
and COFINS calculation base”.
389
1,816
10) Deduction of the IRPJ and CSLL tax base of the amounts paid as an incentive to the Petros Plan renegotiation and past
service.
Current status: This claim involves lawsuits in different judicial stages. In 2024, due to judicial decision, the loss expectation
was partially reclassified.
288
723
11) Import tax, PIS/COFINS and customs fines - Import of vessels through Repetro's Special Customs Regime.
Current status: This claim involves lawsuits in different administrative and judicial stages. In 2024, the reduction refers to
the reclassification of the expected loss in some processes.
235
403
12) Customs – Fines of 1% and 5% on the Customs Value.
Fines applied to the customs value of imported products due to inaccurated information in import declarations.
Current status: This claim involves lawsuits in different administrative and judicial stages.
225
273
13) Additional Social Security Contribution - Harmful Agents
Current status: This claim involves lawsuits in different administrative and judicial stages. In 2024, the increase occurred,
in particular, due to the reclassification of a matter in a process.
166
168
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-63
14) Collection of Import Tax, PIS/COFINS and customs fines, including Petrobras as jointly liable.
Current situation: Awaiting judgment of the Brazilian Federal Government appeal, at CARF, because of a lower court
administrative decision favorable to the Company. In 2024, the expected loss of the claim was reclassified.
−
2,872
Plaintiff: States of SP, RJ, BA, PA, AL, MA, PB, PE, AM and SE Finance Departments
15) VAT (ICMS) and VAT credits on internal consumption of bunker fuel and marine diesel, destined to chartered vessels.
Current status: This claim involves lawsuits in different administrative and judicial stages.
428
514
Plaintiff: States of RJ and BA Finance Departments
16) VAT (ICMS) on dispatch of liquid natural gas (LNG) and C5+ (tax document not accepted by the tax authority), as well
as challenges on the rights to this VAT tax credit.
Current status: This claim involves lawsuits in different administrative and judicial stages. In 2024, a judicial decision
generated the reclassification of the expectation of loss to remote in a claim.
97
960
Plaintiff: States of PE and RJ Finance Departments
17) VAT Tax (ICMS) on imports required by Brazilian States.
Current status: This claim involves lawsuits in different administrative and judicial stages.
298
355
Plaintiff: States of RJ, AM, PA, BA, MA, SP, RO, PE and RS Finance Departments
18) Alleged failure to write-down VAT (ICMS) credits related to zero tax rated or non-taxable sales made by the Company
and its customers.
Current status: This claim involves lawsuits in different administrative and judicial stages. In 2024, the increase refers, in
particular, to the receipt of a new infraction notice, offset by a reduction related to adherence to the amnesty program in
the state of Pernambuco.
1,058
1,257
Plaintiff: States of RJ, BA, PE and MT Finance Departments
19) The plaintiff alleges that the transfers between branches, especially in RJ, without segregating VAT (ICMS), under the
special regime, reduced the total credits of the central department.
Current status: This claim involves lawsuits in different administrative and judicial stages.
870
1,027
Plaintiff: States of RJ, BA, PB, SE, SP, ES, CE and PE Finance Departments
20) Appropriation of ICMS credit on the acquisition of goods (products in general) that, in the understanding of the
inspection, would fit into the concept of material for use and consumption, being the tax credit undue.
Current status: This claim involves lawsuits in different administrative and judicial stages.
314
374
Plaintiff: States of RJ, PR, AM, BA, PA, PE, SP, PB and AL Finance Departments
21) Incidence of VAT (ICMS) over alleged differences in the control of physical and fiscal inventories.
Current status: This claim involves lawsuits in different administrative and judicial stages.
747
913
Plaintiff: State of SP Finance Department
22) Deferral of payment of VAT (ICMS) taxes on B100 Biodiesel sales and the charge of a 7% VAT rate on B100 on Biodiesel
interstate sales, including states in the Midwest, North and Northeast regions of Brazil and the State of Espírito Santo.
Current status: This claim involves lawsuits in different administrative and judicial stages.
244
299
Plaintiff: States of RJ, SP, BA, PE, PR and CE Finance Departments
23) Misappropriation of VAT tax credit (ICMS) on the acquisitions of goods that, per the tax authorities, are not related to
property, plant and equipment.
Current status: This claim involves lawsuits in different administrative and judicial stages. In 2024, the increase refers, in
particular, to the reclassification of expected loss in a process.
515
576
Plaintiff: States of RJ, PE, ES and GO Finance Departments
24) Appropriation of ICMS credit - Monophase applicable to the acquisition of goods
Current status: The new infraction notices, received in 2024, are in the administrative phase, awaiting judgment at first
instance.
634
−
Plaintiff: States of RJ, PE, CE and PB Finance Departments
25) Collection of ICMS related to State Funds.
Current status: This claim involves lawsuits in different judicial stages. In 2024, the increase occurred due to the filing of
annulment actions by the Company due to the receipt of several release notes, especially in the state of Rio de Janeiro.
544
197
Plaintiff: States of AC, PA, AM, MA, BA, PB, PE, SE, TO, GO, MT, RJ, SP, SC and PR Finance Departments
26) VAT Tax (ICMS) under substitution regime required by states.
Current status: There are lawsuits in different administrative and judicial stages.
188
223
Plaintiff: Municipal government of Angra dos Reis/RJ
27) Added value of ICMS on oil import operations.
Current status: There are lawsuits in different judicial stages.
264
311
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-64
Plaintiff: Several Municipalities
28) Alleged failure to withhold and pay tax on services.
Current status: There are lawsuits in different administrative and judicial stages.
201
254
29) Other tax matters
1,420
1,768
Total for tax matters
21,307
37,189
Estimate
Description of labor matters
12.31.2024 12.31.2023
Plaintiff: Employees and Sindipetro Unions.
1) Actions requiring a review of the methodology by which the minimum compensation based on an employee's position
and work schedule (Remuneração Mínima por Nível e Regime - RMNR) is calculated.
Current status: The Federal Supreme Court (STF), accepting the Company's appeal, recognized in March 2024 that the
calculation formula used by the Company is valid and in accordance with what was negotiated between the parties,
reversing the decision of the Superior Labor Court (TST) which had established different criteria and reached an
understanding partially contrary to the Company. As there were several legal actions at different procedural stages, the
Company monitors the progress of the respective processes and makes the necessary adjustments to the values and
expectations of this litigation in accordance with the decisions that apply the Superior Labor Court precedent. In 2024, the
reduction refers, in particular, to write-offs and transfers for remote loss resulting from favorable decisions to Petrobras
that applied the Superior Labor Court precedent.
4,934
8,362
2) Other labor matters
1,531
1,788
Total for labor matters
6,465
10,150
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-65
Estimate
Description of civil matters
12.31.2024 12.31.2023
Plaintiff: Several goods and service providers
1) Claims related to goods and services supply contracts, with emphasis on discussions about economic and financial
imbalance, contractual breach, fines and early termination of contracts.
Current status: The claims involve lawsuits in different judicial stages. In 2024, there was an increase in value due to new
lawsuits and unfavorable decisions to Petrobras.
3,319
3,547
Plaintiff: Agência Nacional de Petróleo, Gás Natural e Biocombustíveis - ANP
2) Proceedings challenging an ANP order requiring Petrobras to: unite Tupi and Cernambi fields on the BM-S-11 joint
venture; to unite Baúna and Piracicaba fields; and to unite Tartaruga Verde and Mestiça fields, which would cause changes
in the payment of special participation charge.
Current status: This list involves claims that are disputed in court and in arbitration proceedings, as follows. In 2024, there
was an increase in the value, due to the judicial deposits that are made by Petrobras:
a) Tupi and Cernanbi: initially, the Company made judicial deposits for the alleged differences resulting from the special
participation. However, with the reversal of the favorable injunction, the payment of these alleged differences were made
directly to ANP, and such judicial deposits were resumed in the 2nd Quarter of 2019. The suspension of the arbitration was
reversed by the BM-S-11 Consortium at the Brazilian Superior Court, so that the arbitration resumed its progress.
b) Baúna and Piracicaba: the decision maintaining the suspension of arbitration was revoked, and the arbitration procedure
is ongoing.
c) Tartaruga Verde and Mestiça: Petrobras was also authorized to make deposits of the disputed amounts, which continue
to occur. The Federal Regional Court of the 2nd Region has so far ruled on the jurisdiction of the Arbitral Court, authorizing
the continuation of the arbitration.
d) Berbigão and Sururu: ANP made a decision on January 24, 2025, determining the unification of the Berbigão and Sururu
fields, located in the BM-S-11A concession, in the pre-salt layer of Santos Basin, operated by Petrobras with a 42.5%
interest. The decision results in the reporting of production from the Berbigão and Sururu fields in a single field, increasing
the rate applied to the corresponding collection of Special Participation related to the unified field, retroactively to the
date of commencement of production. In the same decision, it was determined that ANP's Superintendence of Government
Participations should determine the value of Government Participations considering the unified fields. The company has
not yet received the release note with the charge from ANP.
2,686
2,245
Plaintiff: Federations Oil Workers, Unions, employees and retired personnel from Petros
3) Collective and individual actions that discuss topics related to Petros plans.
Current status: The matter involves proceedings at different judicial stages. In 2024, the increase refers, in particular, to
monetary and interest indexation.
1,946
2,225
Plaintiff: Agência Nacional de Petróleo, Gás Natural e Biocombustíveis - ANP and other agencies
4) Administrative and legal proceedings that discuss:
a) Difference in special participation and royalties in different fields;
b) Fines imposed by ANP due to alleged failure to comply with the minimum exploration activities program, as well as
alleged irregularities relating to compliance with oil and gas industry regulation. It also includes fines imposed by other
agencies.
Current status: The claims involve lawsuits in different administrative and judicial stages.
1,863
2,214
Plaintiff: Legal entities that participated in the purchase and sale of Petrobras assets
5) Judicial and arbitration proceedings that discuss asset sales carried out by Petrobras.
Current status: The matter involves proceedings in different judicial and arbitration stages. In 2024, there was an increase
in value due to the receipt of new processes.
264
240
6) Several civil proceedings, with emphasis on those related to expropriation and easement of passage and civil
liability.
832
984
Total for civil matters
10,910
11,455
Estimate
Description of environmental matters
12.31.2024 12.31.2023
Plaintiff: Several authors, notably: Ministério Público Federal, Ministérios Públicos Estaduais and public environmental
bodies, such as IBAMA - Instituto Brasileiro de Meio Ambiente e Recursos Naturais Renováveis, state and municipal
public bodies.
1) Several lawsuits of an environmental nature, with emphasis on action for alleged damage to fishermen due to the
Company's operations, fines related to the Company's operations and public civil action for alleged environmental damage
due to the sinking of Platform P-36. In 2024, the increase occurred mainly due to the partial reclassification of the expected
loss in an action.
1,298
1,427
Total for environmental matters
1,298
1,427
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-66
19.3.2. Minimum Compensation Based on Employee's Position and Work Schedule (Remuneração Mínima
por Nível e Regime - RMNR)
The RMNR consists of a minimum remuneration guaranteed to employees, based on salary level, work schedule and
geographic location. This remuneration policy was created and implemented by Petrobras in 2007 through collective
negotiation with union representatives, and approved at employee meetings, with the formula for calculating the
supplement to this minimum remuneration adopted by the Company later being questioned in court by employees and
Unions. The Superior Labor Court (TST) established criteria different from those agreed and reached an understanding
partially contrary to the Company, deciding to exclude some portions of the calculation. The Federal Supreme Court
(STF), which accepted the Company's appeal, recognized in March 2024 that the calculation formula used by the
Company is valid and in accordance with what was negotiated between the parties.
The Company has been adjusting the expectation of loss, according to the decisions in which the understanding of the
STF applies. As there are several legal actions at different procedural stages, the Company monitors the application of
the precedent to the respective processes, which are being terminated, according to their progress in the Court.
As of December 31, 2024, the balance of provisions for legal proceedings regarding RMNR amounts to US$ 88, while the
contingent liabilities amount to US$ 4,934.
19.4. Class action and related proceedings
19.4.1. Class action in the Netherlands
On January 23, 2017, Stichting Petrobras Compensation Foundation ("Foundation") filed a class action in the
Netherlands, at the District Court of Rotterdam, against Petróleo Brasileiro S.A. – Petrobras, Petrobras International
Braspetro B.V. (PIB BV), Petrobras Global Finance B.V. (PGF), Petrobras Oil & Gas B.V. (PO&G) and some former Petrobras
managers. The Foundation alleges that it represents the interests of an unidentified group of investors and asserts
that, based on the facts revealed by the Lava-Jato Operation, the defendants acted illegally before the investors. On
May 26, 2021, the District Court of Rotterdam decided that the class action should proceed and that the arbitration
clause of Petrobras' bylaws does not prevent the Company's shareholders from having access to the Dutch Judiciary
and have their interests represented by the “Foundation”. However, the interests of investors who have already started
arbitration against Petrobras or who are parties to legal proceedings in which the applicability of the arbitration clause
has been definitively recognized are excluded from the scope of the action.
On July 26, 2023, the Court issued an intermediary decision on the merits which provided the following understanding:
(i) the requests made against PIB BV, PO&G and certain former members of the Company’s management were rejected;
(ii) the Court declared that Petrobras and the PGF acted illegally in relation to their investors, although the Court
expressed it does not consider itself sufficiently informed about relevant aspects of Brazilian, Argentine and
Luxembourger laws to definitively decide on the merits of the action; and iii) the alleged rights under Spanish legislation
are prescribed.
Regarding the aspects of Brazilian, Argentine and Luxembourger laws considered relevant to the sentence, the Court
ordered the production of technical evidence by Brazilian and Argentine experts and by Luxembourger authorities.
On October 30, 2024, after the parties' comments on the technical evidence, the Court issued a ruling, in which it broadly
accepted Petrobras' arguments regarding the requests presented in favor of the Company's shareholders and
considered that: i) in accordance with Brazilian legislation, all damages alleged by the Foundation qualify as indirect and
are not subject to compensation; and ii) according to Argentine law, shareholders cannot, in principle, request
compensation from the Company for damages alleged by the Foundation, and the Foundation has not demonstrated
that it represents a sufficient number of investors who could, in theory, present such a request.
Therefore, the Court rejected the Foundation's allegations in accordance with Brazilian and Argentine law, which
resulted in the rejection of all requests made in favor of shareholders. With respect to certain bondholders, the Court
considered that Petrobras and PGF acted illegally under Luxembourg law, while PGF acted illegally under Dutch law.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-67
Furthermore, the Court confirmed the following issues of the decision released to the market on July 26, 2023:
(i) rejection of the allegations against PIBBV, POG BV and the former CEOs of Petrobras, Maria das Graças Silva Foster
and José Sérgio Gabrielli de Azevedo; and (ii) prescription of requests formulated in accordance with Spanish legislation.
The Foundation and PGF have appealed the ruling and previous interim decisions and will have the opportunity to
substantiate their own appeals and respond to each other's appeals, before judgment by the Court of Appeal in The
Hague. Petrobras will still be able to present its own appeal, within the deadline for responding to the Foundation's
appeal.
In relation to bondholders, the Foundation cannot claim compensation under the class action, which will depend not
only on a final result favorable to the interests of the investors in the class action, but also on the filing of subsequent
actions by or on behalf of the investors by the Foundation itself, an opportunity in which Petrobras will be able to offer
all the defenses already presented in the class action and others that it deems appropriate, including in relation to the
occurrence and quantification of any damages that must be proven by the potential beneficiaries of the decision or by
the Foundation. Any compensation for the alleged damages will only be determined by court decisions in subsequent
actions.
This class action involves complex issues and the outcome is subject to substantial uncertainties, which depend on
factors such as: the scope of the arbitration clause of the Petrobras Bylaws, the jurisdiction of the Dutch courts, the
scope of the agreement that ended the Class Action in the United States, the Foundation's legitimacy to represent the
interests of investors, the several laws applicable to the case, the information obtained from the production phase of
evidence, the expert analyses, the timetable to be defined by the Court and the judicial decisions on key issues of the
process, possible appeals, including before the Dutch Supreme Court, as well as the fact that the Foundation seeks only
a declaratory decision in this class action.
The Company, based on the assessments of its advisors, considers that there are not enough indicative elements to
qualify the universe of potential beneficiaries of a possible final decision unfavorable to Petrobras' interests, nor to
quantify the supposedly compensable damages.
Thus, it is currently not possible to predict whether the Company will be liable for the effective payment of damages in
any future individual claims, as this analysis will depend on the outcome of these complex procedures. In addition, it is
not possible to know which investors will be able to bring subsequent individual actions related to this matter against
Petrobras.
Furthermore, the claims formulated are broad, cover a multi-year period and involve a wide variety of activities and, in
the current scenario, the impacts of such claims are highly uncertain. The uncertainties inherent in all of these issues
affect the value and duration of final resolution of this action. As a result, Petrobras is unable to estimate an eventual
loss resulting from this action. However, Petrobras continues to reject the Foundation's allegations, in relation to which
it was considered a victim by all Brazilian authorities, including the Brazilian Supreme Federal Court.
Petrobras and its subsidiaries reject the allegations made by the Foundation and will continue to defend themselves
vigorously.
19.4.2. Arbitration and other legal proceedings in Argentina
In relation to the arbitration in Argentina, the Argentine Supreme Court denied the appeal, but the Consumidores
Damnificados Asociación Civil para su Defensa (formerly Consumidores Financieros Asociación Civil, "Association") filed
a new appeal to the Argentine Supreme Court, which was also denied, thus the arbitration was sent to the Arbitration
Court. This arbitration discusses Petrobras' liability for an alleged loss of market value of Petrobras' shares in Argentina,
as a result of the so-called Lava Jato Operation. The Company does not have elements that allow it to provide a reliable
estimate of the potential loss in this arbitration.
In parallel to such arbitration, the Association also initiated a collective action before the Civil and Commercial Court of
Buenos Aires, in Argentina, with Petrobras appearing spontaneously on April 10, 2023, within the scope of which it
alleges Petrobras' responsibility for an alleged loss of the market value of Petrobras' securities in Argentina, as a result
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-68
of allegations made within the scope of Lava Jato Operation and their impact on the Company's financial statements
prior to 2015. Petrobras presented its defense on August 30, 2023. Petrobras denies the allegations presented by the
Association and will defend itself against the accusations made by the author of the class action. The Company does
not have elements that allow it to provide a reliable estimate of the potential loss in this arbitration.
Regarding criminal proceeding in Argentina related to an alleged fraudulent offer of securities, aggravated by the fact
that Petrobras allegedly declared false data in its financial statements prior to 2015, the Court of Appeals revoked, on
October 21, 2021, the lower court decision that had recognized Petrobras' immunity from jurisdiction and recommended
that the lower court judge take steps to certify whether the Company could be considered criminally immune in
Argentina for further reassessment of the issue. After carrying out the steps determined by the Court of Appeals, on
May 30, 2023, the lower court denied the recognition of immunity from jurisdiction to Petrobras. Petrobras filed an
appeal against this decision, which was recognized by the Court of Appeals on April 18, 2024. Against this decision, the
Association filed a new appeal, and on December 20, 2024, the Court of Cassation reformed the decision of the Court of
Appeals to deny Petrobras' immunity from jurisdiction, which, in turn, appealed to the Supreme Court to reinstate the
Court of Appeals decision. On December 27, 2024, before the decision of the Court of Cassation became final, the court
of first instance ordered to sue Petrobras and a precautionary injunction, which was appealed to the Court of Appeals.
The Court of Appeals had already recognized that the Association could not act as a representative of financial
consumers, due to the loss of its registration with the competent Argentine bodies, which was also the subject of an
appeal upheld by the Court of Appeals on September 15, 2022, recognizing the Association the right to represent
financial consumers. The Company's appeal against this decision was rejected on February 21, 2025. Petrobras
presented other procedural defenses, which may be re-discussed in later stages of the process. This criminal action is
being processed before the Economic Criminal Court No. 2 of the city of Buenos Aires.
As for the other criminal action for alleged non-compliance with the obligation to publish a “press release” in the
Argentine market about the existence of a class action filed by Consumidores Damnificados Asociación Civil para su
Defensa before the Commercial Court, there are no developments in 2024.
19.4.3. Lawsuit in United States regarding Sete Brasil Participações S.A (“Sete”)
The EIG Energy Fund XIV, L.P. and affiliates (“EIG”) filed a lawsuit against Petrobras, before the District Court of
Columbia, United States, to recover alleged losses related to its investment in Sete Brasil Participações S.A. On August
8, 2022, the judge upheld EIG's claim as to Petrobras' responsibility for the alleged losses (which was recorded in 2022
as provisions for legal proceedings) but denied the motion for summary judgment with respect to damages, whereby
the award of compensation will be subject to the proof of damages by EIG at a hearing and to the consideration of the
defenses by the Company. In the same decision, whose effects were recognized in the Company's financial statements
in 2022, the judge denied the request to dismiss the case based on Petrobras' immunity from jurisdiction, when an
appeal was filed with the Federal Court of Appeals for the District of Columbia, which was denied in June 2024. Petrobras
then submitted a request to review the issue, which was rejected on July 24, 2024. As a result, the process, which had
been suspended by the lower court judge on October 26, 2022 due to the filing of the appeal by Petrobras, resumed its
course.
On August 26, 2022, on another procedural front initiated by the EIG, the District Court of Amsterdam granted a
precautionary measure to block certain Petrobras assets in the Netherlands. This granting was based on the decision
of the District Court of Columbia, on August 8, 2022, and was intended to ensure the satisfaction of EIG's claims
contained in the aforementioned US lawsuit.
On March 7, 2025, Petrobras and EIG entered into an agreement to end the litigation between the parties. Under the
terms of the agreement, Petrobras paid EIG the amount of US$ 283, while EIG requested the termination of the lawsuit
pending in the District Court of Columbia and the cancellation of the precautionary measure blocking the Company's
assets in the Netherlands, as well as waiving any rights related to the dispute. For more information, see note 36.
This agreement does not constitute admission of guilt or wrongdoing by Petrobras and meets the best interests of the
Company and its shareholders, considering the US legislation applicable to the trial of the case, as well as the procedural
stage and characteristics of litigations in the Federal Courts of the United States.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-69
19.5. Arbitrations proposed by non-controlling shareholders in Brazil
Petrobras is also currently a party to seven arbitrations proceedings before the Market Arbitration Chamber (Câmara
de Arbitragem do Mercado - CAM), linked to the Brazilian Stock Exchange (B3), brought by investors who purchased
Petrobras’ shares traded on B3. Six of these arbitrations were initiated by national and foreign investors. The other
proceeding was brought by an association that is not a shareholder of the Company and intended to be a collective
arbitration, through representation of all non-controlling shareholders of Petrobras that acquired shares on B3
between January 22, 2010 and July 28, 2015. Investors claim alleged financial losses caused by facts related to the
investigations of the so-called Lava Jato investigation.
These claims involve complex issues that are subject to substantial uncertainties and involve factors such as the novelty
of the legal theories, the timing of the Chamber of Arbitration decisions, the information produced in discovery, besides
analysis by retained experts.
The claims asserted are broad and span a multi-year period. The uncertainties inherent in all such matters affect the
amount and timing of their ultimate resolution. As a result, the Company does not have elements that allow it to provide
a reliable estimate of the potential loss in this arbitration.
Depending on the outcome of the remaining complaints, the Company may have to pay substantial amounts, which may
have a significant effect on its consolidated financial position, financial performance and cash flows in a certain period.
However, Petrobras does not recognize responsibility for the losses alleged by investors in these arbitrations.
These arbitrations are in different stages of processing.
In relation to one of the arbitrations, proposed by two institutional investors, on May 26, 2020, a partial award was issued
which generally recognized the Company's responsibility, but not determined the payment of amounts by Petrobras.
Against these decisions, Petrobras filed a lawsuit for the annulment of the partial arbitral award on July 20, 2020, as the
Company understands that the award contains serious flaws and improprieties. On November 11, 2020, the 5th Business
Court of Rio de Janeiro annulled the partial arbitration award, recognizing the serious flaws and improprieties pointed
out by Petrobras. At the moment, the ruling is awaited after the appeals filed at the time have been judged. The appeals
against this decision are still pending judgement of a final decision. In compliance with CAM rules, the lawsuit is
confidential and only available to those involved in the original arbitration proceeding.
On September 11, 2024, in the arbitration that was intended to be collective, a final arbitration ruling was handed down,
in favor of Petrobras, extinguishing the referred arbitration, without resolution on the merits, due to the applicant's
active illegitimacy to act as a procedural substitute. The arbitration is confidential, having become final on November
29, 2024.
In turn, on January 9, 2025, in another of these arbitrations initiated by several foreign investors, a final arbitration
award was handed down in favor of Petrobras. The sentence dismissed the request, accepting one of the defense theses
presented by Petrobras, recognizing that, based on Brazilian law, there is no legal permit that authorizes investors to
bring an action for compensation against the Company for indirect damages, such as those related to the devaluation
of the value of shares. This arbitration is confidential, as are the others in progress.
