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As Of Filer Filing For·On·As Docs:Size Issuer Filing Agent 4/12/24 Petrobras - Petroleo Brasilei… SA 20-F 12/31/23 280:58M MZ Technologies/FA |
Document/Exhibit Description Pages Size
1: 20-F Annual or Annual-Transition Report by a Foreign HTML 14.32M
Non-Canadian Issuer
2: EX-1.1 Underwriting Agreement or Conflict Minerals Report HTML 213K
3: EX-2.4 Plan of Acquisition, Reorganization, Arrangement, HTML 295K
Liquidation or Succession
4: EX-8.1 Opinion of Counsel re: Tax Matters HTML 71K
6: EX-13.1 Annual or Quarterly Report to Security Holders HTML 66K
11: EX-17.1 Correspondence re: Departure of a Director HTML 67K
12: EX-97.2 Clawback Policy re: Recovery of Erroneously HTML 70K
Awarded Compensation
13: EX-99.1 Miscellaneous Exhibit HTML 99K
5: EX-12.1 Statement re: the Computation of Ratios HTML 74K
7: EX-15.1 Letter re: Unaudited Interim Financial Info HTML 63K
8: EX-15.2 Letter re: Unaudited Interim Financial Info HTML 64K
9: EX-15.3 Letter re: Unaudited Interim Financial Info HTML 105K
10: EX-15.4 Letter re: Unaudited Interim Financial Info HTML 85K
19: R1 Cover HTML 133K
20: R2 Consolidated Statements of Financial Position HTML 182K
21: R3 Consolidated Statements of Income HTML 120K
22: R4 Consolidated Statements of Income (Parenthetical) HTML 69K
23: R5 Consolidated Statements of Comprehensive Income HTML 112K
24: R6 Consolidated Statements of Cash Flows HTML 173K
25: R7 Consolidated Statements of Changes In HTML 113K
Shareholders' Equity
26: R8 The Company and its operations HTML 69K
27: R9 Basis of preparation HTML 84K
28: R10 Material accounting policies HTML 67K
29: R11 Judgments and sources of estimation uncertainty HTML 107K
30: R12 Climate Change HTML 115K
31: R13 New standards and interpretations HTML 78K
32: R14 Capital Management HTML 70K
33: R15 Cash and cash equivalents and marketable HTML 106K
securities
34: R16 Sales revenues HTML 174K
35: R17 Costs and expenses by nature HTML 91K
36: R18 Other income and expenses, net HTML 94K
37: R19 Net finance income (Expense) HTML 88K
38: R20 Information by operating segment HTML 247K
39: R21 Trade and other receivables HTML 134K
40: R22 Inventories HTML 79K
41: R23 Trade payables HTML 75K
42: R24 Taxes HTML 232K
43: R25 Employee benefits HTML 565K
44: R26 Provisions for legal proceedings, judicial HTML 258K
deposits and contingent liabilities
45: R27 Provision for decommissioning costs HTML 107K
46: R28 Other assets and liabilities HTML 103K
47: R29 The ?Lava Jato (Car Wash) Operation? and its HTML 69K
effects on the Company
48: R30 Commitment to purchase natural gas HTML 69K
49: R31 Property, plant and equipment HTML 235K
50: R32 Intangible assets HTML 141K
51: R33 Impairment HTML 275K
52: R34 Exploration and evaluation of oil and gas reserves HTML 125K
53: R35 Collateral for crude oil exploration concession HTML 69K
agreements
54: R36 Consortia (partnerships) in E&P activities HTML 150K
55: R37 Investments HTML 462K
56: R38 Disposal of assets and other transactions HTML 184K
57: R39 Finance debt HTML 298K
58: R40 Lease liability HTML 219K
59: R41 Equity HTML 184K
60: R42 Risk management HTML 379K
61: R43 Related-party transactions HTML 208K
62: R44 Supplemental information on statement of cash HTML 95K
flows
63: R45 Subsequent events HTML 69K
64: R46 Supplementary information on Oil and Gas HTML 950K
Exploration and Production (Unaudited)
65: R47 Material accounting policies (Policies) HTML 66K
66: R48 Cash and cash equivalents and marketable HTML 71K
securities (Policies)
67: R49 Sales revenues (Policies) HTML 68K
68: R50 Information by operating segment (Policies) HTML 73K
69: R51 Trade and other receivables (Policies) HTML 69K
70: R52 Inventories (Policies) HTML 67K
71: R53 Taxes (Policies) HTML 69K
72: R54 Employee benefits (Policies) HTML 71K
73: R55 Provisions for legal proceedings, judicial HTML 68K
deposits and contingent liabilities (Policies)
74: R56 Provision for decommissioning costs (Policies) HTML 67K
75: R57 Other assets and liabilities (Policies) HTML 67K
76: R58 Property, plant and equipment (Policies) HTML 70K
77: R59 Intangible assets (Policies) HTML 68K
78: R60 Impairment (Policies) HTML 71K
79: R61 Exploration and evaluation of oil and gas reserves HTML 71K
(Policies)
80: R62 Consortia (partnerships) in E&P activities HTML 70K
(Policies)
81: R63 Investments (Policies) HTML 68K
82: R64 Disposal of assets and other transactions HTML 69K
(Policies)
83: R65 Finance debt (Policies) HTML 66K
84: R66 Lease liability (Policies) HTML 68K
85: R67 Equity (Policies) HTML 67K
86: R68 Risk management (Policies) HTML 70K
87: R69 Basis of preparation (Tables) HTML 80K
88: R70 Climate Change (Tables) HTML 72K
89: R71 New standards and interpretations (Tables) HTML 76K
90: R72 Cash and cash equivalents and marketable HTML 98K
securities (Tables)
91: R73 Sales revenues (Tables) HTML 164K
92: R74 Costs and expenses by nature (Tables) HTML 91K
93: R75 Other income and