Petrobras will continue to defend itself in this and other arbitrations.
Accounting policy for provisions for legal proceedings, contingent liabilities and contingent assets
The Company recognizes provisions for legal, administrative and arbitration proceedings when the technical
assessment of its legal advisors and the judgment of management consider that it is more likely than not that a present
obligation exists and the other conditions to recognize a provision are met, including that it is probable that an outflow
of resources will be required to settle the obligation.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-70
Contingent liabilities are not recognized but are disclosed in explanatory notes when the likelihood of outflows is
possible, including those whose amounts cannot be estimated, considering the best information available to the date
of the issuance of these financial statements.
The methodology used to estimate the provisions is described in note 4.5.
Contingent assets are not recognized, but are disclosed in explanatory notes when the inflow of economic benefits is
considered probable and the amount is considered material. However, if the inflow of economic benefits is virtually
certain, which, in general, considers the final and unappealable decision, and if the value can be reliably measured, the
related asset is not a contingent asset anymore and it is recognized.
20. Provision for decommissioning costs
The following table details the amount of the provision for decommissioning costs by producing area:
12.31.2024
12.31.2023
Onshore
493
447
Shallow waters
7,266
6,253
Deep and ultra-deep post-salt
12,071
10,873
Pre-salt
6,373
5,630
Total
26,203
23,203
Current
1,696
2,032
Non-current
24,507
21,171
Changes in the provision for decommissioning costs are presented as follows:
Non-current liabilities
2024
2023
Opening balance
23,203
18,600
Adjustment to provision
9,373
3,821
Transfers related to liabilities held for sale
(407)
(339)
Use of provisions
(1,464)
(1,227)
Interest accrued
970
837
Others
26
(8)
Translation adjustment
(5,498)
1,519
Closing balance
26,203
23,203
In 2024, it includes the provision established for the Cherne cluster (US$ 664) in Rio de Janeiro, the Pescada cluster
(US$ 46) in Rio Grande do Norte, and the reduction of the provision related to the Uruguá cluster, Uruguá and Tambaú
fields, (US$ 338) in Rio de Janeiro. In 2023, it includes the provision established for the Uruguá cluster (US$ 381) and
the reduction of the provision related to the Pescada cluster (US$ 41), as set out in note 29.
The expected realization of the provisions is presented below:
2025
2026
2027
2028
2029
2030
onwards
12.31.2024
Provision for decommissioning costs
1,696
2,593
2,153
2,340
1,724
15,697
26,203
The effect of a change in the discount rate (key assumption) may result in material variations of the provision, as
outlined below.
Sensitivity to the discount rate (1)
Effects on
provision for
decommissioning
Effects on carrying
amounts of assets
Effects on other
income and
expenses
Increase of 0.5 percentage points
(1,631)
(1,484)
(146)
Decrease of 0.5 percentage points
1,796
1,629
166
(1) It includes liabilities held for sale.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-71
The transfer to liabilities held for sale refers to the register and revision of the provision associated with E&P assets in
the divestment process and classified as assets held for sale.
Accounting policy for decommissioning costs
The initial recognition of legal obligations to remove equipment and restore land or sea areas at the end of operations
occurs after the declaration of commercial feasibility of an oil and gas field. The calculations of the cost estimates for
future environmental removals and recoveries are complex and involve significant uncertainties (as set out in note 4.6).
The estimates of decommissioning costs are reviewed annually based on current information on expected costs and
recovery plans. When the revision of the estimates results in an increase in the provision for decommissioning costs,
there is a corresponding increase in assets. Otherwise, if a decrease in the liability exceeds the carrying amount of the
asset, the excess shall be recognized immediately in profit or loss, within other income and expenses.
21. Other assets and liabilities
Assets
12.31.2024
12.31.2023
Escrow account and/ or collateral
(a)
750
1,009
Advances to suppliers
(b)
2,207
1,814
Prepaid expenses
(c)
351
453
Derivatives transactions
(d)
29
92
Assets related to E&P partnerships
(e)
378
255
Others
336
262
4,051
3,885
Current
1,550
1,570
Non-Current
2,501
2,315
Liabilities
12.31.2024
12.31.2023
Obligations arising from divestments
(f)
914
1,200
Contractual retentions
(g)
611
716
Advances from customers
(h)
270
692
Provisions for environmental expenses, research and development and fines
(i)
681
708
Other taxes
(j)
301
376
Unclaimed dividends
(k)
276
337
Derivatives transactions
(d)
129
62
Obligations arising from acquisition of equity interests
(l)
130
156
Various creditors
99
138
Others
414
520
3,825
4,905
Current
2,205
3,015
Non-Current
1,620
1,890
The following references detail the nature of the operations that make up the balances of other assets and liabilities:
a) Amounts deposited for payment of obligations related to the finance agreement with China Development Bank, as
well as margin in guarantee for futures and over-the-counter derivatives. In addition, there are amounts in investment
funds from escrow accounts related to divestment of Transportadora Associada de Gás S.A. (TAG) and in Nova
Transportadora do Sudeste S.A. (NTS).
b) The balance mainly comprises advances for the construction of platforms P-80, P-82, P-83, P-84 and P-85 and for
the acquisition of underwater oil and gas production and flow equipment. For each of the agreements related to these
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-72
advances, the Company has an associated guarantee capable of fully covering the amount advanced by Petrobras,
which includes bank guarantees, letters of credit, guarantee insurance and/or corporate guarantees.
c) Spending on platform charters and equipment rentals when the start of operations has been postponed due to legal
requirements or to the need for technical adjustments.
d) Fair value of open positions and transactions closed but not yet settled.
e) Cash and amounts receivable from partners in E&P consortia operated by Petrobras.
f) Provisions for contractual indemnities and financial reimbursements assumed by Petrobras to be made to the
acquirer, referring to abandonment costs of divested assets. The settlement of these provisions follows
decommissioning schedules, with payments beginning between two and three months after the date expected for the
execution of operations, according to the contractual terms for reimbursement of abandonment of the respective oil
fields.
g) Retained amounts from obligations with suppliers to guarantee the execution of the contract, accounted for when
the obligations with suppliers are due. Contractual retentions will be paid to suppliers at the end of the contract, upon
issuance of the contract termination term.
h) Amounts related to the advances or cash receipt from third parties, related to the sale of products or services.
i) Accrued amounts for environmental compensation assumed by the Company in the course of its operations and
research projects.
j) Non-current portion of other taxes (see note 17).
k) Dividends made available to shareholders and not paid due to the existence of pending registration issues for which
the shareholders are responsible with the custodian bank for the shares and with Petrobras, according to note 32.
l) Obligations arising from the acquisition of equity interests in Araucária Nitrogenados, which will be settled by the end
of 2030.
Accounting policy for other assets and liabilities
The accounting recognition of obligations arising from divestment is at present value, using a risk-free discount rate,
adjusted to reflect the Company's credit risk, being the best estimate of the disbursement required to settle the present
obligation on the statement of financial position date. The obligations are subject to significant changes as activity
execution schedules are updated and detailed by buyers.
22. The “Lava Jato (Car Wash) Operation” and its effects on the Company
In the preparation of these consolidated financial statements for the the year ended December 31, 2024, the Company
considered all the available information relating to the “Lava Jato” Operation, and did not identify any of such
information that would affect the adopted calculation methodology and would trigger additional write-offs on the
overpayments incorrectly capitalized.
The Company will continue to monitor the investigations and collaborate with the competent authorities. Given the
absence of new relevant facts in relation to this operation in recent years, the Company does not expect any material
changes to the write-off recognized in 2014 or to the methodology adopted, unless there is a new relevant fact in the
future.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-73
During 2024, leniency and plea agreements entitled the Company to receive funds with respect to compensation for
damages, in the amount of US$ 60 (US$ 109 in 2023 and US$ 96 in 2022), accounted for as other income and expenses.
Thus, the total amount recovered from Lava Jato investigation through December 31, 2024 was US$ 1,787.
23. Property, plant and equipment
23.1. By class of assets
Land,
buildings
and
improvement
Equipment and
other assets (1)
Assets under
construction
(2)
Exploration
and
development
costs (3)
Right-of-
use assets
Total
Balance at January 1, 2024
2,687
58,409
21,516
40,432
30,380
153,424
Cost
4,634
118,173
31,467
74,809
44,829
273,912
Accumulated depreciation and impairment (4)
(1,947)
(59,764)
(9,951)
(34,377)
(14,449)
(120,488)
Additions
21
381
15,203
102
10,492
26,199
Decommissioning costs - Additions to / review of
estimates
−
−
−
6,393
−
6,393
Capitalized borrowing costs
−
−
1,558
−
−
1,558
Write-offs
(8)
(53)
(300)
(9)
(66)
(436)
Transfers (5)
482
5,126
(7,641)
2,592
10
569
Transfers to assets held for sale
−
20
(5)
(402)
69
(318)
Depreciation, amortization and depletion
(78)
(4,963)
−
(3,699)
(6,213)
(14,953)
Impairment recognition (note 25)
(2)
(439)
(324)
(864)
(45)
(1,674)
Impairment reversal (note 25)
4
140
11
19
13
187
Translation adjustment
(621)
(12,814)
(5,634)
(8,643)
(6,952)
(34,664)
Balance at December 31, 2024
2,485
45,807
24,384
35,921
27,688
136,285
Cost
3,895
96,963
30,321
67,357
42,366
240,902
Accumulated depreciation and impairment (4)
(1,410)
(51,156)
(5,937)
(31,436)
(14,678)
(104,617)
Balance at January 1, 2023
2,538
55,147
14,838
38,434
19,212
130,169
Cost
4,343
105,429
23,938
67,581
29,670
230,961
Accumulated depreciation and impairment (4)
(1,805)
(50,282)
(9,100)
(29,147)
(10,458)
(100,792)
Additions
−
528
11,919
12
15,177
27,636
Decommissioning costs - Additions to / review of
estimates
−
−
−
2,672
−
2,672
Capitalized borrowing costs
−
−
1,277
−
−
1,277
Signature Bonuses Transfers (6)
−
−
−
16
−
16
Write-offs
(11)
(304)
(86)
(74)
(156)
(631)
Transfers (5)
58
5,531
(7,058)
1,754
1
286
Transfers to assets held for sale
(16)
(36)
99
(241)
(85)
(279)
Depreciation, amortization and depletion
(84)
(5,079)
−
(4,711)
(5,432)
(15,306)
Impairment recognition (note 25)
−
(1,689)
(883)
(314)
(39)
(2,925)
Impairment reversal (note 25)
3
101
9
1
28
142
Translation adjustment
199
4,210
1,401
2,883
1,674
10,367
Balance at December 31, 2023
2,687
58,409
21,516
40,432
30,380
153,424
Cost
4,634
118,173
31,467
74,809
44,829
273,912
Accumulated depreciation and impairment (4)
(1,947)
(59,764)
(9,951)
(34,377)
(14,449)
(120,488)
(1) It is composed of production platforms, refineries, thermoelectric power plants, natural gas processing plants, pipelines, and other operating, storage and
production plants, including subsea equipment for the production and flow of oil and gas, depreciated based on the units of production method.
(2) See note 13 for assets under construction by operating segment.
(3) It is composed of exploration and production assets related to wells, abandonment and dismantling of areas, signature bonuses associated with proved reserves and
other costs directly associated with the exploration and production of oil and gas, except for assets under "Equipment and other assets".
(4) In the case of land and assets under construction, it refers only to impairment losses.
(5) It mainly includes transfers between classes of assets and transfers from advances to suppliers.
(6) Transfer from Intangible Assets.
Additions to assets under construction are mainly due to investments in the production development of Búzios, Mero
and other fields in the Espírito Santo, Santos, and Campos basins. As for additions to right-of-use assets, they are
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-74
related to the chartering of platforms, notably FPSO Maria Quiteria and FPSO Duque de Caxias drilling rigs for E&P
operations, vessels and to the chartering of the Regasification Vessel Sequoia, operating at the LNG Terminal in Bahia,
and the respective effect on lease liability (note 31).
23.2. Estimated useful life
The useful life of assets subject to depreciation are shown below:
Asset
Weighted average useful life in years
Buildings and improvement
38 (between 25 and 50)
Equipment and other assets
22 (between 1 to 31) - except assets by the units of production method
Exploration and development costs
Units of production method or 20 years
Right-of-use
14 (between 2 and 50)
The estimated useful life of buildings and improvements, equipment and other assets is as follows:
Buildings and improvements, equipment and other assets
Estimated useful life
Cost
Accumulated
depreciation
Balance at
December 31, 2024
5 years or less
4,789
(3,830)
959
6 - 10 years
7,159
(5,221)
1,938
11 - 15 years
4,837
(3,466)
1,371
16 - 20 years
26,561
(16,323)
10,238
21 - 25 years
26,431
(9,152)
17,279
25 - 30 years
10,627
(3,505)
7,122
30 years or more
4,773
(1,555)
3,218
Units of production method
15,535
(9,491)
6,044
Total
100,712
(52,543)
48,169
Buildings and improvements
3,749
(1,387)
2,362
Equipment and other assets
96,963
(51,156)
45,807
23.3. Right-of-use assets
The table below shows the split by type of asset and readjustment clauses with possible impacts on accumulated
depreciation and impairment, as follows:
Platforms
Vessels
Properties
Total
Cost
22,484
17,542
2,340
42,366
Accumulated depreciation and impairment
(4,712)
(9,216)
(750)
(14,678)
Without contractual readjustment clauses
−
(7,490)
(120)
(7,610)
With contractual readjustment clauses - Brazil
(4,712)
(731)
−
(5,443)
With contractual readjustment clauses – abroad
−
(996)
(629)
(1,625)
Balance at December 31, 2024
17,772
8,326
1,590
27,688
Cost
23,859
18,000
2,970
44,829
Accumulated depreciation and impairment
(4,803)
(8,796)
(850)
(14,449)
Without contractual readjustment clauses
−
(7,103)
(168)
(7,271)
With contractual readjustment clauses - Brazil
(4,803)
(225)
−
(5,028)
With contractual readjustment clauses – abroad
−
(1,468)
(682)
(2,150)
Balance at December 31, 2023
19,056
9,204
2,120
30,380
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-75
Accounting policy for property, plant and equipment
Property, plant and equipment are measured at the cost of acquisition or construction, including all costs necessary to
bring the asset to working condition for its intended use and the estimated cost of dismantling and removing the asset
and restoring the site, reduced by accumulated depreciation and impairment losses.
A condition for continuing to operate certain items of property, plant and equipment, such as industrial plants, offshore
plants and vessels is the performance of regular major inspections and maintenance. Those expenditures are
capitalized if a maintenance campaign is expected to occur, at least, 12 months later. Otherwise, they are expensed
when incurred. The capitalized costs are depreciated over the period through the next major maintenance date.
Spare parts are capitalized when they are expected to be used during more than one period and can only be used in
connection with an item of property, plant and equipment, and are depreciated over the useful life of the item of
property, plant and equipment to which they relate.
Borrowing costs directly attributable to the acquisition or construction of qualifying assets are capitalized as part of
the costs of these assets.
General borrowing costs are capitalized based on the Company’s weighted average cost of borrowings outstanding
applied over the balance of assets under construction.
In general, the Company suspends capitalization of borrowing to the extent investments in a qualifying asset hibernates
during a period greater than one year or whenever the asset is prepared for its intended use.
Assets directly associated to the production of oil and gas in a contracted area whose useful lives are not less than the
life of the field (reserve exhaustion time), including rights and concessions such as signature bonus, are depleted by the
unit-of-production method.
The unit-of-production method of depreciation (amortization) is computed based on the monthly production volume
over the proved developed oil and gas reserves, except for signature bonuses for which unit of production method takes
into account the monthly production over the total proved oil and gas reserves on a field-by-field basis.
Assets related to oil and gas production with useful lives shorter than the life of the field; floating platforms and other
assets unrelated to oil and gas production are depreciated on a straight-line basis over their useful lives, which are
reviewed annually. Note 23.2 provides further information on the estimated useful life by class of assets. Lands are not
depreciated.
Right-of-use assets are presented as property, plant and equipment and, according to the useful lives of their
respective underlying assets and the characteristics of lease agreements (term, asset transfer or exercise of call option),
are depreciated using the straight-line method based on contractual terms.
23.4. Oil and Gas fields operated by Petrobras returned to ANP
In 2024, the Cachalote oil and gas field, in Campos basin, was returned to ANP. The Company wrote this field off due to
impairments recognized.
In 2023, the following oil and gas fields, in Campos basin, were returned to ANP: Atum, Curimã, Espada and Xaréu. Thus,
the Company wrote off the amount of US$ 45.
In 2022, the following oil and gas fields, in Ceará basin, were returned to ANP: Anequim, Congro, Corvina, Garoupa,
Garoupinha, Malhado, Namorado, Parati and Viola. These fields were returned to ANP mainly due to their economic
unfeasibility and, as a consequence, the Company wrote off the amount of US$ 619 in addition to impairments
recognized in prior years.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-76
23.5. Capitalization rate used to determine the amount of borrowing costs eligible for
capitalization
The capitalization rate used to determine the amount of borrowing costs eligible for capitalization was the weighted
average of the borrowing costs applicable to the borrowings that were outstanding during the period, other than
borrowings made specifically for the purpose of obtaining a qualifying asset. For the year ended December 31,2024, the
capitalization rate was 7.19% p.a. (7% p.a. for the year ended December 31, 2023).
24. Intangible assets
24.1. By class of assets
Rights and
Concessions (1)
Software
Goodwill
Total
Balance at January 1, 2024
2,425
592
25
3,042
Cost
2,489
1,891
25
4,405
Accumulated amortization and impairment
(64)
(1,299)
−
(1,363)
Addition
24
201
−
225
Capitalized borrowing costs
−
12
−
12
Write-offs
(18)
(2)
−
(20)
Transfers
−
7
−
7
Amortization
(4)
(130)
−
(134)
Impairment recognition (note 25)
(224)
−
−
(224)
Translation adjustment
(506)
(142)
(5)
(653)
Balance at December 31, 2024
1,697
538
20
2,255
Cost
1,750
1,663
20
3,433
Accumulated amortization and impairment
(53)
(1,125)
−
(1,178)
Estimated useful life in years
Indefinite (2)
5
Indefinite
Balance at January 1, 2023
2,523
439
24
2,986
Cost
2,578
1,560
24
4,162
Accumulated amortization and impairment
(55)
(1,121)
−
(1,176)
Addition
148
200
−
348
Capitalized borrowing costs
−
13
−
13
Write-offs
(41)
−
−
(41)
Transfers
(11)
2
−
(9)
Signature Bonuses Transfers (3)
(16)
−
−
(16)
Amortization
(4)
(100)
−
(104)
Impairment recognition (note 25)
(364)
−
−
(364)
Translation adjustment
190
38
1
229
Balance at December 31, 2023
2,425
592
25
3,042
Cost
2,489
1,891
25
4,405
Accumulated amortization and impairment
(64)
(1,299)
−
(1,363)
Estimated useful life in years
Indefinite (2)
5
Indefinite
(1) It comprises mainly signature bonuses (amounts paid in concession and production sharing contracts for oil or natural gas exploration), in addition to public service
concessions, trademarks and patents and others.
(2) Mainly composed of assets with indefinite useful lives, which are reviewed annually to determine whether events and circumstances continue to support an indefinite
(3) Transfer to PP&E Assets.
24.2. ANP Bidding Result
Blocks in the Pelotas Basin - 4th Permanent Concession Offering Cycle
On December 13, 2023, Petrobras acquired exploration and production rights for oil and natural gas in 29 blocks in the
Pelotas Basin during the 4th Permanent Concession Offering Cycle conducted by ANP, with a signature bonus payment
of US$ 20 in 2024. For more information about the contracts signed through partnerships, see note 27.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-77
24.3. Exploration rights returned to the ANP
In 2024, the return of 5 exploratory blocks was approved, resulting in the write-off of the respective assets. These blocks
are: ES-M-598 and ES-M-673, located in the Espírito Santo Basin; PAR-T-175, in the Paraná Basin, totaling US$ 19; as
well as blocks C-M-657 and C-M-709, located in the Campos Basin, as stated in explanatory note 25. In 2023, 8
exploration areas located in the pre-salt area of the Campos Basin were returned to ANP, totaling US$ 414 (R$ 2,006
million) in exploration rights written-off.
For more information see note 26 regarding exploration and evaluation of oil and gas reserves.
Accounting policy for intangible assets
Intangible assets are measured at the acquisition cost, less accumulated amortization and impairment losses.
Internally-generated intangible assets are not capitalized and are expensed as incurred, except for development costs
that meet the recognition criteria related to the completion and use of assets, probable future economic benefits, and
others.
When the technical and commercial feasibility of oil and gas production is demonstrated for the first field in an area,
the value of the signature bonus is reclassified to property, plant and equipment at their full value. While they are
registered in intangible assets, they are not amortized. Other intangible assets with defined useful lives are amortized
on a straight-line basis over their estimated useful lives.
If, when defining the technical and commercial feasibility of the first field of a block, there are exploratory activities
being carried out in different locations in the block, so that oil and gas volumes can be estimated for other possible
reservoirs in the area, then the value of the signature bonus is partially reclassified to PP&E, based on the ratio between
the volume of oil and gas expected (oil in place - VOIP) of a specific reservoir and the total volume of oil and gas expected
for all possible reservoirs in the area.
If exploratory activities in the remaining areas do not result in technical and commercial viability, the corresponding
value of the signature bonus is not written off, but transferred to PP&E and added to the value of the signature bonus
related to the location that was previously assessed as technically and commercially viable.
Intangible assets with an indefinite useful life are not amortized but are tested annually for impairment. Their useful
lives are reviewed annually.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-78
25. Impairment
Statement of income
2024
2023
2022
Impairment (losses) reversals
(1,531)
(2,680)
(1,315)
Exploratory assets
(224)
(364)
−
Impairment of equity-accounted investments
13
(2)
(6)
Net effect within the statement of income
(1,742)
(3,046)
(1,321)
Losses
(1,955)
(3,307)
(1,640)
Reversals
213
261
319
Statement of financial position
2024
2023
2022
Property, plant and equipment (1)
(1,487)
(2,783)
(1,163)
Intangible assets (1)
(224)
(364)
(1)
Assets classified as held for sale
(32)
103
(151)
Investments
1
(2)
(6)
Net effect within the statement of financial position
(1,742)
(3,046)
(1,321)
(1) See note 25.1.
The Company annually tests its assets for impairment or when there is an indication that their carrying amount may not
be recoverable, or that there may be a reversal of impairment losses recognized in previous years.
On November 21, 2024, management concluded and approved its Business Plan 2025-2029, considering a complete
update of economic assumptions, as well as its project portfolio and estimates of reserve volumes.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-79
25.1. Impairment of property, plant and equipment and intangible assets
Asset or CGU by nature (1)
Carrying
amount
before
impairment
testing
Recoverable
amount (2)
Impairment
(losses) /
reversals (3)
Business
segment
Comments
2024
Producing properties relating to oil and gas activities in Brazil (several CGUs)
7,998
7,000
(1,129)
E&P
Item (a1)
Second refining unit in RNEST
414
−
(421)
RT&M
Item (b1)
Oil and gas exploratory assets (several CGUs)
200
−
(224)
E&P
Item (c1)
Others
63
Several
Total
(1,711)
2023
Producing properties relating to oil and gas activities in Brazil (several CGUs)
8,332
6,108
(2,217)
E&P
Item (a2)
Second refining unit in RNEST
943
455
(486)
RT&M
Item (b2)
Oil and gas exploratory assets (several CGUs)
371
−
(364)
E&P
Item (c2)
Others
−
−
(80)
Several
Total
(3,147)
2022
Producing properties relating to oil and gas activities in Brazil (several CGUs)
8,307
7,747
(628)
E&P
Item (a3)
Oil and gas production and drilling equipment in Brazil (several CGUs)
486
7
(478)
E&P
Item (d)
Itaboraí utilities
919
777
(142)
G&LCE
Item (e)
Second refining unit in RNEST
792
882
89
RT&M
Item (b3)
Others
(5)
Several
Total
(1,164)
(1) It only refers to CGUs or assets which presented impairment losses or reversals in the period.
(2) The recoverable amounts of assets for impairment computation were their value in use, unless otherwise indicated.
(3) Impairment losses and reversals are calculated individually for each CGU. However, there are certain line items of this table which represent several CGUs. Thus, as
impairment reversals are limited to pre-impairment carrying amounts less subsequent depreciation or amortization recognized, the "Impairment (losses) / reversals" of
the line items representing several CGUs may not represent a direct relation between "Carrying amount" and "Recoverable Amount".
In assessing the recoverable amount of property, plant and equipment and intangible assets, individually or grouped in
CGUs, the Company bases its cash flow projections on:
•
the estimated useful life of the asset or assets grouped into the CGU, based on the expected use of those assets,
considering the Company’s maintenance policy;
•
assumptions and financial forecasts approved by management for the period corresponding to the expected life
cycle of each different business; and
•
discount rates derived from the Company’s post-tax weighted average cost of capital (WACC), adjusted by specific
risk-premiums in case of projects postponed for an extended period, or by specific country-risks, in case of assets
abroad. The use of post-tax discount rates in determining value in use does not result in different recoverable
amounts if pre-tax discount rates had been used.
The cash flow projections used to measure the value in use of the CGUs, at December 31, 2024, were mainly based on
the following updated assumptions for average Brent prices and Brazilian real/U.S. dollar average exchange rates:
At December 31, 2024, average Brent prices and Brazilian real/U.S. dollar average exchange rates used were:
Business Plan 2025-2029
2025
2026
2027
2028
2029
Long term
Average
Average Brent (US$/barrel)
83
77
74
71
68
65
Average Brazilian Real (excluding inflation) - Real /U.S. dollar exchange rate
5.00
4.92
4.87
4.83
4.79
4.64
At December 31, 2023, average Brent prices and Brazilian real/U.S. dollar average exchange rates used were:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-80
Strategic Plan 2024-2028
2024
2025
2026
2027
2028
Long term
Average
Average Brent (US$/barrel)
80
78
75
73
70
65
Average Brazilian Real (excluding inflation) - Real /U.S. dollar exchange rate
5.05
5.04
5.03
4.98
4.90
4.65
At December 31, 2022, average Brent prices and Brazilian real/U.S. dollar average exchange rates used were:
Strategic Plan 2023-2027
2023
2024
2025
2026
2027
Long term
Average
Average Brent (US$/barrel)
85
80
75
70
65
55
Average Brazilian Real (excluding inflation) - Real /U.S. dollar exchange rate
5.02
5.00
5.00
4.97
4.88
4.76
Post-tax discount rates, excluding inflation, applied in the tests which presented the main impairment losses and
reversals for the period were:
Activity
12.31.2024
12.31.2023
Producing properties relating to oil and gas activities in Brazil
7.6% p.a.
7.6% p.a.
RT&M in Brazil – postponed projects
7.7% p.a.
7.0% p.a.
In 2024, the main changes in the CGUs (in the E&P segment) were:
•
Extinction of the Carapanaúba field due to its annexation to the Sudoeste de Urucu field (Arara cluster);
•
Extinction of the Cherne cluster due to the signing of a purchase and sale agreement for the transfer of
Petrobras' entire interest;
•
Extinction of the Cidade Entre Rios field due to its annexation to the Riacho Ouricuri field;
•
Exclusion of the Cachalote field following the approval of its abandonment; and
•
Reintegration of the Uruguá and Tambaú fields due to the cancellation of the purchase and sale agreement.
Additional information on key assumptions for impairment testing and on CGU definitions is presented in note 4.2.2.
Information on the main impairment losses of property, plant and equipment and intangible assets is presented as
follows:
a1) Producing properties in Brazil – 2024
The assessments of assets linked to oil and gas production fields in Brazil resulted in net losses amounting to US$ 1,129,
primarily related to the CGUs of: (i) Roncador (US$ 366), Barracuda and Caratinga cluster (US$ 204). These losses were
mainly driven by the revision of decommissioning costs, as well as a reduction in platform efficiency and well
performance forecasts for Barracuda and Caratinga cluster, negatively impacting the production curves of the fields;
and (ii). Uruguá/Tambaú (US$ 497) due to the cancellation of the divestment process and the absence of production
curves associated with Business Plan 2025-2029.
a2) Producing properties in Brazil – 2023
Impairment losses on producing properties in Brazil amount to US$ 2,217, mainly in Roncador field (US$ 2,004), due to
the revision of the production curve, in the Strategic Plan 2024-2028, arising from below-expected performance of its
wells observed in 2023, due to the interruption of production in some wells and to the accelerated decline of production
due to the increase in the percentage of water in other wells.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-81
a3) Producing properties in Brazil – 2022
Impairment losses on producing properties in Brazil amount to US$ 628, mainly in Roncador field (US$ 518), reflecting
the revision of abandonment costs and of the recovery of areas, as well as changes in operational efficiency estimates,
which had a negative effect over production curves of this field.
b1) Second refining unit of RNEST – 2024
Impairment losses amounting to US$ 421 due to the increase in investment and operating expenditures estimates
reflected in the Business Plan 2025-2029.
b2) Second refining unit of RNEST – 2023
In 2023, the Company recognized a US$ 486 loss on this asset, mainly due to: (i) the review of the scope for the
implementation of logistics infrastructure, with an increase in necessary investments; and (ii) the revision of the
assumptions of the Strategic Plan 2024-2028, resulting in an increase in operational costs.
b3) Second refining unit of RNEST – 2022
The cash flows to measure the value in use of the second refining unit of RNEST considers operational optimization and
the margins for the refining segment estimated in the Strategic Plan 2023-2027, triggering impairment reversals in the
amount of US$ 89.
c1) Oil and gas exploratory assets -2024
The assessments conducted on exploratory assets indicated a reduction in the recoverable values of the exploratory
blocks C-M-657 and C-M-709, located in the Campos Basin and, consequently, the recognition of losses amounting to
US$ 224. Management approved the full and voluntary relinquishment of these blocks to ANP in October 2024.
c2) Oil and gas exploratory assets -2023
The assessment carried out on exploratory assets located in the pre-salt layer of the Campos basin (blocks C-M-210, C-
M-277, C-M-344, C-M-346, C-M-411 and C-M-413) resulted in the recognition of a US$ 364 loss, due to the economic
unfeasibility of projects in the phase of production development. In October 2023, the Company’s management
approved the full and voluntary return of these blocks to the ANP.
d) Oil and gas production and drilling equipment in Brazil - 2022
Impairment losses of US$ 478 relates to equipment and structures in the E&P segment, mainly due to the decision to
cease the use of platforms P-18, P-19, P-20, P-35 and P-47 in the Marlim field, leading to the recognition of losses in
the amount of US$ 402.
e) Itaboraí utilities - 2022
The postponement of the beginning of operations of the Natural Gas Processing Unit (UPGN) of the Gaslub plant in
Itaboraí, in the state of Rio de Janeiro, due to the termination of the agreement with the contractor responsible for the
works, impacted revenue estimate, resulting in the recognition of a US$ 142 impairment loss.
25.1.1. Assets most sensitive to future impairment recognition
Whenever the recoverable amount of an asset or CGU falls below the carrying amount, an impairment loss is recognized
to reduce the carrying amount to the recoverable amount. The following table presents the assets and CGUs most
sensitive to future impairment losses, presenting recoverable amounts close to their current carrying amounts.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-82
The analysis presented as follows considers CGUs with estimated impairment losses or reversals if there was a 10%
reduction or increase in their recoverable amounts, arising from changes in material assumptions:
Potential impairment losses - 10% reduction in the recoverable amount
Business
segment
Carrying
amount
Recoverable
amount
Sensitivity
Asset with recoverable amount close to its carrying amount
CGU Marlim Sul
E&P
4,825
4,760
(65)
Assets with impairment losses
Producing properties relating to oil and gas activities in Brazil (9 CGUs)
E&P
6,656
5,991
(665)
Itaboraí utilities
G&LCE
900
810
(90)
Araucária Nitrogenados - ANSA
RT&M
12
11
(1)
12,393
11,572
(821)
Potential impairment reversals - 10% increase in the recoverable amount
Business
segment
Carrying
amount
Recoverable
amount
Sensitivity
(1)
Assets with impairment losses
Producing properties relating to oil and gas activities in Brazil (9 CGUs)
E&P
6,656
7,322
666
Itaboraí utilities
G&LCE
900
989
89
Araucária Nitrogenados - ANSA
RT&M
12
13
1
7,568
8,324
756
(1) When calculating a 10% increase in the recoverable amount, the amount of impairment to be reversed is limited to the accumulated impairment of the CGU or to
their recoverable amounts, whichever is lower.
Accounting policy for impairment of property, plant and equipment and intangible assets
Property, plant and equipment and intangible assets are assessed for impairment at the smallest identifiable group
that generates largely independent cash inflows from other assets or groups of assets (CGU). Note 4.2 presents detailed
information about the Company’s CGUs.
Assets related to development and production of oil and gas assets (fields or clusters) that have indefinite useful lives,
such as goodwill, are tested for impairment at least annually, irrespective of whether there is any indication of
impairment.
Considering the existing synergies between the Company’s assets and businesses, as well as the expectation of the use
of its assets for their remaining useful lives, value in use is generally used by the Company for impairment testing
purposes. When specifically indicated, the Company assesses differences between its assumptions and assumptions
that would be used by market participants in the determination of the fair value of an asset or CGU.
Reversal of previously recognized impairment losses may occur for assets other than goodwill.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-83
25.2. Assets classified as held for sale
Asset or CGU by nature (1)
Carrying
amount
before
impairment
testing
Recoverable
amount (2)
Impairment
(losses) /
reversals (3)
Business
segment
2024
Producing properties relating to oil and gas activities
44
−
(44)
E&P
Others
12
Several
Total
(32)
2023
Producing properties relating to oil and gas activities
230
334
102
E&P
Others
1
Several
Total
103
2022
Producing properties relating to oil and gas activities
376
300
(116)
E&P
Refinery and associated logistics assets
77
34
(44)
RT&M
Others
9
Several
Total
(151)
(1) It only refers to assets or groups of assets which presented impairment losses or reversals in the period.
(2) The recoverable amounts of assets for impairment computation were their fair value.
In 2024, the Company recognized impairment losses on assets held for sale arising from the assessment at the fair value
of assets, net of disposal expenses, mainly arising from Pescada cluster, due to decommissioning cost review.
In 2023, the Company recognized reversals on assets held for sale in the amount of US$ 103 arising from the assessment
at the fair value of assets, net of disposal expenses, mainly arising from the approval for the disposal of Uruguá cluster
(US$ 102).
In 2022, the Company recognized losses on assets held for sale in the amount of US$ 151, arising from the assessment
at the fair value of assets, net of disposal expenses, mainly:
i. producing properties relating to oil and gas activities – a US$ 116 impairment loss, due to the revision of
abandonment costs and of the recovery of areas of several concessions in clusters Golfinho (a US$ 72 impairment
loss), Pescada (a US$ 29 impairment loss) and Camarupim (a US$ 15 impairment loss); and
ii. refinery and associated logistics assets: approval for the disposal of LUBNOR refinery, in the state of Ceará, resulting
in the recognition of a US$ 44 impairment loss.
The accounting policy for assets and liabilities held for sale is set out in note 29.
25.3. Investments in associates and joint ventures (including goodwill)
Value in use is generally used for impairment test of investments in associates and joint ventures (including goodwill).
The basis for estimates of cash flow projections includes: projections covering a period of 5 to 12 years, zero-growth
rate perpetuity, budgets, forecasts and assumptions approved by management and a post-tax discount rate derived
from the WACC or the Capital Asset Pricing Model (CAPM) models, specific for each case.
Accounting policy for impairment of associates and joint ventures
Investments in associates and joint ventures are tested individually for impairment. When performing impairment
testing of an equity-accounted investment, goodwill, if it exists, is also considered part of the carrying amount to be
compared to the recoverable amount.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-84
Except when specifically indicated, value in use is generally used by the Company for impairment testing purposes in
proportion to the Company’s interests in the present value of future cash flow projections via dividends and other
distributions.
25.3.1. Investment in publicly traded associates
Braskem S.A.
Braskem’s shares are publicly traded on stock exchanges in Brazil and abroad. As of December 31, 2024, the quoted
market value of the Company’s investment in Braskem was US$ 557 based on the quoted values of both Petrobras’
interest in Braskem’s common stock (47% of the outstanding shares), and preferred stock (22% of the outstanding
shares, see note 28.4). However, there is extremely limited trading of the common shares, since non-signatories of the
shareholders’ agreement hold only approximately 3% of the common shares.
Given the operational relationship between Petrobras and Braskem, the recoverable amount of the investment for
impairment testing purposes was determined based on value in use, considering future cash flow projections and the
manner in which the Company can derive value from this investment via dividends and other distributions to arrive at
its value in use. As the recoverable amount was higher than the carrying amount, no impairment losses were recognized
for this investment.
Cash flow projections to determine the value in use of Braskem were based on estimated prices of feedstock and
petrochemical products reflecting international trends on prices, petrochemical products sales volume estimates
reflecting projected Brazilian and global G.D.P. growth, post-tax discount rate (excluding inflation) of 7.4% p.a., (WACC),
and decreases in the EBITDA margin during the growth cycle of the petrochemical industry in the next years and
increases in the long-term. Estimated exchange rates and Brent prices are the same as those set out in note 25.1.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-85
26. Exploration and evaluation of oil and gas reserves
The exploration and evaluation activities include the search for oil and gas reserves from the date of obtaining the legal
rights to explore a specific area to the moment in which technical and commercial feasibility to produce oil and gas are
demonstrated.
Changes in the balances of capitalized costs directly associated with exploratory wells pending determination of proved
reserves and the balance of amounts paid for obtaining rights and concessions for exploration of oil and natural gas
(capitalized acquisition costs) are set out in the following table:
Capitalized Exploratory Well Costs / Capitalized Acquisition Costs (1)
2024
2023
Property plant and equipment
Opening Balance
1,512
1,876
Additions
338
505
Write-offs
(27)
(8)
Transfers
(3)
(1,000)
Translation adjustment
(345)
139
Closing Balance
1,475
1,512
Intangible assets
Opening Balance
2,313
2,406
Additions
20
147
Write-offs
(19)
(41)
Transfers
−
(16)
Losses on exploration expenditures written off
(224)
(364)
Translation adjustment
(481)
181
Closing Balance
1,609
2,313
Capitalized Exploratory Well Costs / Capitalized Acquisition Costs
3,084
3,825
(1) Amounts capitalized and subsequently expensed in the same period have been excluded from this table.
The additions occurred in Intangible assets during 2024 mainly referred to due to the signing of agreement of the 29
blocks in the Pelotas Basin acquired in the 4th Permanent Concession Offering Cycle.
The recognition of losses in Intangible assets (US$ 224), in 2024, was due to the economic unfeasibility of the
exploratory blocks C-M-657 and C-M-709, located in the Campos Basin, given that the Company decided not to
complete the development of these projects (see note 25).
In 2023, the recognition of losses in Intangible Assets (US$ 364) was due to the economic unfeasibility of the projects
in blocks C-M-210, C-M-277, C-M-344, C-M-346, C-M-411 and C-M-413, which were in the production development
phase. In October 2023, the Company’s Management approved the voluntary full return of these blocks to the ANP, in
addition to the return of Dois Irmãos block (US$ 37) and Três Marias block (US$ 6). All blocks are located in the pre-salt
layer of the Campos basin and the corresponding assets were written-off.
The transfers which occurred in Property plant and equipment during 2023 were destined for the production
development projects of the Raia Pintada and Raia Manta fields, related to the BM-C-33 block (US$ 968), and the Sépia
field (US$ 46).
Exploration costs recognized in the statement of income and cash used in oil and gas exploration and evaluation
activities are set out in the following table:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-86
2024
2023
2022
Exploration costs recognized in the statement of income
Geological and geophysical expenses
(412)
(566)
(358)
Exploration expenditures written off (includes dry wells and signature bonuses (1)
(482)
(421)
(248)
Contractual penalties on local content requirements
(5)
12
(47)
Other exploration expenses
(14)
(7)
(34)
Total expenses
(913)
(982)
(687)
Cash used in:
Operating activities
426
573
393
Investment activities
582
672
555
Total cash used
1,008
1,245
948
(1) It includes amounts relating to economic unfeasibility of exploratory blocks (note 25).
In 2023 and 2022, Petrobras signed Terms of Conduct Adjustment (TACs) with the ANP to offset local content fines
related in 24 concessions in which Petrobras has a 100% interest and in 22 concessions in which Petrobras operates in
partnership with other companies.
The TACs converted fines into investment commitments in the Exploration and Production segment with local content,
resulting in the closing of administrative proceedings, resulting in a US$ 0.2 gain in 2024 due to the reversal of liabilities
(a US$ 54 gain in 2023).
As of December 31, 2024, under the terms of the agreement, Petrobras commits to investing US$ 160 (R$ 990) in local
content by December 31, 2027.
Accounting policy for exploration and evaluation of oil and gas reserves
The costs incurred in connection with the exploration, appraisal and development of crude oil and natural gas production
are accounted for using the successful efforts method of accounting, as set out below:
• geological and geophysical costs related to exploration and appraisal activities incurred until economic and technical
feasibility are demonstrated are immediately recognized as an expense;
• amounts paid for obtaining concessions for exploration of crude oil and natural gas (capitalized acquisition costs)
are initially capitalized as intangible assets and are transferred to property, plant and equipment once the technical
and commercial feasibility are demonstrated. More information on intangible assets accounting policy, see note 24;
• costs directly attributable to exploratory wells, including their equipment, installations and other costs necessary
to identify the technical and commercial feasibility, pending determination of proved reserves, are capitalized within
property, plant and equipment. In some cases, exploratory wells have discovered oil and gas reserves, but at the
moment the well drilling is completed they are not yet able to be classified as proved. In such cases, the expenses
continue to be capitalized if the well has found a sufficient quantity of reserves to justify its completion as a
producing well and progress on assessing the reserves and the technical and commercial feasibility of the project is
under way (for more information see note 26.1);
• an internal commission of technical executives of the Company reviews monthly these conditions for each well, by
analysis of geoscience and engineering data, existing economic conditions, operating methods and government
regulations (for more information see note 4.1);
• costs related to exploratory wells drilled in areas of unproved reserves are charged to expense when determined to
be dry or uneconomic by the aforementioned internal commission; and
• costs related to the construction, installation and completion of infrastructure facilities, such as drilling of
development wells, construction of platforms and natural gas processing units, construction of equipment and
facilities for the extraction, handling, storing, processing or treating crude oil and natural gas, pipelines, storage
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-87
facilities, waste disposal facilities and other related costs incurred in connection with the development of proved
reserve areas (technically and commercially feasible) are capitalized within property, plant and equipment.
26.1. Aging of Capitalized Exploratory Well Costs
The following tables set out the amounts of exploratory well costs that have been capitalized for a period of one year or
more after the completion of drilling, the number of projects whose costs have been capitalized for a period greater
than one year, and an aging of those amounts by year (including the number of wells relating to those costs):
Aging of capitalized exploratory well costs (1)
2024
2023
Exploratory well costs capitalized for a period of one year
311
211
Exploratory well costs capitalized for a period greater than one year
1,164
1,301
Total capitalized exploratory well costs
1,475
1,512
Number of projects relating to exploratory well costs capitalized for a period greater than one year
18
17
Capitalized
costs
(
)
Number of
wells
2023
76
2
2022
209
3
2021
73
2
2020
17
1
2019 and previous years
789
14
Exploratory well costs that have been capitalized for a period greater than one year
1,164
22
(1) Amounts paid for obtaining rights and concessions for exploration of oil and gas (capitalized acquisition costs) are not included.
Exploratory well costs that have been capitalized for a period greater than one year since the completion of drilling
relate to 18 projects comprising 22 wells, are composed of (i) US$ 1,046 of wells in areas in which there has been ongoing
drilling or firmly planned drilling activities for the near term and for which an evaluation plan has been submitted for
approval to the ANP; and (ii) US$ 118 relates to costs incurred to evaluate technical and commercial feasibility necessary
for the decision on the production development and on definition of proved reserves.
26.2. Collateral for crude oil exploration concession agreements
The Company has granted collateral to ANP in connection with the performance of the Minimum Exploration Programs
established in the concession agreements for petroleum exploration areas in the total amount of US$ 1,250 (US$ 1,770
as of December 31, 2023), which is still in force as of December 31, 2024, net of commitments undertaken. As of
December 31, 2024, the collateral comprises future crude oil production capacity from Marlim and Buzios producing
fields, already in production, pledged as collateral, in the amount of US$ 1,239 (US$ 1,756 as of December 31, 2023) and
bank guarantees of US$ 11 (US$ 14 as of December 31, 2023).
27. Consortia (partnerships) in E&P activities
In line with its strategic objectives, Petrobras operates in association with other companies in consortia as holder of oil
and natural gas exploration and production rights in concessions and production sharing regimes.
As of December 31, 2024, the Company holds interests in 95 consortia with 34 companies, among which Petrobras is the
operator in 64 (67 consortia with 32 companies and operator in 39, as of December 31, 2023). In 2024, the Company
formed 32 new consortia, stopped participating in 2 others, and now holds 100% in 2 others.
The partnerships established in 2024, with Petrobras as the operator, are related to the 4th Cycle of the Permanent
Concession Offer in the Pelotas Basin, as follows:
•
26 contracts with Petrobras holding a 70% interest and Shell holding 30%; and
•
3 contracts with Petrobras holding a 50% interest, Shell 30%, and CNOOC 20% (note 24.2).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-88
Additionally, Petrobras will act as a non-operator in 3 new partnerships in São Tomé and Príncipe.
In 2023, 2 new partnerships were formed with Petrobras as the operator, both related to the 1st Cycle of the Permanent
Sharing Offer:
•
Campos Basin, with 30% held by Petrobras, 30% by TotalEnergies, 20% by Petronas, and 20% by Qatar Energy;
and
•
Santos Basin, with Petrobras holding a 60% interest and Shell 40%.
Consortia bring benefits through risk sharing, increased investment capacity, technical and technological interchange,
aiming at the growth in oil and gas production. The following table presents the production referring to Petrobras's
participation in the main fields in which the Company is the operator in the consortium:
Field
Location
Petrobras
interest
Partners
interest
Petrobras production
portion in 2024
(mboed)
Regime
Tupi
Santos basin pre-salt
65%
Shell - 25%
Petrogal - 10%
666
Concession
Búzios ECO
Santos basin pre-salt
85%
CNODC - 10%
CNOOC - 5%
501
Production sharing
Mero
Santos basin pre-salt
40%
TotalEnergies - 20%
Shell - 20%
CNODC - 10%
CNOOC – 10%
136
Production sharing
Roncador
Campos basin
75%
Equinor - 25%
85
Concession
Sapinhoá
Santos basin pre-salt
45%
Shell - 30%
Repsol Sinopec - 25%
77
Concession
Atapu ECO
Santos basin pre-salt
52.5%
Shell - 25%
TotalEnergies - 22.5%
47
Production sharing
Berbigão
Santos basin pre-salt
42.5%
Shell - 25%
TotalEnergies - 22.5%
Petrogal - 10%
31
Concession
Sururu
Santos basin pre-salt
42.5%
Shell - 25%
TotalEnergies - 22.5%
Petrogal - 10%
29
Concession
Tartaruga Verde
Campos basin
50.0%
Petronas - 50%
26
Concession
Sépia ECO
Santos basin pre-salt
30%
TotalEnergies - 28%
Petronas - 21%
Qatar - 21%
19
Production sharing
Total
1,617
Accounting policy for joint operations
The E&P consortia are classified as joint operations, where the assets, liabilities, revenues and expenses relating to
these consortia are accounted for in the financial statements individually, observing the applicable specific accounting
policies and reflecting the portion of the contractual rights and obligations that the Company has.
27.1. Unitization Agreements
Petrobras has Production Individualization Agreements (AIP) signed in Brazil with partner companies in E&P consortia.
These agreements result in reimbursements payable to (or receivable from) partners regarding expenses and
production volumes mainly related to Agulhinha, Albacora Leste, Berbigão, Budião Noroeste, Budião Sudeste, Caratinga
and Sururu.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-89
Provision for equalizations (1)
The table below presents changes in the reimbursements payable relating to the execution of the AIP submitted to the
approval of the ANP:
2024
2023
Opening balance
462
407
Additions to PP&E, net of write-offs
230
17
Payments made
(1)
(56)
Other income and expenses
16
62
Translation adjustments
(130)
32
Closing balance (1)
577
462
(1) Notably Berbigão, Sururu and Agulhinha.
In 2024, these agreements resulted in additions and write-offs in PP&E, in addition to other income and expenses,
reflecting the best available estimate of the assumptions used in the calculation base and the sharing of assets in areas
to be equalized.
Closed agreements in 2024
In May 2024, the Agreement on Expenditure and Volume Equalization, provided for in the Brava Shared Reservoir AIP,
was signed. The amount paid by Petrobras to Pré-sal Petróleo S.A. (PPSA) on June 24, 2024 was US$ 1.
Accounting Policy for unitization agreements
A unitization agreement occurs when a reservoir extends across two or more license or contract areas. In this case,
partners pool their individual interests in return for an interest in the overall unit (shared reservoir) and determine their
new share in the single producing unit.
Events that occurred prior to the unitization agreement may lead to the need for compensation between the partners.
The compensation will be the difference between the expenses actually incurred by each party up to the reference date
and those that should have been incurred by each party if the established participations in the shared reservoir by the
AIP were already in effect during that period.
At the signing of the AIP, an amount to be reimbursed to the Company will be recognized as an asset only when there is
a contractual right to reimbursement or when the reimbursement is practically certain. An amount to be reimbursed by
the Company will be recognized as a liability when it derives from a contractual obligation or, when the outflow of funds
is deemed probable and the amount can be reliable estimated. The provision will be offset by an increase or decrease in
PP&E, revenues and/or expenses, according to the nature of the events to be reimbursed.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-90
28. Investments
28.1. Information on direct subsidiaries, joint arrangements and associates
Main
business
segment
%
Petrobras'
ownership
%
Petrobras'
voting
rights
Sales
revenues
(1)
Share-
holders’
equity
(deficit)
Net
income
(loss)for
the year
Country
Subsidiaries
Petrobras International Braspetro - PIB BV
Several
100.00
100.00
44,842
59,836
3,668
Netherlands
Petrobras Transporte S.A. - Transpetro
RT&M
100.00
100.00
2,227
932
161
Brazil
Petrobras Logística de Exploração e Produção S.A. - PB-LOG
E&P
100.00
100.00
281
60
99
Brazil
Petrobras Biocombustível S.A.
G&LCE
100.00
100.00
242
135
13
Brazil
Araucária Nitrogenados S.A.
RT&M
100.00
100.00
−
90
75
Brazil
Termomacaé S.A.
G&LCE
100.00
100.00
11
48
7
Brazil
Braspetro Oil Services Company - Brasoil
Corporate, others
100.00
100.00
−
2
−
Cayman
Termobahia S.A.
G&LCE
98.85
98.85
−
56
10
Brazil
Baixada Santista Energia S.A.
G&LCE
100.00
100.00
−
53
8
Brazil
Fundo de Investimento Imobiliário RB Logística - FII
Corporate, others
99.15
99.15
−
18
5
Brazil
Procurement Negócios Eletrônicos S.A.
Corporate, others
72.00
49.00
14
6
1
Brazil
Petrobras Comercializadora de Gás e Energia e Participações
S.A.
G&LCE
100.00
100.00
29
12
5
Brazil
Transportadora Brasileira Gasoduto Bolívia - Brasil S.A.
G&LCE
51.00
51.00
313
61
85
Brazil
Associação Petrobras de Saúde (2)
Corporate, others
93.47
93.47
892
117
5
Brazil
Joint operations
Fábrica Carioca de Catalizadores S.A. - FCC
RT&M
50.00
50.00
60
47
22
Brazil
Joint ventures
Logum Logística S.A.
RT&M
30.00
30.00
−
186
(23)
Brazil
Petrocoque S.A. Indústria e Comércio
RT&M
50.00
50.00
−
23
4
Brazil
Refinaria de Petróleo Riograndense S.A.
RT&M
33.20
33.33
−
5
(16)
Brazil
Brasympe Energia S.A.
G&LCE
20.00
20.00
−
13
3
Brazil
Metanor S.A. - Metanol do Nordeste
RT&M
34.54
50.00
−
20
6
Brazil
Companhia de Coque Calcinado de Petróleo S.A. - Coquepar
RT&M
45.00
45.00
−
−
−
Brazil
Associates
Braskem S.A. (3)
RT&M
36.15
47.03
−
(4)
(1,053)
Brazil
Energética SUAPE II S.A.
G&LCE
20.00
20.00
−
84
32
Brazil
Nitrocolor Produtos Químicos LTDA.
RT&M
38.80
38.80
−
−
−
Brazil
Bioenergética Britarumã S.A.
G&LCE
30.00
30.00
−
−
−
Brazil
Transportadora Sulbrasileira de Gás - TSB
G&LCE
25.00
25.00
−
2
1
Brazil
(1) Sales revenues refers to the home country of companies. Regarding PIBBV, the composition of sales revenue is: 55% in the Netherlands, 26% in the United States, and 19% in Singapore.
(2) APS is a non-profit civil association, which carries out health assistance activities, and is consolidated in the Company’s financial statements.
(3) Equity and net income at September 30, 2024, most current public information.
The main investees of PIB BV are:
•
Petrobras Global Trading B.V. – PGT (100%, based in the Netherlands), dedicated to the trade of oil, oil products,
biofuels and LNG (liquefied natural gas), as well as to the funding of its activities in light of Petrobras;
•
Petrobras Global Finance B.V. – PGF (100%, based in the Netherlands); the finance subsidiary of Petrobras,
raising funds through bonds issued in the international capital market;
•
Petrobras America Inc. – PAI (100%, based in the United States), dedicated to trading and E&P activities (MP
Gulf of Mexico, LLC);
•
Petrobras Singapore Private Limited - PSPL (100%, based in Singapore), which operates primarily in the trading
of crude oil, oil products, biofuels and liquefied natural gas (LNG); and
•
Petrobras Netherlands B.V. - PNBV (100%, based in the Netherlands), operates through joint operations in Tupi
BV (67.59%), Guará BV (45%), Libra (40%), Papa Terra BV (62.5%), Roncador BV (75%), Iara BV (90.11%),
Petrobras Frade Inversiones SA - PFISA (100%) and BJSOO BV (20%), dedicated to the construction and lease
of equipment and platforms for Brazilian E&P consortia. Considering the liquidation process of companies in
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-91
the Netherlands, the company Agri BV was liquidated in the fiscal year 2024. Currently, the Company is
assessing the liquidation of Guara BV, Libra BV, Papa-Terra BV, Roncador BV and PFISA, where conditions
precedent are pending. Subsequently, the Company will assess the liquidation of Tupi BV and Iara BV.
In 2024, the Company carried out the disposal of the following direct investments:
•
Transfer of its entire 30% equity interest in Brentech Energia S.A. on May 29, 2024.
•
Exercise of the tag-along right for its 18.8% equity interest in the capital of UEG Araucária S.A. (UEGA) on July
1, 2024.
Additionally, the Company approved the dissolution of Refinaria de Mucuripe S.A. on December 30, 2024.
28.2. Investments in associates and joint ventures
Balance at
12.31.2023
Investments
Restructuring,
capital decrease
and others
Results in
equity-
accounted
investments
CTA
OCI
Dividends
Balance at
12.31.2024
Joint Ventures
481
13
−
125
(4)
−
(134)
481
MP Gulf of Mexico, LLC/PIB BV
340
−
−
75
1
−
(118)
298
Compañia Mega S.A. - MEGA
119
−
−
60
1
−
(17)
163
Other joint ventures
22
13
−
(10)
(6)
−
1
20
Associates
873
9
(12)
(752)
323
(261)
(5)
175
Others Associates
873
9
(12)
(752)
323
(261)
(5)
175
Other investments
4
−
−
−
(1)
−
−
3
Total
1,358
22
(12)
(627)
318
(261)
(139)
659
Balance at
12.31.2022
Investments
Restructuring,
capital
decrease and
others
Results in
equity-
accounted
investments
CTA
OCI
Dividends
Balance at
12.31.2023
Joint Ventures
546
12
−
(2)
2
1
(78)
481
MP Gulf of Mexico, LLC/PIB BV
374
−
−
(3)
(1)
−
(30)
340
Compañia Mega S.A. - MEGA
149
−
−
4
1
−
(35)
119
Other joint ventures
23
12
−
(3)
2
1
(13)
22
Associates
1,016
12
(1)
(302)
(114)
266
(4)
873
Other investments
4
−
−
−
−
−
−
4
Total
1,566
24
(1)
(304)
(112)
267
(82)
1,358
28.3. Investments in non- consolidated listed companies
Thousand-share lot
Quoted stock exchange
prices (US$ per share)
Fair value
12.31.2024
12.31.2023
Type
12.31.2024
12.31.2023
12.31.2024
12.31.2023
Associate
Braskem S.A.
212,427
212,427
Common
1.95
4.48
415
952
Braskem S.A.
75,762
75,762
Preferred A
1.87
4.52
142
342
557
1,294
The fair value of these shares does not necessarily reflect the realizable value upon sale of a large block of shares.
Information on the main estimates used in the cash flow projections to determine the value in use of Braskem is set out
in note 25.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-92
28.4. Non-controlling interest
The total amount of non-controlling interest at December 31, 2024 is US$ 244 (US$ 392 in 2023) primarily comprising
US$ 201 of FIDC (US$ 331 in 2023); and US$ 30 of Transportadora Brasileira Gasoduto Brasil-Bolívia – TBG (US$ 51 in
2023).
Condensed financial information is set out as follows:
FIDC
TBG
2024
2023
2024
2023
Current assets
14,839
7,803
156
260
Property, plant and equipment
−
1
246
314
Other non-current assets
−
−
4
4
14,839
7,804
406
578
Current liabilities
13
8
159
250
Non-current liabilities
−
−
186
224
Shareholders' equity
14,826
7,796
61
104
14,839
7,804
406
578
Sales revenues
−
−
313
349
Net income
1,317
1,203
85
153
Increase (decrease) in cash and cash equivalents
203
(1,133)
(51)
39
The Credit Rights Investment Fund (FIDC) is a fund mainly intended to securitize “performed” and “non-performed”
credits for operations carried out by the Company’s subsidiaries, aiming to optimize cash management.
TBG is an indirect subsidiary which operates in natural gas transmission activities mainly through Bolivia-Brazil Gas
Pipeline. The Company holds 51% of interests in this indirect subsidiary.
28.5. Summarized information on joint ventures and associates
The Company invests in joint ventures and associates in Brazil and abroad, whose activities are related to petrochemical,
refining, production, trade and logistics of oil products, gas distribution, biofuels, thermoelectric power plants, and
other activities. Condensed financial information is set out below:
2024
2023
Joint ventures Associates(1)
Joint ventures Associates(1)
In Brazil
MP Gulf of
Mexico,
LLC
Other
companies
abroad
In Brazil
MP Gulf of
Mexico,
LLC
Other
companies
abroad
Current assets
345
400
271
6,102
330
537
275
7,910
Non-current assets
242
6
22
3,365
272
66
9
2,591
Property, plant and equipment
418
1,808
305
6,594
525
1,863
189
8,082
Other non-current assets
29
−
−
1,267
41
1
−
1,263
1,034
2,214
598
17,328
1,168
2,467
473
19,846
Current liabilities
284
315
99
4,554
313
365
70
5,096
Non-current liabilities
498
425
19
12,641
533
424
52
13,182
Shareholders' equity
246
1,176
480
43
315
1,336
351
1,690
Non-controlling interest
6
298
−
90
7
342
−
(122)
1,034
2,214
598
17,328
1,168
2,467
473
19,846
Sales revenues
786
1,124
149
14,430
1,036
907
−
14,199
Net Income (loss) for the year
(25)
481
208
(2,119)
5
408
21
(849)
Ownership interest - %
20 to 50%
20%
34 to 45%
20 to 38.8%
20 to 50%
20%
34 to 45% 18.8 to 38.8%
(1) It is mainly composed of Braskem.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-93
Accounting policy for investments
Basis of consolidation
The consolidated financial statements include the financial information of Petrobras and the entities it controls
(subsidiaries), joint operations (at the level of interest the Company has in them) and consolidated structured entities.
Intragroup balances and transactions, including unrealized profits arising from intragroup transactions, are eliminated
in the consolidation of the financial statements.
Investments in other companies
Profit or loss, assets and liabilities related to joint ventures and associates are accounted for by the equity method.
Business combination
A business combination is a transaction in which the acquirer obtains control of another business, regardless it legal
form. Acquisitions of businesses are accounted for using the acquisition method when control is obtained.
Combinations of entities under common control are accounted for at cost. The acquisition method requires that the
identifiable assets acquired and the liabilities assumed be measured at the acquisition-date fair value, with limited
exceptions.
29. Disposal of assets and other transactions
The major classes of assets and related liabilities classified as held for sale are shown in the following table:
12.31.2024
12.31.2023
E&P
Total
Total
Assets classified as held for sale
Property, plant and equipment
510
510
335
Total
510
510
335
Liabilities on assets classified as held for sale
Finance debt
−
-
99
Provision for decommissioning costs
713
713
442
Total
713
713
541
29.1. Sales pending closing at December 31, 2024
a)
Cherne and Bagre fields
On April 25, 2024, the Company signed an agreement with Perenco Pétroleo e Gás Ltda (“Perenco”) for the sale of its
entire interest in the Cherne and Bagre fields, located in shallow waters of the Santos Basin.
The amount to be received is US$ 10, of which US$ 1 was received at the transaction signing and the remainder will be
received on the closing date.
29.2. Transaction interrupted
a)
Uruguá and Tambaú fields
On December 21, 2023, the Company signed agreements with Enauta Energia S.A. for the sale of its entire interest in
the Uruguá and Tambaú fields located in the post-salt layer of the Santos basin.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-94
On December 21, 2024, due to the non-completion of the acquisition of the FPSO Cidade de Santos by Enauta, Petrobras
notified Brava Energia S.A. (Enauta's parent company) of its decision to terminate the agreement, since the closing of
the transaction was subject, among other factors, to the completion of the FPSO acquisition, as provided for in the
contract.
The closing of the transaction was conditioned, among other factors, to the completion of the acquisition of the FPSO.
The amount of US$ 3 was received in advance on the signing date and was retained by Petrobras, as also provided for
in the contract, and recognized as other income and expenses, net.
Petrobras maintains its 100% interest on the Uruguá and Tambaú fields and is assessing the alternatives for the
management of these assets, which was classified as property, plant and equipment on December 31, 2024.
Accounting Policy for assets and liabilities held for sale
Non-current assets, disposal groups and liabilities directly associated with those assets are classified as held for sale if
their carrying amounts will be recovered mainly through a sale transaction.
The condition for classification as held for sale is met only when the sale is approved by the Company’s Board of
Directors and the asset or disposal group is available for immediate sale in its present condition and there is the
expectation that the sale will occur within 12 months after its classification as held for sale. However, an extended period
required to complete a sale does not preclude an asset (or disposal group) from being classified as held for sale if the
delay is caused by events or circumstances beyond the Company’s control and there is sufficient evidence that the
Company remains committed to its plan to sell the assets (or disposal groups).
Assets (or disposal groups) classified as held for sale and the associated liabilities are measured at the lower of their
carrying amount and fair value less disposal expenses.
In the classification of non-current assets as held for sale, provisions for decommissioning costs related to these assets
are also disclosed. Any commitments with decommissioning assumed by the Company resulting from the sale process
are recognized after the closing of the transaction, in accordance with the contractual terms.
29.3. Contingent assets from disposed investments and other transactions
Some disposed assets and other agreements provide for receipts subject to contractual clauses, especially related to
the Brent variation in transactions related to E&P assets. Information on sources of estimation uncertainty regarding
compensation for the Surplus Volume for the Transfer of Rights Agreement, partnerships and divestments are
described in note 4.11.
The transactions that may generate revenue recognition, accounted for within other income and expenses, are
presented below:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-95
Transaction
Closing date
Contingent
assets at
the closing
date
Assets
recognized
in 2024
Assets
recognized
in previous
periods
Balance of
contingent
assets as of
December
31, 2024
Surplus volume of the Transfer of Rights Agreement
Sepia and Atapu
August 2023
5,244
262
948
4,034
Sales in previous years
Riacho da Forquilha cluster
December 2019
62
−
58
4
Pampo and Enchova cluster
July 2020
650
57
246
347
Baúna field
November 2020
285
57
196
32
Miranga cluster
December 2021
85
15
70
−
Cricare cluster
December 2021
118
30
76
12
Peroá cluster
August 2022
43
−
10
33
Papa-Terra field
December 2022
90
16
16
58
Albacora Leste field
January 2023
250
167
58
25
Norte Capixaba cluster
April 2023
66
11
22
33
Golfinho and Camarupim clusters
August 2023
60
−
20
40
Total
6,953
615
1,720
4,618
(1) The amount recorded in other income and expenses, net is adjusted to present value (see note 11).
Sépia and Atapu
In 2022, Petrobras signed Production Individualization Agreements (AIPs) for Atapu and Sépia fields, according to the
results of the Second Bidding Round for the Surplus Volume of the Transfer of Rights Agreement in the Production
Sharing regime, which was held in 2021. Petrobras explores the Sépia field in a consortium with TotalEnergies (28%
interest), Petronas Petróleo Brasil Ltda. (21% interest) and QP Brasil Ltda. (21% interest), while the Atapu field is
explored in a consortium with Shell Brasil Petróleo Ltda (25% interest) and TotalEnergies EP Brasil Ltda. (22.5%
interest).
In addition to the amounts received by Petrobras in previous years following the signing of the AIPs, as established in
Ordinance No. 8/2021, whenever the price of Brent oil reaches an annual average ranging from US$ 40.00 to US$ 70.00,
an earnout is due to Petrobras, for which the Company expects to receive a maximum of US$ 5,244 between 2022 and
2032.
In 2024, the Company recognized, within the Statement of financial position, portions of these contingent assets,
amounting to US$ 262, of which: (i) US$ 161 relates to the earnout of 2025, which is expected to be received in 2026;
and (ii) US$ 101 for the update of the earnout of 2024, received in January 2025. In previous periods, the Company had
already recognized the total amount of US$ 948 within the Statement of financial position, of which US$ 255 was
recognized in 2023 and US$ 693 in 2022.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-96
30. Finance debt
30.1. Balance by type of finance debt
In Brazil
12.31.2024
12.31.2023
Banking market
2,828
2,262
Capital market
2,225
3,130
Development banks (1)
508
698
Others
2
1
Total
5,563
6,091
Abroad
Banking market
3,691
6,303
Capital market
12,265
14,384
Export credit agency
1,508
1,870
Others
135
153
Total
17,599
22,710
Total finance debt
23,162
28,801
Current
2,566
4,322
Non-current
20,596
24,479
(1) It includes BNDES and FINEP.
Current finance debt is composed of:
12.31.2024
12.31.2023
Short-term debt
10
4
Current portion of long-term debt
2,132
3,776
Accrued interest on short and long-term debt
424
542
Total
2,566
4,322
The capital market balance is mainly composed of US$ 11,723 in global notes issued abroad by the wholly owned
subsidiary PGF, as well as US$ 1,370 in debentures and US$ 778 in commercial notes issued by Petrobras in reais in
Brazil.
The balance in global notes has maturities between 2026 to 2115 and does not require collateral. Such financing was
carried out in dollars and pounds, 92% and 8%, of the total global notes, respectively.
The debentures and the commercial notes, with maturities between 2026 and 2037, do not require collateral and are
not convertible into shares or equity interests.
30.2. Changes in finance debt
In Brazil
Abroad
Total
Balance at December 31, 2023
6,090
22,711
28,801
Proceeds from finance debt
1,132
997
2,129
Repayment of principal (1)
(526)
(6,045)
(6,571)
Repayment of interest (1)
(418)
(1,505)
(1,923)
Accrued interest (2)
483
1,498
1,981
Foreign exchange/ inflation indexation charges
177
508
685
Translation adjustment
(1,375)
(565)
(1,940)
Balance at December 31, 2024
5,563
17,599
23,162
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-97
In Brazil
Abroad
Total
Balance at December 31, 2022
4,907
25,047
29,954
Proceeds from finance debt
925
1,285
2,210
Repayment of principal (1)
(331)
(3,907)
(4,238)
Repayment of interest (1)
(324)
(1,640)
(1,964)
Accrued interest (2)
436
1,822
2,258
Foreign exchange/ inflation indexation charges
111
(150)
(39)
Translation adjustment
383
254
637
Modification of contractual cash flows
(17)
-
(17)
Balance at December 31, 2023
6,090
22,711
28,801
(1) It includes pre-payments.
(2) It includes premium and discount over notional amounts, as well as gains and losses by modifications in contractual cash flows.
30.3. Reconciliation with cash flows from financing activities
2024
2023
Proceeds from
finance debt
Repayment of
principal
Repayment of
interest
Proceeds from
finance debt
Repayment of
principal
Repayment of
interest
Changes in finance debt
2,129
(6,571)
(1,923)
2,210
(4,238)
(1,964)
Discount on repurchase of debt securities
10
−
77
−
Deposits linked to finance debt (1)
25
5
(32)
(14)
Net cash used in financing activities
2,129
(6,536)
(1,918)
2,210
(4,193)
(1,978)
(1) Deposits linked to finance debt with China Development Bank, with semiannual settlements in June and December.
In 2024, the Company repaid several finance debts, in the amount of US$ 8,454, notably: (i) repurchase and withdrawal
of US$ 2,512 of securities in the international capital market; and (ii) the pre-payment of US$ 250 of loan in the
international banking market.
In the same period, the Company raised US$ 2,129, notably: (i) the issuance of Global Notes in the international capital
market in the amount of US$ 978, maturing in 2035; and (ii) proceeds in the domestic banking market, in the amount of
US$ 1,122.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-98
30.4. Summarized information on current and non-current finance debt
Maturity in
2025
2026
2027
2028
2029
2030
onwards
Total (1)
Fair Value
Financing in U.S. Dollars (US$):
2,182
1,464
2,146
1,544
602
8,495
16,433
15,947
Floating rate debt (2)
1,958
1,123
1,468
523
144
284
5,500
Fixed rate debt
224
341
678
1,021
458
8,211
10,933
Average interest rate p.a.
6.3%
6.5%
5.9%
5.5%
6.1%
6.6%
6.5%
Financing in Brazilian Reais (R$):
325
400
118
119
788
3,515
5,265
4,835
Floating rate debt (3)
170
112
30
30
30
3,029
3,401
Fixed rate debt
155
288
88
89
758
486
1,864
Average interest rate p.a.
9.6%
10.6%
10.7%
10.6%
10.1%
8.0%
9.6%
Financing in Euro (€):
21
−
−
128
23
371
543
543
Fixed rate debt
21
−
−
128
23
371
543
Average interest rate p.a.
4.5%
-
-
4.6%
4.7%
4.7%
4.6%
Financing in Pound Sterling (£):
38
−
−
−
367
516
921
888
Fixed rate debt
38
−
−
−
367
516
921
Average interest rate p.a.
6.1%
-
-
-
6.1%
6.6%
6.3%
Total as of December 31, 2024
2,566
1,864
2,264
1,791
1,780
12,897
23,162
22,213
Average interest rate
7.0%
7.4%
7.1%
6.9%
7.3%
6.6%
6.8%
Total as of December 31, 2023
4,322
3,066
2,551
2,547
1,816
14,499
28,801
29,329
Average interest rate
5.8%
5.8%
6.3%
6.1%
5.9%
6.5%
6.4%
(1) The average maturity of outstanding debt as of December 31, 2024 is 12.52 years (11.38 years as of December 31, 2023).
(2) Operations with variable index + fixed spread.
(3) Operations with variable index + fixed spread, if applicable.
The fair value of the Company's finance debt is mainly determined and categorized into a fair value hierarchy as follows:
•
Level 1- quoted prices in active markets for identical liabilities, when applicable, amounting to US$ 11,174 of
December 31, 2024 (US$ 13,971 of December 31, 2023); and
•
Level 2 – discounted cash flows based on discount rate determined by interpolating spot rates considering
financing debts indexes proxies, taking into account their currencies and also Petrobras’ credit risk, amounting
to US$ 11,039 as of December 31, 2024 (US$ 15,358 as of December 31, 2023).
Regarding the Interest Rate Benchmark Reform (IBOR Reform), there was a necessity to amend the Company's
contracts referenced in these indexes, considering the end of the publication of LIBOR (London Interbank Offered Rate)
in dollars (US$), of one, three and six months.
As of December 31, 2024, 18% of the Company's finance debt has been indexed to SOFR (Secured Overnight Financing
Rate) and has the CSA (Credit Spread Adjustment) negotiated with the creditors serving as a parameter.
The renegotiations performed have been solely for the replacement of the LIBOR benchmark and were necessary as a
direct consequence of the reform of the reference interest rate. In these renegotiated cash flows, the change of the
index was economically equivalent to the previous basis. Thus, the changes were prospective with the recognition of
interest at the new index in the applicable periods.
The sensitivity analysis for financial instruments subject to foreign exchange variation is set out in note 34.4.1.
A maturity schedule of the Company’s finance debt (undiscounted), including face value and interest payments is set
out as follows:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-99
Maturity
2025
2026
2027
2028
2029
2030 and
thereafter
12.31.2024
12.31.2023
Principal
2,158
1,903
2,308
1,899
1,982
13,223
23,473
29,181
Interest
1,549
1,461
1,271
1,088
1,043
13,976
20,388
22,541
Total (1)
3,707
3,364
3,579
2,987
3,025
27,199
43,861
51,722
(1) A maturity schedule of the lease arrangements (nominal amounts) is set out in note 31.
30.5. Lines of credit
12.31.2024
Company
Financial
institution
Date
Maturity
Available
(Lines of Credit)
Used
Balance
Abroad
PGT BV (1)
Syndicate of banks
12/16/2021
11/16/2026
5,000
−
5,000
PGT BV
Syndicate of banks
3/27/2019
2/27/2026
2,050
−
2,050
Total
7,050
−
7,050
In Brazil
Petrobras (2)
Banco do Brasil
3/23/2018
9/26/2030
323
−
323
Petrobras (3)
Banco do Brasil
10/4/2018
9/4/2029
646
−
646
Transpetro
Caixa Econômica Federal
11/23/2010
Not defined
53
−
53
Total
1,022
−
1,022
(1) On April 08, 2024, the Revolving Credit Facility was reduced to US$ 4,110 compared to the US$ 5,000 contracted in 2021. Thus, US$ 5,000 will be available for withdrawal
until November 16, 2026 and US$ 4,110 from November 16, 2026, to November 16, 2028.
(2) On December 27, 2024, the credit line agreement with Banco do Brasil for US$ 323 (R$ 2 billion) was amended, extending the term to October 26, 2030.
(3) On June 18, 2024, the credit line with Banco do Brasil was renewed, extending its term to September 4, 2029, and increasing its amount from US$ 323 (R$ 2 billion) to
US$ 646 (R$ 4 billion).
30.6. Covenants and Collateral
Covenants
The Company has covenants that were not in default at December 31, 2024 in its loan agreements and notes issued in
the capital markets requiring, among other obligations i) the presentation of interim financial statements within 90
days of the end of each quarter (not reviewed by Independent Registered Public Accounting Firm) and audited financial
statements within 120 days of the end of each fiscal year; ii) Negative Pledge / Permitted Liens clause.
Additionally, there are other non-financial obligations that the Company has to comply with: i) clauses of compliance
with the laws, rules and regulations applicable to the conduct of its business including (but not limited to)
environmental laws; (ii) clauses in financing agreements that require both the borrower and the guarantor to conduct
their business in compliance with anti-corruption laws and anti-money laundering laws and to institute and maintain
policies necessary for such compliance; and (iii) clauses in financing agreements that restrict relations with entities or
even countries sanctioned primarily by the United States (including, but not limited to, the Office of Foreign Assets
Control - OFAC, Department of State and Department of Commerce), the European Union and United Nations.
If the Company breaches any of the aforementioned covenants and either is incapable of remedy or continues to fail to
comply with the covenants for a period ranging from 30 to 60 calendar days (depending on the contract) after it has
received a written notice from the creditors specifying such default or breach and requiring it to be remedied and
stating that such notice is a “Notice of Default”, this may be declared an Event of Default, and in certain cases the debt
related to that contract becomes due and payable.
Collateral
Most of the Company’s debt is unsecured, but certain specific funding instruments to promote economic development
are collateralized. Such contracts represent 11.9% of the total financing, notably a Financing agreement with China
Development Bank (CDB).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-100
The loans obtained by structured entities are collateralized based on the projects’ assets, as well as liens on receivables
of the structured entities.
Bonds issued by the Company in the capital market are unsecured.
The global notes issued by the Company in the capital market through its wholly-owned subsidiary Petrobras Global
Finance B.V. – PGF are unsecured. However, Petrobras fully, unconditionally and irrevocably guarantees these notes.
Accounting policy for loans and finance debt
Loans and finance debt are initially recognized at fair value less transaction costs that are directly attributable to its
issue and subsequently measured at amortized cost using the effective interest method.
When the contractual cash flows of a financial liability measured at amortized cost are renegotiated or modified and
this change is not substantial, its gross carrying amount will reflect the discounted present value of its cash flows under
new terms using the original effective interest rate. The difference between the book value immediately prior to such
modification and the new gross carrying amount is recognized as gain or loss in the statement of income. When such
modification is substantial, the original liability is extinguished and a new liability is recognized, impacting the
statement of income of the period.
31. Lease liability
The Company is the lessee in agreements primarily including oil and gas producing units, drilling rigs and other
exploration and production equipment, vessels and support vessels, helicopters, land and buildings. Changes in the
balance of lease liabilities are presented below:
Lessors
in Brazil
Lessors
abroad
Total
Balance at December 31, 2023
6,792
27,007
33,799
Remeasurement / new contracts
1,589
8,128
9,717
Payment of principal and interest (1)
(2,649)
(5,192)
(7,841)
Interest expenses
529
1,765
2,294
Foreign exchange losses
716
6,986
7,702
Translation adjustment
(1,493)
(7,068)
(8,561)
Transfers
−
39
39
Balance at December 31, 2024
5,484
31,665
37,149
Current
8,542
Non-current
28,607
Lessors
in Brazil
Lessors
abroad
Total
Balance at December 31, 2022
6,020
17,825
23,845
Remeasurement / new contracts
2,276
12,094
14,370
Payment of principal and interest (1)
(2,273)
(3,999)
(6,272)
Interest expenses
519
1,290
1,809
Foreign exchange losses
(223)
(1,635)
(1,858)
Translation adjustment
472
1,531
2,003
Transfers
1
(99)
(98)
Balance at December 31, 2023
6,792
27,007
33,799
Current
7,200
Non-current
26,599
(1) The Statement of Cash Flows comprises US$ 54 (US$ 14 on December 31, 2023) relating to changes on liabilities held for sale.
A maturity schedule of the lease arrangements (nominal amounts) is set out as follows:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-101
Nominal Future Payments
2025
2026
2027
2028
2029
2030
onwards
Total
Recoverable
taxes
Without readjustment
Vessels
4,534
2,563
1,506
675
351
1,457
11,086
243
Others
192
124
99
54
12
−
481
44
With readjustment - abroad (1)
Vessels
333
312
282
64
42
24
1,057
−
Platforms
2,623
2,450
2,443
2,401
2,382
26,392
38,691
−
With readjustment - Brazil
Vessels
760
418
215
91
2
2
1,488
138
Properties
185
125
139
118
83
990
1,640
22
Others
210
148
133
73
32
78
674
62
Nominal amounts on December 31, 2024
8,837
6,140
4,817
3,476
2,904
28,943
55,117
509
Nominal amounts on December 31, 2023
7,442
6,137
4,547
3,367
2,708
25,939
50,140
690
(1) Contracts signed in the U.S. dollars.
The following table presents the main information on leases by class of underlying assets, where platforms and vessels
represent 95.4% of the lease liability:
Present Value of Future Payments (1)
Discount
rate (%)
Average
Period
(years)
Recovera
ble taxes 12.31.2024
12.31.2023
Without readjustment
Vessels
5.2316
4.5
243
9,875
8,311
Others
5.2350
3.3
44
440
264
With readjustment - abroad
Platforms
6.3660
18
−
23,292
20,336
Vessels
5.7706
3.3
−
964
1,127
With readjustment - Brazil
Vessels
11.0131
2.4
138
1,313
1,506
Properties
8.6458
22.8
22
734
1,230
Others
11.5059
4.5
62
531
1,025
Total (2)
6.0085
14.4
509
37,149
33,799
(1) Incremental nominal rate on company debt calculated from the yield curve of bonds and credit risk of the Company, as well as terms.
(2) Total amount, except for the average period column.
In certain contracts, there are variable payments and terms of less than 1 year recognized as expenses:
12.31.2024
12.31.2023
Variable payments
1,035
1,067
Up to 1 year maturity
96
109
Variable payments x fixed payments
13%
17%
At December 31, 2024, the nominal amounts of lease agreements for which the lease term has not commenced, as they
relate to assets under construction or not yet available for use, is US$ 65,034 (US$ 65,358 at December 31, 2023).
The sensitivity analysis of financial instruments subject to exchange variation is presented in note 33.4.1.
Accounting policy for lease liabilities
Lease liabilities, including those whose underlying assets are of low value, are measured at the present value of lease
payments, which includes recoverable taxes, non-cancellable periods and options to extend a lease when they are
reasonably certain. These payments are discounted at the Company's nominal incremental rate on loans, as the interest
rates implicit in lease agreements with third parties usually cannot be readily determined.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-102
Lease remeasurements reflect changes arising from contractual rates or indexes, as well as lease terms due to new
expectations of lease extensions or terminations.
Unwinding of discount on the lease liability is classified as finance expense, while payments reduce their carrying
amount. According to the Company’s foreign exchange risk management, foreign exchange variations on lease liabilities
denominated in U.S. dollars are designated as instruments to protect cash flow hedge relationships from highly
probable future exports (see note 33.4.1).
In the E&P segment, some activities are conducted by joint operations with partner companies where the Company is
the operator. In cases where all parties to the joint operation are primarily responsible for the lease payments, the
Company recognizes the lease liability in proportion to its share. When using underlying assets arising from a specific
contract in which the Company is solely responsible for the lease payments, the lease liabilities remain fully recognized
and the partners are charged in proportion to their interests.
Payments associated with short-term leases (term of 12 months or less) are recognized as an expense over the term of
the lease.
32. Equity
32.1. Share capital (net of share issuance costs)
As of December 31, 2024 and December 31, 2023, subscribed and fully paid share capital, net of issuance costs, was
US$ 107,101, represented by 7,442,454,142 common shares and 5,602,042,788 preferred shares, all of which are
registered, book-entry shares with no par value.
Preferred shares have priority on returns of capital, do not grant any voting rights and are non-convertible into common
shares.
32.2. Capital reserve
Capital reserve comprises treasury shares owned by Petrobras, in the amount of US$ 1, at December 31, 2024 and
December 31, 2023.
32.3. Capital transactions
32.3.1. Incremental costs directly attributable to the issue of shares
It includes any transaction costs directly attributable to the issuance of new shares, net of taxes.
32.3.2. Change in interest in subsidiaries
It includes any excess of amounts paid/received over the carrying value of the interest acquired/disposed. Changes in
interests in subsidiaries that do not result in loss of control of the subsidiary are equity transactions.
32.3.3. Treasury shares
Shares held in treasury in the amount of US$ 1,118, at December 31, 2024 and US$ 737 at December 31, 2023, are
represented by 222,760 common shares and 155,541,409 preferred shares.
On January 29, 2025, the Board of Directors approved the cancellation of all treasury shares, without reducing the share
capital (see note 36).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-103
32.4. Appropriation of net income
32.4.1. Profit reserves
The following table presents the final balance of profit reserves as disclosed in the Statements of changes in
shareholders’ equity:
Legal
R&D
reserve
Capital
remuneration
Tax
incentives
Profit
retention
Additional
dividends
proposed
Total
Balance at January 1, 2023
11,574
3,281
−
1,677
43,038
6,864
66,434
Additional dividends proposed
−
−
−
−
−
(6,864)
(6,864)
Transfer to reserves
1,272
116
8,428
321
−
−
10,137
Dividends
−
−
−
−
−
2,934
2,934
Balance at December 31, 2023
12,846
3,397
8,428
1,998
43,038
2,934
72,641
Balance at January 1, 2024
12,846
3,397
8,428
1,998
43,038
2,934
72,641
Additional dividends proposed
−
−
(4,244)
−
−
(2,934)
(7,178)
Transfer to reserves
−
−
−
130
−
−
130
Dividends
−
−
(4,184)
−
(1,440)
1,477
(4,147)
Balance at December 31, 2024
12,846
3,397
−
2,128
41,598
1,477
61,446
Legal reserve
It represents the accumulated balance of 5% of the net income for each year, calculated pursuant to article 193 of the
Brazilian Corporation Law, limited to 20% of the share capital (calculated in Brazilian reais). The balance of this reserve
may only be used to compensate losses or increase capital and reached the legal limit on December 31, 2023.
Statutory reserves
In accordance with the Company's Bylaws, the constitution of the statutory reserves below must be considered in the
proposal for distribution of net income, observing the following order of priority:
•
Reserve for research and development (R&D): constituted with the appropriation of net income by applying 0.5% of
the year-end share capital, with the accumulated balance not exceeding 5% of the share capital, aiming at funding
technological R&D programs. The balance of this reserve reached the limit on December 31, 2023.
•
Capital remuneration reserve: may be constituted through the appropriation of up to 70% of the adjusted net
income for the year, subject to article 202 of the Brazilian Corporation Law and to the Shareholders Remuneration
Policy, limited to the share capital, with the purpose of ensuring resources for the payment of dividends, interest
on capital or other form of shareholder remuneration provided for by law, its anticipations, shares repurchases
authorized by law, absorption of losses and, as a remaining purpose, incorporation into the share capital.
Tax incentives reserve
Government grants are recognized in the statement of income and are appropriated from retained earnings to the tax
incentive reserve pursuant to article 195-A of Brazilian Corporation Law. This reserve may only be used to offset losses
or increase share capital.
As of December 31, 2024, this reserve referring to a subsidy incentive for investments, granted by the
Superintendencies for Development of the Northeast Region of Brazil (SUDENE) and of the Amazon (SUDAM).
Profit retention reserve
It includes funds intended for capital expenditures, primarily in oil and gas exploration and development activities, as
per the capital budget of the Company, pursuant to article 196 of the Brazilian Corporation Law.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-104
32.4.2. Distributions to shareholders
Distributions to shareholders are made by means of dividends, interest capital and share repurchases based on the
limits defined in the Brazilian Corporation Law, in the Company’s bylaws and in the shareholders remuneration policy.
Pursuant to Brazilian Corporation Law, the Company’s shareholders are entitled to receive minimum mandatory
dividends (and/or interest on capital) of 25% of the adjusted net income for the year in proportion to the number of
common and preferred shares held by them.
To the extent the Company proposes dividend distributions, preferred shares have priority in dividend distribution,
which is based on the highest of 3% of the preferred shares’ net book value or 5% of the preferred share capital.
Preferred shares participate under the same terms as common shares in capital increases resulting from the
capitalization of profit reserves or retained earnings. However, this priority does not necessarily grant dividend
distributions to the preferred shareholders in the event of loss for a year.
The payment of dividends may be made only to preferred shareholders if the priority dividends absorb all the adjusted
net income for the year or reach an amount equal to or greater than the mandatory minimum dividend of 25%.
a) Shareholders Remuneration Policy
The Company’s policy on distributions to shareholders, approved by the Company’s Board of Directors on July 28, 2023,
defines the following:
•
minimum distribution of US$ 4,000 for fiscal years when the average Brent price exceeds US$ 40 per barrel, which
shall be distributed regardless of its level of indebtedness, provided that the parameters set forth in the policy are
observed. This distribution will be equal to both common and preferred shares, once it exceeds the minimum value
for preferred shares provided for in the Company's bylaws;
•
in the event of gross debt (comprising current and non-current finance debt and lease liability) equal to or less
than the maximum debt level defined in the strategic plan (US$ 75,000 in the 2025-2029 Business Plan), in addition
to the existence of net income attributable to shareholders of Petrobras, to be verified at the end of the year, the
Company shall distribute to its shareholders 45% of the difference between consolidated net cash provided by
operating activities and consolidated cash used in the acquisition of PP&E and intangible assets and on the
acquisition of equity interests, calculated in Brazilian reais, provided that the result of this calculation exceeds
US$ 4,000 and does not compromise the financial sustainability of the Company. This calculation will be applied on
a quarterly basis;
•
any amounts related to share repurchases, as disclosed in the consolidated statement of cash flows, are be
deducted from the amount resulting of the formula applied each quarter;
•
the Company may, in exceptional cases, distribute extraordinary remuneration to its shareholders, higher than the
minimum mandatory dividends or than the amount calculated according to this policy, provided that the financial
sustainability of the Company is preserved;
•
the distribution of remuneration to shareholders shall be made on a quarterly basis;
•
the Company may exceptionally distribute dividends even if there is no net income for the year, in accordance with
the rules provided for the Brazilian Corporation Law and the criteria defined in this policy.
Petrobras seeks, through its shareholders remuneration policy, to ensure short, medium and long-term financial
sustainability, providing predictability to the dividend payments to shareholders.
b) Share Repurchase Program
On August 3, 2023, the Board of Directors approved a Share Repurchase Program, for the acquisition of up to
157.8 million preferred shares issued by the Company, on the Brazilian Stock Exchange (B3), to be held in treasury with
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-105
subsequent cancellation, without reduction of share capital. This program was carried in the scope of the revised
Shareholders Remuneration Policy.
On August 4, 2024, the Program was closed, resulting in the repurchase of 155,468,500 preferred shares in the amount
of US$ 1,116, including transaction costs (US$ 407 thousand), of which:
i.
104,064,000 preferred shares repurchased from August to December 2023 in the amount of US$ 735 (including
transaction costs); and
ii.
51,404,500 preferred shares repurchased from January to June 2024 in the amount of US$ 381 (including
transaction costs).
On January 29, 2025, the Board of Directors approved the cancellation of all treasury shares, without reducing the share
capital (see note 36).
c) Proposed remuneration to the shareholders of Petrobras
For 2024, the proposed remuneration to the shareholders of Petrobras amounts to US$ 13,457, was based on the
shareholders remuneration policy of 45% of the free cash flow (calculated in Brazilian Reais), including the share
repurchase program, and the additional dividends proposed.
2024
2023
Dividends and interest on capital (1)
13,076
14,754
Share repurchase program (2)
381
735
Total capital remuneration reserve
13,457
15,489
(1) The Annual General Shareholders Meeting held in April 2024 changed the original Board of Administration’s proposal (see note 32.4.2.e).
(2) It excludes transaction costs on the repurchase of shares.
d) Anticipation of dividends relating to 2024
In 2024, the Board of Directors approved the anticipation of dividends and interest on capital in the total amount of
US$ 11,493 (R$64,139 million), equivalent to US$ 0,8917 (R$ 4,976) per common and preferred shares, based on the net
income of the period from January to September 2024 (interim), as well on the use of profit reserves, as shown in the
following table:
Date of
approval
by the Board
of Directors
Date of
record
Amount per
common and
preferred share
Amount
Interim dividends and interest on capital - 1st quarter of 2024 (1)
05.13.2024
06.11.2024
0.2029
2,615
Interim dividends and interest on capital - 2nd quarter of 2024
08.08.2024
08.21.2024
0.1875
2,417
Interim dividends and interest on capital - 3rd quarter of 2024
11.07.2024
12.23.2024
0.2346
3,023
Additional dividends proposed
11.21.2024
12.11.2024
0.2668
3,438
Total anticipated of remuneration to the shareholders of Petrobras
0.8917
11,493
Update by the SELIC interest rate (2)
0.0082
106
Total updated anticipated dividends
0.9000
11,599
Interim dividends and interest on capital by use of a portion of profit and loss
7,452
Interim dividends and interest on capital by use of a portion of profit retention reserve
4,147
(1) The amount of dividends and interest on capital per share was updated due to the share repurchase program, which reduced the number of outstanding shares.
(2) The amount of update by the SELIC interest rate on capital per share was calculated based on shares outstanding on December 31, 2024.
According to the Company’s bylaws, these amounts are indexed to the Selic interest rate, from the date of the payment
to the end of the fiscal year (US$ 106) and are considered in determining the remaining dividends to be paid relating to
2024.
The interest on capital anticipated for the year 2024 resulted in a deductible expense which reduced the income tax
expense by US$ 1,319. This amount was subject to withholding income tax (IRRF) of 15%, except for immune and exempt
shareholders, as established in applicable law.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-106
e) Proposed dividends for 2024
The Dividends for 2024, proposed by management for approval at the Annual General Shareholders Meeting, amounts
to US$ 13,076 (US$ 1.0146 per outstanding share), including the minimum mandatory dividend of 25% of the adjusted
net income (US$ 1,446) and additional dividends proposed of US$ 6,006 arising from the remaining portion of retained
earnings, in addition to US$ 5,624 arising from the capital remuneration and profit retention reserves. This proposal is
superior to the priority of preferred shares and in accordance with the shareholders remuneration policy.
In relation to the dividends for 2023, on April 25, 2024, shareholders approved, at the Annual General Shareholders
Meeting, a change to the management's original proposal made on March 7, 2024, which had been based in the
application of the Shareholder Remuneration Policy formula (US$ 14,754).The total amount was adjusted to include the
distribution of 50% of the remaining net income that had been appropriated to the capital remuneration reserve as an
extraordinary dividend (US$ 4,244). Therefore, the total dividends for 2023 approved at the Annual General
Shareholders Meeting is US$ 18,998 (equivalent to US$ 1.4634 per outstanding preferred and common share).
f) Dividends payable
As of December 31, 2024, dividends payable within current liabilities, amounting to US$ 2,657, net of withholding
income taxes over interest on capital US$ 385, relate to the anticipation of dividend approved on November 7, 2024,
related to the third quarter of 2024. The first installment of these dividends was paid on February 20, 2025 and the
second installment was paid on March 20, 2025.
Changes in the balance of dividends payable are set out as follows:
2024
2023
Consolidated opening balance of dividends payable
3,539
4,171
Opening balance of dividends payable to non-controlling shareholders
38
2
Opening balance of dividends payable to shareholders of Petrobras
3,501
4,169
Additions relating to complementary dividends
7,178
6,864
Additions relating to anticipated dividends
11,493
11,605
Payments made
(18,327)
(19,670)
Indexation to the Selic interest rate
385
512
Transfers to unclaimed dividends
(64)
(84)
Withholding income taxes over interest on capital and indexation to the Selic interest rate
(383)
(410)
Translation adjustment
(1,145)
515
Closing balance of dividends payable to shareholders of Petrobras
2,638
3,501
Closing balance of dividends payable to non-controlling shareholders
19
38
Consolidated closing balance of dividends payable
2,657
3,539
Additional dividends proposed, amounting to US$ 1,477 (US$ 0.1146 per outstanding share), will be maintained in
shareholders' equity until its approval on the Annual General Shareholders Meeting, expected to be held in April 2025,
when it will be reclassified to liabilities, if approved.
32.4.3. Unclaimed Dividends
As of December 31, 2024, the balance of dividends not claimed by shareholders of Petrobras is US$ 276, recorded as
other current liabilities, as described in note 21 (US$ 337 as of December 31, 2023). The payment of these dividends was
not carried out due to the lack of registration data for which the shareholders are responsible with the custodian bank
for the Company's shares.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-107
2024
2023
Changes in unclaimed dividends
Opening balance
337
241
Prescription
(54)
(7)
Transfers from dividends payable
64
84
Translation adjustment
(71)
19
Closing Balance
276
337
Prescribed dividends amounting to US$ 54 in 2024 were transferred to equity, within retained earnings.
The following table presents the Company’s expectation of prescription of unclaimed dividends if missing registration
data is uninformed by shareholders of Petrobras.
12.31.2024
Expectation of prescription of unclaimed dividends
2025
136
2026
68
2027
72
276
Accounting policy on distributions to shareholders
Interest on capital is a deductible expense, since it is part of the dividend for the year, as provided for in the Company’s
bylaws, and accounted for in the statement of income, as required by tax legislation, resulting in a tax credit for income
taxes recognized in the statement of income of the year.
The dividends portion provided for in the bylaws or that represents the minimum mandatory dividends is recognized as
a liability within the statement of financial position. Any excess must be maintained in shareholders' equity, as
additional dividends proposed, until its approval on the Annual General Shareholders Meeting.
Dividends not claimed by Petrobras’ shareholders are transferred from dividends payable to other current liabilities.
After 3 years from the date these dividends are made available to shareholders, they are reclassified from other current
liabilities to equity within retained earnings, in accordance with Petrobras' bylaws.
32.5. Earnings per share
2024
2023
2022
Common
Preferred
Total
Common
Preferred
Total
Common
Preferred
Total
Net income
attributable to
shareholders of
Petrobras
4,343
3,185
7,528
14,221
10,663
24,884
20,895
15,728
36,623
Weighted average
number of
outstanding
shares
7,442,231,382 5,456,530,746 12,898,762,128 7,442,231,382 5,580,057,862 13,022,289,244 7,442,231,382 5,601,969,879 13,044,201,261
Basic and diluted
earnings per share
- in U.S. dollars
0.58
0.58
0.58
1.91
1.91
1.91
2.81
2.81
2.81
Basic and diluted
earnings (losses)
per ADS
equivalent - in U.S.
dollars (1)
1.16
1.16
1.16
3.82
3.82
3.82
5.62
5.62
5.62
(1) Petrobras' ADSs are equivalent to two shares.
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-108
Basic earnings per share are calculated by dividing the net income (loss) attributable to shareholders of Petrobras by
the weighted average number of outstanding shares during the period. The change in the weighted average number of
outstanding shares is due to the Share repurchase program (preferred shares) which was closed on August 4, 2024.
Diluted earnings per share are calculated by adjusting the net income (loss) attributable to shareholders of Petrobras
and the weighted average number of outstanding shares during the period taking into account the effects of all dilutive
potential shares (equity instrument or contractual arrangements that are convertible into shares).
Basic and diluted earnings are identical as the Company has no potentially dilutive shares.
33. Financial risk management
The Company is exposed to a variety of risks arising from its operations, including price risk (related to crude oil and oil
products prices), foreign exchange rates risk, interest rates risk, credit risk and liquidity risk. Corporate risk
management is part of the Company’s commitment to act ethically and comply with the legal and regulatory
requirements of the countries where it operates.
To manage market and financial risks the Company prefers structuring measures through adequate capital and
leverage management. While managing risks, the Company considers its corporate governance and controls, technical
departments and statutory committees monitoring, under the guidance of the Board of Executive Officers and the
Board of Directors. The Company takes risks into account in its business decisions and manages any such risk in an
integrated manner to take advantage of the benefits of diversification.
In its corporate risk management process, Petrobras maintains derivative financial instruments to hedge its exposures
to market risks on certain occasions and designates certain U.S. dollar obligations and highly probable future exports
as hedge accounting relationships to protect against exchange rate variations.
The Company presents a sensitivity analysis for the period of one year, except for operations with commodity
derivatives, for which a three-month period is applied, due to the short-term nature of these transactions.
The effects of derivative financial instruments and hedge accounting are set out as follows.
33.1. Statement of income
Gains/ (losses) recognized in the
statement of income
2024
2023
2022
Exchange rate risk
Cross-currency Swap CDI x Dollar - Note 33.4.1 (b)
(96)
81
211
Cash flow hedge on exports - Note 33.4.1 (a)
(2,992)
(3,763)
(4,871)
Interest rate risk
Swap Pounds sterling x dollar
−
−
(297)
Swap IPCA X CDI - 33.4.1 (b)
(78)
25
(50)
Others
−
−
5
Recognized in Net finance income (expense)
(3,166)
(3,657)
(5,002)
Price risk (commodity derivatives)
Recognized in other income and expenses
42
11
(256)
Total
(3,124)
(3,646)
(5,258)
The effects on the statement of income of derivative financial instruments reflect outstanding transactions and
transactions closed during the years.
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-109
33.2. Statement of comprehensive income
Gains/ (losses) recognized in the statement of comprehensive income
2024
2023
2022
Hedge accounting
Cash flow hedge on exports - Note 33.4.1 (a)
(12,635)
8,317
10,094
Deferred income taxes
4,295
(2,830)
(3,432)
Total
(8,340)
5,487
6,662
33.3. Statement of Financial Position
12.31.2024
12.31.2023
Fair value Asset Position (Liability)
Open derivatives transactions
(101)
20
Closed derivatives transactions awaiting financial settlement
1
10
Recognized in Statements of Financial Position
(100)
30
Other assets (note 21)
29
92
Other liabilities (note 21)
(129)
(62)
The following table presents the details of the open derivative financial instruments held by the Company as of
December 31, 2024, and represents its risk exposure:
Statement of Financial Position
Fair value
Fair value
hierarchy
Maturity
Notional value
Asset Position (Liability)
12.31.2024
12.31.2023
12.31.2024
12.31.2023
Derivatives not designated for hedge accounting
Exchange Risk (1)
Cross-currency swap - CDI x US$
488
729
(105)
(49)
Level 2
2029
Short position/Foreign currency forwards (BRL/USD)
(20)
(1)
-
−
Level 2
2025
Interest rate risk
-
-
Swap - IPCA X CDI
R$ 3,008
R$ 3,008
17
68
Level 2
2029/2034
Price risk
−
−
Future contracts - Crude oil and oil products (2)
(1,450)
(1,053)
(13)
1
Level 1
2025
Swap - Short position/Soybean oil (3)
−
(1)
−
−
Level 2
-
Total open derivative transactions
(101)
20
(1) Amounts in US$ and R$ are presented in million.
(2) Notional value in thousands of bbl.
(3) Notional value in thousands of tons.
Commercial derivatives require guarantees, accounted for as other assets and/or other liabilities.
Guarantees given as collateral
31.12.2024
12.31.2023
Commodity derivatives
69
18
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-110
Equity
Cumulative losses in other comprehensive income (shareholders’ equity)
2024
2023
2022
Hedge accounting
Cash flow hedge on exports - Note 33.4.1 (a)
(30,845)
(18,210)
(26,527)
Deferred income taxes
10,485
6,190
9,020
Total
(20,360)
(12,020)
(17,507)
33.4. Market risks
33.4.1. Foreign exchange risk management
By managing its foreign exchange risk, the Company takes into account the cash flows derived from its operations as a
whole. This concept is especially applicable to the risk relating to the exposure of the Brazilian Real against the U.S.
dollar, in which future cash flows in U.S. dollar, as well as cash flows in Brazilian Real affected by the fluctuation between
both currencies, such as cash flows derived from diesel and gasoline sales in the domestic market, are assessed in an
integrated manner.
Accordingly, the financial risk management mainly involves structured actions encompassing the business of the
Company.
Changes in the Real/U.S. dollar spot rate, as well as foreign exchange variation of the Real against other foreign
currencies, may affect net income and the statement of financial position due to the exposures in foreign currencies,
such as high probable future transactions, monetary items and firm commitments.
The Company seeks to mitigate the effect of potential variations in the Real/U.S. dollar spot rates mainly raising funds
denominated in U.S. dollars, aiming at reducing the net exposure between obligations and receipts in this currency, thus
representing a form of structural protection that takes into account criteria of liquidity and cost competitiveness.
Foreign exchange variation on future exports denominated in U.S. Dollar in a given period are efficiently hedged by the
U.S. dollar debt portfolio taking into account changes in such portfolio over time. Cash flow hedge involving the
Company’s future exports are presented in note 34.4.1(a).
The foreign exchange risk management strategy may involve the use of derivative financial instruments to hedge
certain liabilities, mitigating foreign exchange rate risk exposure, especially when the Company is exposed to a foreign
currency in which no cash inflows are expected. The positions with exchange rate derivatives are presented in note 34.3.
In the short-term, the foreign exchange risk is managed by applying resources in cash or cash equivalent denominated
in Brazilian Real, U.S. dollar or in another currency.
a)
Cash Flow Hedge involving the Company’s future exports
The Company uses hedge accounting for the risk arising from exchange rate variations of “highly probable future
exports” (hedged item) by means of foreign exchange rate variations of proportions of certain obligations denominated
in U.S. dollars (hedging instruments).
The carrying amounts, the fair value as of December 31, 2024, and a schedule of expected reclassifications to the
statement of income of cumulative losses recognized in other comprehensive income (shareholders’ equity) based on
a US$ 1.00 / R$ 6.1923 exchange rate are set out below:
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-111
Present value of hedging instrument notional value at
12.31.2024
Hedging Instrument
Hedged Transactions
Nature
of the Risk
Maturity
Date
US$ million
R$ million
Foreign exchange gains and losses
on proportion of non-derivative
financial instruments cash flows
Foreign exchange gains and losses
of highly probable future monthly
exports revenues
Foreign Currency
– Real vs U.S. Dollar
Spot Rate
January
2025 to
December
2034
65,900
408,073
Changes in the present value of hedging instrument notional value
US$ million
R$ million
Amounts designated as of December 31, 2023
65,138
315,350
Additional hedging relationships designated, designations revoked and hedging instruments re-designated
18,993
104,302
Exports affecting the statement of income
(9,767)
(52,126)
Principal repayments / amortization
(8,464)
(46,114)
Foreign exchange variation
-
86,661
Amounts designated as of December 31, 2024
65,900
408,073
Nominal value of hedging instrument (finance debt and lease liability) at December 31, 2024
84,690
524,425
In 2024, the Company recognized a US$ 208 loss within foreign exchange gains (losses) due to ineffectiveness (a
US$ 172 gain in the same period of 2023).
The average ratio of future exports for which cash flow hedge accounting was designated to the highly probable future
exports is 69.11%.
A roll-forward schedule of cumulative foreign exchange losses recognized in equity to be realized by future exports is
set out below:
2024
2023
Opening balance
(18,210)
(26,527)
Recognized in equity
(15,627)
4,554
Reclassified to the statement of income
2,992
3,763
Other comprehensive income (loss)
(12,635)
8,317
Closing balance
(30,845)
(18,210)
Additional hedging relationships may be revoked or additional reclassification adjustments from equity to the
statement of income may occur as a result of changes in forecasted export prices and export volumes following future
revisions of the Company’s business plans. Based on a sensitivity analysis considering a US$ 10/barrel decrease in Brent
prices stress scenario, when compared to the Brent price projections in the Business Plan 2025-2029, would not indicate
a reclassification from equity to the statement of income.
A schedule of expected reclassification of cumulative foreign exchange losses recognized in other comprehensive
income to the statement of income as of December 31, 2024, is set out below:
2025
2026
2027
2028
2029
2030
onwards
Total
Expected realization
(5,557)
(5,697)
(5,766)
(4,497)
(3,658)
(5,670)
(30,845)
Accounting policy for hedge accounting
At inception of the hedge relationship, the Company documents its objective and strategy, including identification of
the hedging instrument, the hedged item, the nature of the hedged risk and evaluation of hedge effectiveness
requirements.
Considering the natural hedge and the risk management strategy, the Company designates hedging relationships to
account for the effects of the existing hedge between a foreign exchange gain or loss from proportions of its long-term
debt obligations (denominated in U.S. dollars) and foreign exchange gain or loss of its highly probable U.S. dollar
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-112
denominated future exports revenues, so that gains or losses associated with the hedged transaction (the highly
probable future exports) and the hedging instrument (debt obligations) are recognized in the statement of income in
the same periods.
Foreign exchange gains and losses on proportions of debt obligations and lease liability (non-derivative financial
instruments) have been designated as hedging instruments.
The highly probable future exports for each month are hedged by a proportion of the debt obligations with an equal US
dollar nominal amount. Only a portion of the Company’s forecast exports are considered highly probable.
The Company’s future exports are exposed to the risk of variation in the Brazilian Real/U.S. dollar spot rate, which is
offset by the converse exposure to the same type of risk with respect to its debt denominated in U.S. dollar.
The hedge relationships are assessed on a monthly basis and they may cease and may be re-designated in order to
achieve the risk management strategy.
Foreign exchange gains and losses relating to the effective portion of such hedges are recognized in equity, within other
comprehensive income and reclassified to the statement of income within finance income (expense) in the periods when
the hedged item affects the statement of income.
Whenever a portion of future exports for a certain period, for which their foreign exchange gains and losses hedging
relationship has been designated is no longer highly probable, the Company revokes the designation and the
cumulative foreign exchange gains or losses that have been recognized in other comprehensive income remain
separately in equity until the forecast exports occur.
If future exports for which foreign exchange gains and losses hedging relationship has been designated is no longer
expected to occur, any related cumulative foreign exchange gains or losses that have been recognized in other
comprehensive income from the date the hedging relationship was designated to the date the Company revoked the
designation is immediately recycled from other comprehensive income to the statement of income.
In addition, when a financial instrument designated as a hedging instrument expires or settles, the Company may
replace it with another financial instrument in a manner in which the hedge relationship continues to occur. Likewise,
whenever a hedged transaction effectively occurs, its financial instrument previously designated as a hedging
instrument may be designated for a new hedge relationship.
Gains or losses relating to the ineffective portion are immediately recognized in finance income (expense).
Ineffectiveness may occur as hedged items and hedge instruments have different maturity dates and due to discount
rate used to determine their present value.
b)
Derivative financial instruments not designated for hedge accounting
In September 2019, Petrobras contracted a cross-currency swap aiming to protect against exposure arising from the
7th issuance of debentures, for IPCA x CDI operations, maturing in September 2029 and September 2034, and US$ 240
for CDI x U.S. Dollar operations, maturing in September 2024 and September 2029. In September 2024, the notional
amount of the matured cross-currency swap was US$ 241.
The methodology used to calculate the fair value of this swap operation consists of calculating the future value of the
operations, using rates agreed in each contract and the projections of the interest rate curves, IPCA coupon and foreign
exchange coupon, discounting to present value using the risk-free rate. Curves are obtained from Bloomberg based on
forward contracts traded in stock exchanges.
The mark-to-market is adjusted to the credit risk of the financial institutions, which is not relevant in terms of financial
volume, since the Company makes contracts with highly rated banks.
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-113
Changes in interest rate forward curves (CDI interest rate) may affect the Company's results, due to the market value
of these swap contracts. In preparing a sensitivity analysis for these curves, a parallel shock was estimated based on
the average maturity of these swap contracts, in the scope of the Company’s Risk Management Policy, which resulted
in a 618 basis points effect on the estimated interest rate. The effect of this sensitivity analysis, keeping all other
variables constant, is shown in the following table:
Financial Instruments
Reasonably possible
scenario
SWAP CDI x USD
(10)
c)
Sensitivity analysis for foreign exchange risk on financial instruments
The sensitivity analysis only covers the exchange rate variation and maintains all other variables constant. The probable
scenario is referenced on external sources like Focus bulletin and Thomson Reuters, making use of the exchange rate
forecast for the end of the following year, as follows:
• U.S. dollar x real - a 3.15% appreciation of the real;
• euro x U.S. dollar - a 1.03% depreciation of the euro;
• pound sterling x U.S. dollar - a 1.32% depreciation of the pound sterling.
The reasonably possible scenario has the same references and considers the risk of depreciation of a 20% depreciation
of the closing exchange rate of the year against the reference currency, except for assets and liabilities of foreign
subsidiaries, when transacted in a currency equivalent to their respective functional currencies.
Risk
Financial Instruments
Exposure at
12.31.2024
Exposure in R$
million
Probable
Scenario
Reasonably
possible
scenario
Dollar/Real
Assets
7,616
47,159
(240)
1,523
Liabilities
(113,943)
(705,569)
3,594
(22,789)
Exchange rate - Cross currency swap
(488)
(3,023)
15
(98)
Cash flow hedge on exports
65,900
408,073
(2,078)
13,180
Total
(40,915)
(253,360)
1,291
(8,184)
Euro/Dollar
Assets
941
5,824
10
188
Liabilities
(1,552)
(9,611)
(16)
(310)
Total
(611)
(3,787)
(6)
(122)
Pound/Dollar
Assets
934
5,784
12
187
Liabilities
(1,841)
(11,402)
(24)
(368)
Total
(907)
(5,618)
(12)
(181)
Pound/Real
Assets
21
131
4
(2)
Liabilities
(42)
(257)
1
(8)
Total
(21)
(126)
5
(10)
Total at December 31, 2024
(42,454)
(262,891)
1,278
(8,497)
33.4.2. Risk management of products prices - crude oil and oil products and other commodities
The Company is exposed to commodity price cycles, and it may use derivative instruments to hedge exposures related
to prices of products purchased and sold to fulfill operational needs and in specific circumstances depending on
business environment analysis and assessment of whether the targets of the Business Plan are being met.
The Company, by use of its assets, positions and market knowledge from its operations in Brazil and abroad, may seek
to optimize some of its commercial operations in the international market, with the use of commodity derivatives to
manage price risk.
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-114
The probable scenario uses market references, used in pricing models for oil, oil products and natural gas markets, and
takes into account the closing price of the asset on December 31, 2024. Therefore, no effect is considered arising from
outstanding operations in this scenario. The reasonably possible scenario reflects the potential effects on the
statement of income from outstanding transactions, considering a variation in the closing price of 20%. To simulate the
most unfavorable scenarios, the variation was applied to each asset according to open transactions: price decrease for
long positions and increase for short positions.
Financial Instruments
Risk
Probable
scenario
Reasonably
possible
scenario
Derivatives not designated for hedge accounting
Crude oil and oil products - price changes
Future and forward contracts (Swap)
−
(148)
Soybean oil - price changes
Future and forward contracts (Swap)
−
-
Foreign currency - depreciation BRL x USD
Forward contracts
−
(2)
−
(150)
The positions with commodity derivatives are presented in note 33.3.
33.4.3. Interest rate risk management
The Company considers that interest rate risk does not create a significant exposure and therefore, preferably does not
use derivative financial instruments to manage interest rate risk, except for specific situations faced by certain
subsidiaries of Petrobras.
In this sensitivity analysis, the probable scenario represents the amounts to be disbursed by Petrobras relating to the
payment of interests on debts linked to floating rates as of December 31, 2024. The reasonably possible scenario
represents the disbursement if there is a 40% change on these rates, keeping all other variables constant.
Risk
Sensitivity
effect on
the results
Reasonably
possible
scenario
Finance debt
SOFR 3M (1)
93
120
SOFR 6M (1)
90
106
SOFR O/N (1)
140
195
CDI
401
562
TR
5
6
TJLP
52
73
IPCA
68
95
849
1,157
(1) It represents the Secured Overnight Financing Rate (note 24.4).
33.5. Liquidity risk management
The possibility of a shortage of cash to settle the Company’s obligations on the agreed dates is managed by the
Company. The Company mitigates its liquidity risk by defining reference parameters for treasury management and by
periodically analyzing the risks associated to the projected cash flow, quantifying its main risks through Monte Carlo
simulations. These risks include oil prices, exchange rates, gasoline and diesel international prices, among others. In this
way, the Company is able to predict cash needs for its operational continuity and for the execution of its strategic plan.
Management believes that its current working capital is sufficient for the Company's present requirements. In the event
that the Company presents a negative net working capital, management believes it does not compromise the
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-115
Company's liquidity since Petrobras maintains revolving credit facilities contracted as a liquidity reserve to be used in
adverse scenarios (see note 30.5).
Additionally, the Company regularly assesses market conditions and may enter into transactions to repurchase its own
securities or those of its subsidiaries, through a variety of means, including tender offers, make whole exercises and
open market repurchases, since they are in line with the Company's liability management strategy, in order to improve
its debt repayment profile and cost of debt.
The expected cash flows from finance debt, lease liabilities, post-employment benefits and decommissioning costs are
presented in notes 30.4 and 31, 18.3.4 and 20, respectively.
33.6. Credit risk
Credit risk management in Petrobras aims to mitigate risk of not collecting receivables, financial deposits or collateral
from third parties or financial institutions through the analysis, granting and management of credit, based on
quantitative and qualitative parameters that are appropriate for each market segment in which the Company operates.
The commercial credit portfolio is broad and diversified and comprises clients from the domestic and foreign markets.
Credit granted to financial institutions is related to collaterals received, cash surplus invested and derivative financial
instruments. It is spread among “investment grade” international banks rated by international rating agencies and
Brazilian banks with low credit risk.
33.6.1. Credit quality of financial assets
a)
Cash and cash equivalents and marketable securities
The evaluation of the credit quality of these financial assets is based on external credit ratings provided by Standard &
Poor’s, Moody’s and Fitch, as follows:
Cash and cash
i
l
Marketable securities
12.31.2024
12.31.2023
12.31.2024
12.31.2023
Investment grade – global rating
1,413
7,503
1,875
1,115
AA
315
593
876
651
A
1,098
6,890
999
464
BBB
−
20
−
−
Other ratings abroad
215
3,251
1,026
−
Investment grade - local rating (Brazil)
1,642
1,966
1,944
4,113
AAA.br
1,642
1,966
1,944
4,113
Other ratings in Brazil
1
7
−
−
3,271
12,727
4,845
5,228
As of December 31, 2024, the Brazilian sovereign risk is BB, the best level within the speculative grade category, with
effect on the rating of Brazilian banks abroad, which represent most of the Company’s balance of other ratings abroad,
including cash.
These financial assets, which are not past due nor considered to be credit impaired, present fair values equivalent to or
do not differ significantly from their carrying amounts.
NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-116
b)
Trade and other receivables
Most of Petrobras's clients do not have a risk rating granted by rating agencies. Thus, for the definition and monitoring
of credit limits, management evaluates the customer's field of activity, commercial relationship, financial relationship
with Petrobras and its financial statements, among other aspects.
More information on the effect of this risk assessment is available in notes 14.2 and 14.3, which present the provision
for expected credit losses and the respective accounting policy.
34. Related-party transactions
The Company has a related-party transactions policy, which is annually revised and approved by the Board of Directors
in accordance with the Company’s bylaws.
In order to ensure the goals of the Company are achieved and to align them with transparency of processes and
corporate governance best practices, this policy guides Petrobras while entering into related-party transactions and
dealing with potential conflicts of interest on these transactions, based on the following assumptions and provisions:
competitiveness, compliance, transparency, fairness and commutability.
The Statutory Audit Committee (CAE) must approve in advance transactions between the Company and: i) the Brazilian
Federal Government, including its agencies or similar bodies; ii) Petros Foundation; iii) Petrobras Health Association;
iv) entities controlled by Petrobras in which there is a participation in the share capital of the controlled company by the
Brazilian Federal Government, its Entities, or any authority of a public entity to which Petrobras is linked, or by
individuals connected to it; v) Petrobras’ associated entities (including entities controlled by its associates); and vi)
entities controlled by key management personnel or by their close family members, taking into account the materiality
established by this policy.
Transactions with the Brazilian Federal Government, including its agencies or similar bodies and controlled entities (the
latter when classified as out of the Company's normal course of business by the CAE), which are under the scope of
Board of Directors approval, must be preceded by the CAE and Minority Shareholders Committee assessment and must
have prior approval of, at least, 2/3 of the board members.
The related-party transactions policy also aims to ensure an adequate and diligent decision-making process for the
Company’s key management.
34.1. Transactions with joint ventures, associates, government entities and pension plans
The Company has engaged, and expects to continue to engage, in the ordinary course of business in numerous
transactions with joint ventures, associates, pension plans, as well as with the Company’s controlling shareholder, the
Brazilian Federal Government, which include transactions with banks and other entities under its control, such as
financing and banking, asset management and other transactions.
The balances of significant transactions are set out in the following table:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-117
12.31.2024
12.31.2023
Assets
Liabilities
Assets
Liabilities
Joint ventures and associates
Petrochemical companies (associates)
65
1
45
4
Other associates and joint ventures
52
15
95
10
Subtotal
117
16
140
14
Brazilian government – Parent and its controlled entities
Government bonds
1,114
−
1,819
−
Banks controlled by the Brazilian Government
12,030
2,675
15,526
2,119
Petroleum and alcohol account - receivables from the Brazilian Government (note 14.1)
−
−
278
−
Brazilian Federal Government (1)
−
1,046
−
1,378
Pré-Sal Petróleo S.A. – PPSA
−
79
−
28
Others
235
85
138
80
Subtotal
13,379
3,885
17,761
3,605
Petros
44
234
64
305
Total
13,540
4,135
17,965
3,924
Current
1,557
1,382
2,684
1,676
Non-Current
11,983
2,753
15,281
2,248
(1) It includes amounts related to lease liability.
The income/expenses of significant transactions are set out in the following table:
2024
2023
2022
Joint ventures and associates
State-controlled gas distributors (joint ventures) (1)
−
−
1,196
Petrochemical companies (associates)
3,505
3,402
4,465
Other associates and joint ventures
50
57
96
Subtotal
3,555
3,459
5,757
Brazilian government – Parent and its controlled entities
Government bonds
145
210
204
Banks controlled by the Brazilian Government
−
(19)
71
Receivables from the Electricity sector
−
233
−
Petroleum and alcohol account - receivables from the Brazilian Government
7
15
62
Brazilian Federal Government
(112)
(124)
288
Pré-Sal Petróleo S.A. – PPSA
(599)
(361)
(657)
Others
(255)
(204)
(79)
Subtotal
(814)
(250)
(111)
Petros
(19)
(19)
(21)
Total - Income (Expenses)
2,722
3,190
5,625
Revenues, mainly sales revenues
3,536
3,450
5,821
Purchases and services
15
12
(4)
Income (expenses)
(871)
(582)
(804)
Foreign exchange and inflation indexation charges, net
(105)
(267)
299
Finance income (expenses), net
147
577
313
Total - Income (Expenses)
2,722
3,190
5,625
Information on the judicialized debts from the Brazilian Federal Government (precatórios) issued in favor of the
Company arising from the petroleum and alcohol accounts is disclosed in note 14.
The liability related to pension plans of the Company's employees and managed by the Petros Foundation, including
debt instruments, is presented in note 18.
34.2. Compensation of key management personnel
The criteria for compensation of employees and officers are established based on the relevant labor legislation and the
Company’s Positions, Salaries and Benefits Plan (Plano de Cargos e Salários e de Benefícios e Vantagens).
The compensation of employees (including those occupying managerial positions) in December 2024 and December
2023 were:
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-118
Parent Company (U.S. dollars)
Compensation of employees, excluding officers
2024
2023
Lowest compensation
731
920
Average compensation
4,249
4,921
Highest compensation
18,194
21,516
Parent Company
Employees
2024
2023
Number of employees
41,778
40,213
The annual compensation of Executive Officers, including variable compensation, for the years 2024 and 2023 were:
Parent Company (U.S. dollars)
Compensation of the Director of Petrobras (includes variable compensation)
2024
2023
Lowest compensation (1)
452,163
30,301
Average compensation (2)
615,641
765,364
Highest compensation (3)
563,303
562,491
(1) It corresponds to the lowest annual compensation, according to the Annual Circular Letter CVM/SEP of March 7, 2024, for those who served for 12 months. If there
are no members meeting this condition, the lowest amount paid should be considered.
(2) It corresponds to the total value of the annual compensation, including expenses with former members, divided by the number of remunerated positions (9),
according to the Annual Circular Letter CVM/SEP of March 7, 2024.
(3) It corresponds to the annual compensation, without any exclusions, of the officer with the highest individual compensation, according to the Annual Circular Letter
CVM/SEP of March 7, 2024.
The criteria for compensation of members of the Board of Directors and the Board Executive Officers is based on the
guidelines established by the Secretariat of Management and Governance of the State-owned Companies (SEST) of the
Ministry of Management and Innovation in Public Services, and by the Ministry of Mines and Energy. The total
compensation is set out as follows:
Parent Company
2024
2023
Executive
Officers
Board of
Directors
Total
Executive
Officers
Board of
Directors
Total
Wages and short-term benefits
3.0
0.4
3.4
3.0
0.1
3.1
Social security and other employee-related taxes
0.8
−
0.8
0.9
−
0.9
Post-employment benefits (pension plan)
0.3
−
0.3
0.3
−
0.3
Variable compensation
2.6
−
2.6
2.9
−
2.9
Benefits due to termination of tenure
0.5
−
0.5
0.9
−
0.9
Total compensation recognized in the statement of income
7.2
0.4
7.6
8.0
0.1
8.1
Total compensation paid (1)
6.4
0.4
6.8
7.6
−
7.6
Monthly average number of members
9.00
11.00
20.00
9.00
11.00
20.00
Monthly average number of paid members
9.00
8.00
17.00
9.00
6.33
15.33
(1) It includes variable compensation for Executive Officers.
In 2024, expenses related to compensation of the board members and executive officers of Petrobras amounted to
US$ 14 (US$ 13.9 in 2023 and US$ 14.7 in 2022).
The compensation of the Advisory Committees to the Board of Directors is separate from the fixed compensation set
for the Board Members and, therefore, has not been classified under compensation of Petrobras’ key management
personnel.
In accordance with Brazilian regulations applicable to companies controlled by the Brazilian Federal Government, Board
members who are also members of the Statutory Audit Committees are only compensated with respect to their Audit
Committee duties. The total compensation concerning these members was US$ 416 thousand for 2024 (US$ 493
thousand with tax and social security costs). For 2023, the total compensation concerning these members was US$ 403
thousand (US$ 484 thousand with tax and social security costs). For 2022, it was US$ 544 thousand (US$ 642 thousand
with tax and social security costs).
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-119
On April 25, 2024, the shareholders, at the Company’s Annual General Shareholders Meeting, set the threshold for the
overall compensation for executive officers and board members at US$ 8.6 (R$ 43.21 million) from April 2024 to March
2025.
The average annual remuneration of the members of Petrobras' Fiscal Council, in fiscal year 2024, was US$ 29 (US$ 34,
considering social security costs). In 2023, the average annual remuneration was US$ 31 (US$ 38, considering social
security costs). In 2022, the average annual remuneration was US$ 28 (US$ 33, considering social security costs).
The Variable Compensation Program for Executive Officers is subject to compliance with prerequisites and performance
indicators. The variable remuneration to be paid changes according to the percentage of goals achievement and its
payment is deferred in 4 annual installments.
In 2024, the Company provisioned US$ 2.6 referring to the Performance Award Program – PPP 2024 for Executive
Directors.
Exemption from damage (indemnity)
Since 2022, the Company's Bylaws establish the obligation to indemnify its managers, members with statutory
functions and other employees and agents who legally act by delegation of the Company's managers, besides
maintaining a permanent insurance contract in favor of these individuals, to save them from liability for acts arising
from the exercise of their activities. As of 2018, the bylaws also began to provide for the possibility of Petrobras entering
into indemnity contracts, in order to cover any expenses due to complaints, inquiries, administrative, arbitration or
judicial investigations and proceedings, in Brazil or in any other jurisdiction, which aim to impute responsibility for
regular management acts practiced exclusively in the exercise of its activities since the date of its investiture or the
beginning of the contractual relationship with the Company. The limits and form of defense in judicial and
administrative proceedings are defined in the Policy for the Application and Governance of the Indemnity Commitment,
approved by the Board of Directors.
The first Indemnity Commitment was approved by the Board of Directors on December 18, 2018, starting from its
signature until the Ordinary General Meeting of 2020. The maximum exposure established by the Company (global limit
for all eventual damages) was US$ 500.
The second Indemnity Commitment was approved by the Board of Directors on March 25, 2020, starting from its
signature until the Ordinary General Meeting of 2022. The maximum exposure established by the Company (global limit
for all possible damages) was US$ 300.
The third Indemnity Commitment was approved by the Board of Directors on March 30, 2022, starting from its signature,
until the Ordinary General Meeting of 2024. The maximum exposure established by the Company (global limit for all
possible damages) was US$ 200.
The fourth Indemnity Commitment was approved by the Board of Directors on March 27, 2024, starting from its
signature, until the Ordinary General Meeting of 2026. The maximum exposure established by the Company (global limit
for all possible damages) was US$ 161.
The term of coverage provided for in the Commitment begins from the date of signature until the occurrence of the
following events, whichever comes last: (i) the end of the fifth year following the date on which the beneficiary leave,
for any reason, to exercise the mandate or function/position; (ii) the course of the time required in transit of any Process
in which the Beneficiary is partly due to the practice of Regular Management Act; or (iii) the course of the limitation
period according to law to events that can generate the obligations of indemnification by the Company, including, but
not limited to, the criminal statute applicable deadline, even if such period is applied by administrative authorities or at
any time when there is an indemnifiable event based on an imprescriptible fact.
Indemnity agreements shall not cover: (i) acts covered under Directors and Officers (D&O) insurance policy purchased
by the Company, as formally recognized and implemented by the insurance Company; (ii) acts outside the regular
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-120
exercise of the duties or powers of the Beneficiaries; (iii) acts in bad faith act, malicious acts, fraud or serious fault on
the part of the Beneficiaries, observing the principle of presumed innocence; (iv) self-interested acts or in favor of third
parties that damage the Company’s social interest; (v) obligation to pay damages arising from social action according
to article 159 of Law 6,404/76 or reimbursement of the damages according to art. 11, § 5°, II of Law 6,385/76; or (vi)
where a manifest conflict of interest with the Company is established.
Petrobras will have no obligation to indemnify the Beneficiaries for loss of profits, loss of business opportunity,
interruption of professional activity, moral damages or indirect damages. eventually claimed by the Beneficiaries, with
compensation or reimbursement limited to the cases provided for in the Indemnity Commitment.
In the case of conviction for an intentional act or committed with gross error, final and unappealable in criminal, public
civil, impropriety, popular action, action proposed by a third party, or by shareholders in favor of the Company, or, still,
of an unappealable administrative decision concluding that an act was committed intentionally or with gross error and
that has not been subject to judicial suspension, the beneficiary undertakes, regardless of any manifestation of the
independent third party, to reimburse the Company for all amounts spent by the Company within the scope of this
Commitment, including all expenses and costs related to the process, refunding them within a period of up to 30 days
from the competent notification.
In order to avoid the configuration of conflicts of interest, notably as provided for in art. 156 of Law 6,404/76, the
Company will hire external professionals, who may act individually or jointly, with an unblemished, impartial and
independent reputation (“Independent Third Party”), and with experience to analyze any claim by the Beneficiaries on
the characterization of Regular Management Act or on the hypothesis of exclusions. In addition, Beneficiaries who are
claiming such amounts are prohibited from participating in meetings or discussions that deal with the approval of the
payment of expenses, in compliance with the provisions of art. 156, head provision of Law 6,404/76, Brazilian Corporate
Law.
35. Supplemental information on statement of cash flows
2024
2023
2022
Amounts paid during the year:
Withholding income tax paid on behalf of third-parties
1,307
1,403
1,413
Transactions not involving cash
Purchase of property, plant and equipment on credit
1,081
−
19
Lease
10,107
14,992
6,923
Provision for decommissioning costs
6,393
2,641
3,260
Use of tax credits and judicial deposit for the payment of contingency
256
144
1,236
Remeasurement of property, plant and equipment acquired in previous periods
−
5
24
Earnout related to Atapu and Sépia fields
268
280
694
35.1. Reconciliation of Depreciation, depletion and amortization with Statements of Cash Flows
2024
2023
2022
Depreciation and depletion of Property, plant and equipment
14,953
15,306
14,618
Amortization of Intangible assets
134
104
77
Capitalized depreciation
(2,438)
(1,965)
(1,343)
Depreciation of right of use - recovery of PIS/COFINS
(170)
(165)
(134)
Depreciation, depletion and amortization in the Statements of Cash Flows
12,479
13,280
13,218
NOTES TO THE FINANCIAL STATEMENTS
PETROBRAS
(Expressed in millions of US Dollars, unless otherwise indicated)
F-121
36. Subsequent events
Cancellation of Treasury Shares
On January 29, 2025, the Board of Directors approved the cancellation of a total of 155,764,169 treasury shares, without
reducing the share capital, consisting of 155,541,409 preferred shares and 222,760 common shares.
As a result of the cancellation of treasury shares, the Company's share capital is now composed of 7,442,231,382
common shares and 5,446,501,379 preferred shares, without par value.
The proposal to update the Company's Bylaws to reflect this new number of shares will be submitted to the
Shareholder’s General Meeting.
Contingent Payments Received (earnout)
In January 2025, Petrobras received contingent payments related to three transactions, totaling US$ 605 (R$ 3,702
million), as follows:
•
US$ 356 (R$ 2,161 million) from the partners in the Sépia and Atapu fields, related to the Surplus Volume of the
Transfer of Rights Agreement;
•
US$ 166 (R$ 1,025 million) from Petro Rio Jaguar Petróleo S.A. (PRIO), related to the sale of Petrobras' interest
in the Albacora Leste field; and
•
US$ 83 (R$ 516 million) from Karoon Petróleo & Gás Ltda., related to the sale of the Baúna field.
All these payments are in accordance with the terms of the contracts negotiated between the parties.
Agreement with EIG
On March 7, 2025, Petrobras and EIG entered into an agreement to end the litigation between the parties. Under the
terms of the agreement, Petrobras paid EIG the amount of US$ 283, while EIG requested the termination of the lawsuit
pending in the District Court of Columbia and the cancellation of the precautionary measure blocking the Company's
assets in the Netherlands, as well as waiving any rights related to the dispute. For more information, see note 19.4.3.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-122
Supplementary information on Oil and Gas Exploration and Production (unaudited)
In accordance with Codification Topic 932 - Extractive Activities – Oil and Gas, this section provides supplemental
information on oil and gas exploration and production activities of the Company. The information included in items (i)
through (iii) provides historical cost information pertaining to costs incurred in exploration, property acquisition and
development, capitalized costs and results of operations. The information included in items (iv) and (v) presents
information on Petrobras’ estimated net proved reserve quantities, standardized measure of estimated discounted
future net cash flows related to proven reserves, and changes in estimated discounted future net cash flows.
The Company, on December 31, 2024, maintains activities mainly in Brazil, in addition to activities in Argentina,
Colombia and Bolivia, in South America. The equity-accounted investments are comprised of the operations of the joint
venture company MP Gulf of Mexico, LLC (MPGoM), in which Murphy Exploration & Production Company ("Murphy") has
80% stake and Petrobras America Inc ("PAI") 20% stake in United States of America, North America. The Company
reports its reserves in Brazil, United States of America and Argentina. Volumes in Bolivia are not registered as the
Constitution of this country does not allow. In Colombia, our activities are exploratory, and therefore, there are no
associated reserves.
i) Capitalized costs relating to oil and gas producing activities
As set out in note 26, the Company uses the successful efforts method of accounting for appraisal and development
costs of crude oil and natural gas production. In addition, notes 23 and 24 presents the accounting policies applied by
the Company for recognition, measurement and disclosure of property, plant and equipment and intangible assets.
The following table summarizes capitalized costs for oil and gas exploration and production activities with the related
accumulated depreciation, depletion and amortization, and asset retirement obligations:
Consolidated entities
Brazil
Abroad
Total
Equity
Method
Investees
South
America
Others
Total
December 31, 2024
Unproved oil and gas properties
2,924
160
−
160
3,084
−
Proved oil and gas properties
75,088
284
−
284
75,372
651
Support Equipment
95,073
726
1
727
95,800
−
Gross Capitalized costs
173,085
1,170
1
1,171
174,256
651
Depreciation, depletion and amortization
(57,940)
(815)
(1)
(816)
(58,756)
(330)
Net capitalized costs
115,145
355
−
355
115,500
321
December 31, 2023
Unproved oil and gas properties
3,764
61
−
61
3,825
−
Proved oil and gas properties
82,396
243
−
243
82,639
607
Support Equipment
103,284
758
1
759
104,043
−
Gross Capitalized costs
189,444
1,062
1
1,063
190,507
607
Depreciation, depletion and amortization
(63,003)
(811)
(1)
(812)
(63,815)
(289)
Net capitalized costs
126,441
251
−
251
126,692
318
December 31, 2022
Unproved oil and gas properties
4,227
55
−
55
4,282
−
Proved oil and gas properties
83,030
205
−
205
83,235
762
Support Equipment
69,735
732
1
733
70,468
−
Gross Capitalized costs
156,993
992
1
993
157,986
762
Depreciation, depletion and amortization
(52,836)
(769)
(1)
(770)
(53,606)
(224)
Net capitalized costs
104,156
223
−
223
104,380
538
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-123
ii) Costs incurred in oil and gas property acquisition, exploration and development activities
Costs incurred are summarized below and include both amounts expensed and capitalized:
Consolidated entities
Brazil
Abroad
Total
Equity
Method
Investees
South
America
Total
December 31, 2024
Acquisition costs:
Proved
−
−
−
−
−
Unproved
21
−
−
21
−
Exploration costs
861
119
119
980
−
Development costs
14,007
34
34
14,041
14
Total
14,889
153
153
15,042
14
December 31, 2023
Acquisition costs:
Proved
−
−
−
−
−
Unproved
146
−
−
146
−
Exploration costs
862
11
11
873
10
Development costs
10,929
53
53
10,982
37
Total
11,937
64
64
12,001
47
December 31, 2022
Acquisition costs:
Proved
−
−
−
−
−
Unproved
892
−
−
892
−
Exploration costs
707
51
51
758
1
Development costs
6,883
31
31
6,914
30
Total
8,482
82
82
8,564
31
(iii) Results of operations for oil and gas producing activities
The Company’s results of operations from oil and gas producing activities for the years ended December 31, 2024, 2023
and 2022 are shown in the following table. The Company transfers substantially all of its Brazilian crude oil and gas
production to the RT&M and G&LCE segments, respectively, in Brazil. The internal transfer prices calculated by the
Company’s model may not be indicative of the price the Company would have realized had this production been sold in
an unregulated spot market. Additionally, the prices calculated by the Company’s model may not be indicative of the
future prices to be realized by the Company. Gas prices used are those set out in contracts with third parties.
Production costs are lifting costs incurred to operate and maintain productive wells and related equipment and
facilities, including operating employees’ compensation, materials, supplies, fuel consumed in operations and operating
costs related to natural gas processing plants.
Exploration expenses include the costs of geological and geophysical activities and projects without economic
feasibility. Depreciation and amortization expenses relate to assets employed in exploration and development
activities. In accordance with Codification Topic 932 – Extractive Activities – Oil and Gas, income taxes are based on
statutory tax rates, reflecting allowable deductions. Interest income and expense are excluded from the results
reported in this table.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-124
Consolidated entities
Equity
Method
Investees
Brazil
Abroad
Total
South
America
North
America
Others
Total
December 31, 2024
Net operation revenues:
Sales to third parties
175
133
−
−
133
308
170
Intersegment
60,208
−
−
−
−
60,208
−
60,383
133
−
−
133
60,516
170
Production costs
(15,472)
(59)
−
−
(59)
(15,531)
(50)
Exploration expenses
(901)
(12)
−
−
(12)
(913)
−
Depreciation, depletion and amortization
(9,248)
(44)
−
−
(44)
(9,292)
(36)
Impairment of oil and gas properties
(1,239)
(5)
−
−
(5)
(1,244)
−
Other operating expenses
(5,547)
(5)
71
(1)
65
(5,482)
(10)
Results before income tax expenses
27,977
8
71
(1)
77
28,054
74
Income tax expenses
(9,538)
(3)
2
1
−
(9,538)
−
Results of operations (excluding corporate
overhead and interest costs)
18,439
5
73
−
77
18,516
74
December 31, 2023
Net operation revenues:
Sales to third parties
631
136
−
−
136
767
159
Intersegment
66,113
−
−
−
−
66,113
−
66,744
136
−
−
136
66,880
159
Production costs
(16,946)
(63)
−
−
(63)
(17,009)
(36)
Exploration expenses
(981)
(1)
−
−
(1)
(982)
−
Depreciation, depletion and amortization
(10,186)
(44)
−
−
(44)
(10,230)
(26)
Impairment of oil and gas properties
(2,105)
−
−
−
−
(2,105)
(75)
Other operating expenses
(2,504)
(15)
(8)
(1)
(24)
(2,528)
(25)
Results before income tax expenses
34,023
12
(8)
(1)
3
34,026
(3)
Income tax expenses
(11,568)
(4)
3
1
(1)
(11,569)
−
Results of operations (excluding corporate
overhead and interest costs)
22,455
8
(5)
(1)
2
22,457
(3)
December 31, 2022
Net operation revenues:
Sales to third parties
1,153
158
−
−
158
1,311
275
Intersegment
76,579
−
−
−
−
76,579
−
77,732
158
−
−
158
77,890
275
Production costs
(19,975)
(75)
−
−
(75)
(20,050)
(41)
Exploration expenses
(719)
(168)
−
−
(168)
(887)
−
Depreciation, depletion and amortization
(10,373)
(42)
−
−
(42)
(10,415)
(42)
Impairment of oil and gas properties
(1,216)
(2)
−
−
(2)
(1,218)
−
Other operating expenses
3,000
(1)
(8)
21
12
3,012
(22)
Results before income tax expenses
48,449
(130)
(8)
21
(117)
48,332
170
Income tax expenses
(16,474)
44
−
(3)
41
(16,433)
−
Results of operations (excluding corporate
overhead and interest costs)
31,975
(86)
(8)
19
(76)
31,899
170
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-125
(iv) Reserve quantities information
As presented in note 4.1, proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience
and engineering data, can be estimated with reasonable certainty to be economically producible from a given date
forward, from known reservoirs, and under existing economic conditions, operating methods, and government
regulations – prior to the time at which contracts providing the right to operate expire, unless evidence indicates that
renewal is reasonably certain. The project to extract the hydrocarbons must have commenced or there must be
reasonable certainty that the project will commence within a reasonable time. Reserves estimate involves a high degree
of judgment and complexity and its application affects different items of these Financial Statements.
The Company’s estimated net proved oil and gas reserves and changes thereto for the years 2024, 2023 and 2022 are
presented in the following table. Proved reserves are estimated in accordance with the reserve definitions prescribed
by the Securities and Exchange Commission.
Proved developed oil and gas reserves are proved reserves that can be expected to be recovered: (i) through existing
wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor
compared to the cost of a new well; and (ii) through installed extraction equipment and infrastructure operational at
the time of the reserves estimate if the extraction is done by means not involving a well.
Proved reserves for which substantial new investments in additional wells and related facilities will be required are
named proved undeveloped reserves.
Reserve estimates are subject to variations due to technical uncertainties in the reservoir and changes in economic
scenarios. A summary of the annual changes in the proved reserves of oil is as follows (in millions of barrels):
Consolidated Entities
Equity Method
Investees
Proved developed and undeveloped
reserves (*)
Crude oil in
Brazil
Crude Oil in
South
America
Synthetic Oil
in Brazil
Consolidated
Total
Crude Oil in
North
America
Total
At January 1, 2024
9,210
2
−
9,212
16
9,228
Extensions and discoveries
−
−
−
−
−
−
Revisions of previous estimates
1,185
−
−
1,185
−
1,184
Production for the year
(761)
−
−
(761)
(2)
(764)
Reserves at December 31, 2024
9,634
2
−
9,636
13
9,649
At January 1, 2023
8,908
2
−
8,910
16
8,926
Extensions and discoveries
95
−
−
95
−
95
Revisions of previous estimates
1,140
−
−
1,140
2
1,142
Sales of reserves
(147)
−
−
(147)
−
(147)
Production for the year
(786)
−
−
(786)
(2)
(789)
Reserves at December 31, 2023
9,210
2
−
9,212
16
9,228
At January 1, 2022
8,406
2
10
8,419
17
8,435
Revisions of previous estimates
1,705
−
−
1,705
3
1,708
Sales of reserves (1)
(455)
−
(10)
(465)
(1)
(465)
Production for the year
(748)
−
(1)
(749)
(3)
(752)
Reserves at December 31, 2022
8,908
2
−
8,910
16
8,926
(1) Includes the effects of the write-offs related to the Co-Participation Agreements of Atapu and Sepia fields.
(*) Apparent differences in the sum of the numbers are due to rounding.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-126
A summary of the annual changes in the proved reserves of natural gas is as follows (in billions of cubic feet):
Consolidated Entities
Equity Method
Investees
Proved developed and undeveloped
reserves (*)
Natural Gas in
Brazil
Natural Gas in
South
America
Synthetic Gas
in Brazil
Consolidated
Total
Natural Gas in
North
America
Total
At January 1, 2024
9,335
163
−
9,498
7
9,504
Extensions and discoveries
−
7
−
7
−
7
Revisions of previous estimates
796
19
−
815
(4)
811
Production for the year
(549)
(20)
−
(569)
(1)
(570)
Reserves at December 31, 2024
9,582
168
−
9,750
2
9,752
At January 1, 2023
8,504
173
−
8,677
6
8,683
Extensions and discoveries
779
15
−
794
−
794
Revisions of previous estimates
673
(5)
−
668
1
669
Sales of reserves
(47)
−
−
(47)
−
(47)
Production for the year
(573)
(20)
−
(594)
(1)
(595)
Reserves at December 31, 2023
9,335
163
−
9,498
7
9,504
At January 1, 2022
7,912
177
17
8,106
7
8,113
Revisions of previous estimates
1,560
16
−
1,575
−
1,575
Sales of reserves (1)
(382)
−
(15)
(397)
(1)
(398)
Production for the year
(586)
(20)
(1)
(606)
(1)
(607)
Reserves at December 31, 2022
8,504
173
−
8,677
6
8,683
(1) Includes the effects of the write-offs related to the Co-Participation Agreements of Atapu and Sepia fields.
(*) Apparent differences in the sum of the numbers are due to rounding.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
Natural gas production volumes used in these tables are the net volumes withdrawn from our proved reserves, including
gas consumed in operations and excluding reinjected gas. Our disclosure of proved gas reserves includes gas consumed
in operations, which represent 36% of our total proved reserves of natural gas as of December 31, 2024.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-127
The tables below summarize information about the changes in total proved reserves of crude oil and natural gas, in
millions of barrels of oil equivalent, in our consolidated entities and equity method investees for 2024, 2023 and 2022:
Consolidated Entities
Equity Method
Investees
Proved developed and undeveloped
reserves (*)
Oil equivalent
in Brazil
Oil equivalent
in South
America
Synthetic Oil
in Brazil
Consolidated
Total
Oil equivalent in
North
America
Total
At January 1, 2024
10,873
31
−
10,904
17
10,921
Extensions and discoveries
−
1
−
1
−
2
Revisions of previous estimates
1,326
4
−
1,330
(1)
1,329
Production for the year
(859)
(4)
−
(863)
(3)
(865)
Reserves at December 31, 2024
11,341
32
−
11,372
14
11,386
At January 1, 2023
10,423
33
−
10,455
17
10,473
Extensions and discoveries
233
3
−
236
−
237
Revisions of previous estimates
1,260
(1)
−
1,259
2
1,262
Sales of reserves
(155)
−
−
(155)
−
(155)
Production for the year
(888)
(4)
−
(892)
(2)
(894)
Reserves at December 31, 2023
10,873
31
−
10,904
17
10,921
At January 1, 2022
9,816
33
13
9,862
18
9,880
Revisions of previous estimates
1,983
3
−
1,986
3
1,989
Sales of reserves (1)
(523)
−
(12)
(536)
(1)
(536)
Production for the year
(852)
(4)
(1)
(857)
(3)
(860)
Reserves at December 31, 2022
10,423
33
−
10,455
17
10,473
(1) Includes the effects of the write-offs related to the Co-Participation Agreements of Atapu and Sepia fields.
(*) Apparent differences in the sum of the numbers are due to rounding.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
In 2024, we incorporated 1,330 million boe of proved reserves by revising previous estimates, including:
(i) addition of 883 million boe due to new projects, mainly in Atapu and Sépia fields and in other fields in Santos, Campos
and Solimões basins; and
(ii) addition of 447 million boe, due to the good performance of assets, mainly in Búzios, Itapu, Tupi and Sépia fields, in
the Santos Basin, and other revisions.
We did not have relevant changes related to the variation in the oil price.
The Company's total proved reserve resulted in 11,386 million boe in 2024, considering the variations above and the
reduction from 2024 production of 865 million boe. Production refers to volumes that were previously included in our
reserves and, therefore, does not consider natural gas liquids, since the reserve is estimated at a reference point prior
to gas processing, except in the United States and Argentina. The production also does not consider volumes of injected
gas, the production of Extended Well Tests in exploratory blocks and production in Bolivia, since the Bolivian
Constitution does not allow the registration of reserves by the Company.
In 2023, we incorporated 1,262 million boe of proved reserves by revising previous estimates, including:
(i) addition of 1,092 million boe arising from the good performance of assets, mainly in Búzios, Tupi and Atapu fields, in
the Santos Basin; and
(ii) addition of 170 million boe due to new projects and other revisions.
We did not have relevant changes related to the variation in the oil price.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-128
In addition, we incorporated 237 million boe from discoveries and extensions, mainly due to the declaration of
commerciality of Raia Manta and Raia Pintada fields (non-operated), in the Campos Basin.
Moreover, proved reserves were reduced by 155 million boe, resulting from sales.
The Company's total proved reserve resulted in 10,921 million boe in 2023, considering the variations above and the
reduction from 2023 production of 894 million boe. Production refers to volumes that were previously included in our
reserves and, therefore, does not consider natural gas liquids, since the reserve is estimated at a reference point prior
to gas processing, except in the United States and Argentina. The production also does not consider volumes of injected
gas, the production of Extended Well Tests in exploratory blocks and production in Bolivia, since the Bolivian
Constitution does not allow the registration of reserves by the Company.
In 2022, we incorporated 1,989 million boe of proved reserves by revising previous estimates, including:
(i) addition of 1,279 million boe due to new projects, mainly in Búzios field and in other fields in the Santos and Campos
Basins; and
(ii) addition of 710 million boe arising from other revisions, mainly due to good performance of reservoirs in the pre-
salt layer of Santos Basin and to the contract term extension of Rio Urucu and Leste do Urucu fields.
We did not have relevant changes related to the variation in the oil price.
The addition in our proved reserves were partially offset by the reduction of 536 million boe, due to the effects of the
transfer of interests of 5% of the Surplus Volume of the Transfer of Rights of Búzios field, of the write-offs related to
the Co-Participation Agreements of Atapu and Sepia fields and of sales of properties in mature fields.
The Company's total proved reserve resulted in 10,473 million boe in 2022, considering the variations above and the
reduction from 2022 production of 860 million boe. Production refers to volumes that were previously included in our
reserves and, therefore, does not consider natural gas liquids, since the reserve is estimated at a reference point prior
to gas processing, except in the United States and Argentina. The production also does not consider volumes of injected
gas, the production of Extended Well Tests in exploratory blocks and production in Bolivia, since the Bolivian
Constitution does not allow the registration of reserves by the Company.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-129
The tables below present the volumes of proved developed and undeveloped reserves, net, that is, reflecting Petrobras'
participation:
2024
Crude Oil
Natural Gas
Total oil and
gas
(mmbbl)
(bncf)
(mmboe)
Net proved developed reserves (*):
Consolidated Entities
Brazil
4,884
5,387
5,843
South America, outside Brazil (1)
1
80
15
Total Consolidated Entities
4,885
5,467
5,858
Equity Method Investees
North America (1)
13
2
14
Total Equity Method Investees
13
2
14
Total developed Consolidated and Equity Method Investees
4,898
5,469
5,872
Net proved undeveloped reserves (*):
Consolidated Entities
Brazil
4,750
4,194
5,497
South America, outside Brazil (1)
1
89
17
Total Consolidated Entities
4,751
4,283
5,514
Equity Method Investees
North America (1)
−
−
−
Total Equity Method Investees
−
−
−
Total undeveloped Consolidated and Equity Method Investees
4,751
4,283
5,514
Total proved reserves (developed and undeveloped)
9,649
9,752
11,386
(1) South America oil reserves include 25% of natural gas liquid (NGL) in proved developed reserves and 24% of NGL in proved undeveloped reserves. North America oil
reserves include 14% of natural gas liquid (NGL) in proved developed reserves and 17% of NGL in proved undeveloped reserves.
(*) Apparent differences in the sum of the numbers are due to rounding off.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
2023
Crude Oil
Natural Gas
Total oil and
gas
(mmbbl)
(bncf)
(mmboe)
Net proved developed reserves (*):
Consolidated Entities
Brazil
4,710
5,522
5,694
South America, outside Brazil (1)
1
92
17
Total Consolidated Entities
4,711
5,614
5,711
Equity Method Investees
North America (1)
14
6
15
Total Equity Method Investees
14
6
15
Total developed Consolidated and Equity Method Investees
4,726
5,620
5,727
Net proved undeveloped reserves (*):
Consolidated Entities
Brazil
4,500
3,814
5,179
South America, outside Brazil (1)
1
70
13
Total Consolidated Entities
4,501
3,884
5,193
Equity Method Investees
North America (1)
2
1
2
Total Equity Method Investees
2
1
2
Total undeveloped Consolidated and Equity Method Investees
4,503
3,885
5,194
Total proved reserves (developed and undeveloped)
9,228
9,504
10,921
(1) South America oil reserves include 25% of natural gas liquid (NGL) in proved developed reserves and 26% of NGL in proved undeveloped reserves. North America oil
reserves include 6% of natural gas liquid (NGL) in proved developed reserves and 7% of NGL in proved undeveloped reserves.
(*) Apparent differences in the sum of the numbers are due to rounding.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-130
2022
Crude Oil
Natural Gas
Total oil and
gas
(mmbbl)
(bncf)
(mmboe)
Net proved developed reserves (*):
Consolidated Entities
Brazil
4,185
5,097
5,093
South America, outside Brazil (1)
1
91
17
Total Consolidated Entities
4,186
5,188
5,110
Equity Method Investees
North America (1)
14
5
15
Total Equity Method Investees
14
5
15
Total developed Consolidated and Equity Method Investees
4,200
5,193
5,125
Net proved undeveloped reserves (*):
Consolidated Entities
Brazil
4,723
3,407
5,330
South America, outside Brazil (1)
1
82
15
Total Consolidated Entities
4,724
3,489
5,346
Equity Method Investees
North America (1)
2
1
2
Total Equity Method Investees
2
1
2
Total undeveloped Consolidated and Equity Method Investees
4,726
3,490
5,348
Total proved reserves (developed and undeveloped)
8,926
8,683
10,473
(1) South America oil reserves include 24% of natural gas liquid (NGL) in proved developed reserves and 24% of NGL in proved undeveloped reserves. North America oil
reserves include 2% of natural gas liquid (NGL) in proved developed reserves and 4% of NGL in proved undeveloped reserves.
(*) Apparent differences in the sum of the numbers are due to rounding.
In 2023, we standardized the conversion between gas and oil equivalent to 5,614.65 ft3 = 1 boe, which is equivalent to the conversion used in contracts in Brazil.
Quantities from previous years were restated with the new conversion.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-131
(v) Standardized measure of discounted future net cash flows relating to proved oil and gas quantities and
changes therein
The standardized measure of discounted future net cash flows, related to the above proved oil and gas reserves, is
calculated in accordance with the requirements of Codification Topic 932 – Extractive Activities – Oil and Gas.
Estimated future cash inflows from production in Brazil are computed by applying the average price during the 12-
month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic
average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual
arrangements, excluding escalations based upon future conditions. Future price changes are limited to those provided
by contractual arrangements existing at the end of each reporting year. Future development and production costs are
those estimated future expenditures necessary to develop and produce year-end estimated proved reserves based on
current costs, including abandonment costs, assuming continuing economic conditions. Estimated future income taxes
(including future social contributions on net income - CSLL) are calculated by applying appropriate year-end statutory
tax rates. The amounts presented as future income taxes expenses reflect allowable deductions considering statutory
tax rates. Discounted future net cash flows are calculated using 10% mid-period discount factors. This discounting
requires a year-by-year estimate of when the future expenditures will be incurred and when the reserves will be
produced.
The valuation prescribed under Codification Topic 932 – Extractive Activities – Oil and Gas requires assumptions as to
the timing and amount of future development and production costs. The calculations are made as of December 31 each
year and should not be relied upon as an indication of Petrobras’ future cash flows or the value of its oil and gas reserves.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-132
Standardized measure of discounted future net cash flows:
Consolidated entities
Equity
Method
Investees
Abroad
Brazil
South
America
Total
December 31, 2024
Future cash inflows
800,773
579
801,353
941
Future production costs
(304,051)
(336)
(304,387)
(139)
Future development costs
(74,770)
(107)
(74,877)
(34)
Future income tax expenses
(149,968)
(58)
(150,026)
−
Undiscounted future net cash flows
271,984
78
272,062
768
10 percent midyear annual discount for timing of estimated
cash flows (1)
(128,559)
(31)
(128,590)
(262)
Standardized measure of discounted future net cash flows
143,425
47
143,473
506
December 31, 2023
Future cash inflows
819,428
650
820,078
1,213
Future production costs
(348,787)
(354)
(349,142)
(191)
Future development costs
(64,121)
(113)
(64,235)
(13)
Future income tax expenses
(140,774)
(43)
(140,818)
−
Undiscounted future net cash flows
265,745
139
265,884
1,009
10 percent midyear annual discount for timing of estimated
cash flows (1)
(120,216)
(46)
(120,262)
(319)
Standardized measure of discounted future net cash flows
145,529
93
145,622
691
December 31, 2022
Future cash inflows
983,826
837
984,663
1,581
Future production costs
(399,655)
(357)
(400,012)
(273)
Future development costs
(62,548)
(128)
(62,676)
(21)
Future income tax expenses
(178,412)
(88)
(178,500)
−
Undiscounted future net cash flows
343,211
264
343,475
1,287
10 percent midyear annual discount for timing of estimated
cash flows (1)
(151,828)
(124)
(151,951)
(401)
Standardized measure of discounted future net cash flows
191,383
141
191,524
886
(1) Semiannual capitalization
Apparent differences in the sum of the numbers are due to rouding.
Petróleo Brasileiro S.A. – Petrobras
Supplementary information (unaudited)
(Expressed in millions of US Dollars, unless otherwise indicated)
F-133
Changes in discounted net future cash flows:
Consolidated entities
Equity
Method
Investees
Abroad
Brazil
South
America
Total
Balance at January 1, 2024
145,529
93
145,622
691
Sales and transfers of oil and gas, net of production cost
(44,911)
(52)
(44,963)
(119)
Development cost incurred
14,007
34
14,040
14
Net change due to purchases and sales of minerals in place
−
−
−
−
Net change due to extensions, discoveries and improved recovery
related costs
−
7
7
2
Revisions of previous quantity estimates
32,619
26
32,645
(31)
Net change in prices, transfer prices and in production costs
10,226
(41)
10,185
(71)
Changes in estimated future development costs
(23,749)
(18)
(23,767)
(6)
Accretion of discount
14,553
13
14,566
60
Net change in income taxes
(4,848)
(17)
(4,865)
−
Other - unspecified
−
3
3
(32)
Balance at December 31, 2024
143,425
47
143,473
506
Balance at January 1, 2023
191,383
141
191,524
886
Sales and transfers of oil and gas, net of production cost
(49,797)
(54)
(49,851)
(123)
Development cost incurred
10,929
53
10,982
37
Net change due to purchases and sales of minerals in place
(3,894)
−
(3,894)
−
Net change due to extensions, discoveries and improved recovery
related costs
5,858
19
5,876
11
Revisions of previous quantity estimates
31,616
3
31,619
82
Net change in prices, transfer prices and in production costs
(63,907)
(97)
(64,004)
(201)
Changes in estimated future development costs
(16,409)
(27)
(16,436)
(17)
Accretion of discount
19,138
20
19,159
68
Net change in income taxes
20,611
30
20,641
−
Other - unspecified
−
5
5
(53)
Balance at December 31, 2023
145,529
93
145,622
691
Balance at January 1, 2022
114,780
89
114,869
470
Sales and transfers of oil and gas, net of production cost
(54,230)
(62)
(54,291)
(235)
Development cost incurred
6,883
31
6,913
29
Net change due to purchases and sales of minerals in place
(17,030)
−
(17,030)
−
Net change due to extensions, discoveries and improved recovery
related costs
−
−
−
10
Revisions of previous quantity estimates
64,535
17
64,553
82
Net change in prices, transfer prices and in production costs
129,462
122
129,584
349
Changes in estimated future development costs
(23,317)
(39)
(23,356)
(4)
Accretion of discount
11,478
14
11,492
93
Net change in income taxes
(41,178)
(17)
(41,194)
−
Other - unspecified
−
(15)
(15)
92
Balance at December 31, 2022
191,383
141
191,524
886
Apparent differences in the sum of the numbers are due to rounding.
F-134
Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing, adequately maintaining and assessing the effectiveness of internal
control over financial reporting. Such internal control is a process designed by, or under the supervision of our CEO and
CFO, and effected by our board of directors, management and other employees.
The internal control over financial reporting is designed to provide reasonable assurances regarding the reliability of
financial reporting and of the preparation of our consolidated financial statements for external purposes, in accordance
with IFRS, as issued by the IASB.
Due to its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. In
addition, projections of any evaluation of effectiveness of internal control over financial reporting to future periods are
subject to the risk of becoming inadequate because of changes in its conditions and assumptions.
Our management has assessed the effectiveness of our internal control over financial reporting as of December 31,
2024 based on the criteria established in “Internal Controls – Integrated Framework (2013)” issued by the Committee of
Sponsoring Organizations of Treadway Commission (“COSO”). Our management has concluded that our internal control
over financial reporting was effective.
Magda Maria de Regina Chambriard
Chief Executive Officer
Fernando Sabbi Melgarejo
Chief of Financial and Investor Relations Executive Officer
KPMG Auditores Independentes Ltda., uma sociedade simples brasileira, de
responsabilidade limitada e firma-membro da organização global KPMG de
firmas-membro independentes licenciadas da KPMG International Limited,
uma empresa inglesa privada de responsabilidade limitada.
KPMG Auditores Independentes Ltda., a Brazilian limited liability company
and a member firm of the KPMG global organization of independent member
firms affiliated with KPMG International Limited, a private English company
limited by guarantee.
F-135
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors of
Petróleo Brasileiro S.A. – Petrobras
Opinions on the Consolidated Financial Statements and Internal Control Over Financial Reporting
We have audited the accompanying consolidated statements of financial position of Petróleo Brasileiro S.A. –
Petrobras and subsidiaries (“the Company”) as of December 31, 2024 and 2023, the related consolidated
statements of income, comprehensive income, changes in shareholders’ equity and cash flows for each of the
years in the three-year period ended December 31, 2024, and the related notes (collectively, the “consolidated
financial statements”). We also have audited the Company’s internal control over financial reporting as of
December 31, 2024, based on criteria established in Internal Control – Integrated Framework (2013) issued by the
Committee of Sponsoring Organizations of the Treadway Commission.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the
financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash
flows for each of the years in the three-year period ended December 31, 2024, in conformity with IFRS Accounting
Standards as issued by the International Accounting Standards Board (IASB). Also in our opinion, the Company
maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024
based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of
Sponsoring Organizations of the Treadway Commission.
Basis for Opinions
The Company’s management is responsible for these consolidated financial statements, for maintaining effective
internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial
reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our
responsibility is to express an opinion on the Company’s consolidated financial statements and an opinion on the
Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered
with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be
independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable
rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan
and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are
free of material misstatement, whether due to error or fraud, and whether effective internal control over financial
reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material
misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures
that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts
and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting
principles used and significant estimates made by management, as well as evaluating the overall presentation of
the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an
understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and
testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our
audits also included performing such other procedures as we considered necessary in the circumstances. We
believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance
regarding the reliability of financial reporting and the preparation of financial statements for external purposes in
accordance with generally accepted accounting principles. A company’s internal control over financial reporting
includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail,
accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable
assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance
with generally accepted accounting principles, and that receipts and expenditures of the company are being made
only in accordance with authorizations of management and directors of the company; and (3) provide reasonable
KPMG Auditores Independentes Ltda., uma sociedade simples brasileira, de
responsabilidade limitada e firma-membro da organização global KPMG de
firmas-membro independentes licenciadas da KPMG International Limited,
uma empresa inglesa privada de responsabilidade limitada.
KPMG Auditores Independentes Ltda., a Brazilian limited liability company
and a member firm of the KPMG global organization of independent member
firms affiliated with KPMG International Limited, a private English company
limited by guarantee.
F-136
assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the
company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect
misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that
controls may become inadequate because of changes in conditions, or that the degree of compliance with the
policies or procedures may deteriorate.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit
of the consolidated financial statements that were communicated or required to be
communicated to the audit committee and that: (1) relate to accounts or disclosures that are
material to the consolidated financial statements and (2) involved our especially challenging,
subjective, or complex judgments. The communication of critical audit matters does not alter in
any way our opinion on the consolidated financial statements, taken as a whole, and we are not,
by communicating the critical audit matters below, providing separate opinions on the critical
audit matters or on the accounts or disclosures to which they relate.
Assessment of the measurement of the defined benefit obligations for pension and
health care plans
As discussed in notes 4.4 and 18.3 to the consolidated financial statements, the Company
sponsors defined benefit pension and health care plans that provide supplementary retirement
benefits and medical care to its employees and former employees. As of December 31, 2024,
the defined benefit obligations for these pension and health care plans were US$ 11,398 million.
The measurement of the Company’s defined benefit obligations with respect to these plans
requires the determination of certain actuarial assumptions. These assumptions include the
discount rates and projected medical and hospital costs. The Company hires external actuarial
professionals to assist in the process of determining the actuarial assumptions and the valuation
of the defined benefit obligations for its pension and health care plans.
We identified the assessment of the measurement of the defined benefit obligations for the
pension and health care plans as a critical audit matter. Subjective auditor judgment was
required because changes to the discount rates and projected medical and hospital costs used
to determine the defined benefit obligations can cause significant changes to the measurement
of the defined benefit obligations for the pension and health care plans.
The following are the primary procedures we performed to address this critical audit matter:
• we evaluated the design and tested the operating effectiveness of certain internal controls over
the Company’s process for determining the defined benefit obligations for pension and health
care plans. This included controls related to the determination, review and approval of the
discount rates and projected medical and hospital costs;
• we evaluated the scope of the work, competency, and objectivity of the external actuarial
professionals hired by the Company to assist in the process of determining the actuarial
assumptions and the measurement of the defined benefit obligations for the pension and health
care plans. This included assessing the nature and scope of the work performed by these
external actuarial professionals and their qualifications and professional experience; and
KPMG Auditores Independentes Ltda., uma sociedade simples brasileira, de
responsabilidade limitada e firma-membro da organização global KPMG de
firmas-membro independentes licenciadas da KPMG International Limited,
uma empresa inglesa privada de responsabilidade limitada.
KPMG Auditores Independentes Ltda., a Brazilian limited liability company
and a member firm of the KPMG global organization of independent member
firms affiliated with KPMG International Limited, a private English company
limited by guarantee.
F-137
• we involved actuarial professionals with specialized skills and knowledge, who assisted in
evaluating the Company’s discount rates and projected medical and hospital costs including
comparisons to data obtained from external sources.
Evaluation of the impairment testing of exploration and production cash generating units
As discussed in notes 4.2.1, 4.2.2, 4.2.2(a) and 25 to the consolidated financial statements, for
the purposes of impairment testing, the Company identifies its cash generating units (“CGUs”),
estimates the recoverable amount of these CGUs and compares the recoverable amount with
the carrying amount of these CGUs. The carrying amount of the exploration and production
CGUs as of December 31, 2024 was US$ 7,998 million. For the year ended December 31,
2024, the amount of impairment losses recognized in relation to the exploration and production
CGUs was US$ 1,129 million.
We identified the evaluation of the impairment testing of exploration and production CGUs as a
critical audit matter. A high degree of complexity and subjectivity of auditor judgment was
involved in evaluating the Company’s determination of these CGUs and the estimate of the
recoverable amount. The determination of exploration and production CGUs requires auditor
judgment in the consideration of operational factors that impact the interdependencies between
oil and gas assets. These interdependencies alter the aggregation or segregation of the oil and
gas assets into CGUs. The expected future cash flows used to determine the recoverable
amount depend on certain assumptions about the future including average Brent oil and natural
gas prices; exchange rate (Brazilian Real / US Dollar); capital and operating expenditure and
volume and timing of recovery of the oil and gas reserves. The recoverable amount is also
sensitive to changes in the discount rate. The assessment of these assumptions required
significant auditor judgment.
The following are the primary procedures we performed to address this critical audit matter:
• we evaluated the design and tested the operating effectiveness of certain internal controls
over the Company’s impairment assessment process. These included controls related to the
review and approval of the Company’s determination of the CGUs and of the key assumptions
used to estimate the recoverable amount;
• for changes in exploration and production CGUs during the year, we assessed the operational
factors considered by the Company when determining these changes by comparing to
information obtained from internal and external sources;
• we evaluated the Company’s internally prepared projections of recovery of oil and gas
reserves, by comparing them with estimated volumes certified by an external reservoir specialist
hired by the Company and, for a selection of CGUs, with historical production;
• we evaluated the scope of the work, competency, and objectivity of the internal engineers
responsible for the estimate of the oil and gas reserves, as well as the external reservoir
specialist hired by the Company that certified the estimated reserve volumes. This included
assessing the nature and scope of the work they were engaged to perform and their
qualifications and professional experience;
• we evaluated, for a selection of CGUs, the Company’s projected future capital and operating
expenditures by comparing these projections with the latest approved business and
management plan and long-term budgets;
KPMG Auditores Independentes Ltda., uma sociedade simples brasileira, de
responsabilidade limitada e firma-membro da organização global KPMG de
firmas-membro independentes licenciadas da KPMG International Limited,
uma empresa inglesa privada de responsabilidade limitada.
KPMG Auditores Independentes Ltda., a Brazilian limited liability company
and a member firm of the KPMG global organization of independent member
firms affiliated with KPMG International Limited, a private English company
limited by guarantee.
F-138
• we evaluated the Company’s ability to accurately project cash flows by comparing, for a
selection of CGUs, the prior years’ estimated cash flows for the year ended December 31, 2023
with actual cash flows in this year; and
• we involved a valuation professional with specialized skill and knowledge, who assisted in
evaluating certain assumptions used in the impairment testing such as the discount rates,
average Brent oil and natural gas prices and the exchange rates by comparing them against
available external market data.
Evaluation of the estimate of the provision for decommissioning costs
As discussed in notes 4.6 and 20 to the consolidated financial statements the Company records
a provision for decommissioning costs which reflects its obligations to restore the environment
and dismantle and remove oil and gas production facilities upon abandonment. As of December
31, 2024, the carrying amount of the provision for decommissioning costs was US$ 26,203
million. The Company’s estimate of the provision for decommissioning costs includes
assumptions in relation to the nature and extent of the environmental restoration and the
dismantlement and removal work as well as the cost and timing of this work.
We identified the evaluation of the estimate of the provision for decommissioning costs as a
critical audit matter. Subjective auditor judgment was necessary to evaluate the key
assumptions used in the estimate such as the extent of the decommissioning work that will be
required by contract and regulations, the criteria to be met when the decommissioning actually
occurs and the costs and related timing of the future payments that will be incurred in the
decommissioning process.
The following are the primary procedures we performed to address this critical audit matter:
• we evaluated the design and tested the operating effectiveness of certain internal controls over
the Company’s process to estimate the provision for decommissioning costs. This included
controls related to the determination, review and approval of the key assumptions, including
estimates of the timing of abandonment and estimated costs of decommissioning;
• we assessed the estimates of timing until abandonment used by the Company by comparing
the production curves and life of the oil and gas reserves used with estimated reserve volumes
certified by the external reservoir specialist hired by the Company;
• we involved infrastructure valuation professionals with specialized skills and knowledge, who
assisted in the evaluation of the method used to define the extent of decommissioning work in
the determination of the estimated costs by comparing the method to applicable regulatory
requirements and relevant industry practices, as well as the assessment of the estimated costs
of decommissioning by comparing certain of these costs to existing contracts;
• we evaluated the scope of the work, competency, and objectivity of the internal engineers that
estimated the production curves and life of the oil and gas reserves and the external reservoir
specialist hired by the Company that certified the estimated reserve volumes. This included
assessing the nature and scope of the work they were engaged to perform and their
qualifications and professional experience; and
• we evaluated the Company´s ability to accurately forecast costs of decommissioning work, by
comparing a selection of actual expenditure incurred with the decommissioning of oil and gas
KPMG Auditores Independentes Ltda., uma sociedade simples brasileira, de
responsabilidade limitada e firma-membro da organização global KPMG de
firmas-membro independentes licenciadas da KPMG International Limited,
uma empresa inglesa privada de responsabilidade limitada.
KPMG Auditores Independentes Ltda., a Brazilian limited liability company
and a member firm of the KPMG global organization of independent member
firms affiliated with KPMG International Limited, a private English company
limited by guarantee.
F-139
production facilities during the year to the Company´s forecasts of that expenditure at the prior
year-end.
/s/ KPMG Auditores Independentes Ltda.
Rio de Janeiro – Brazil
April 3, 2025
We have served as the Company’s auditor since 2017.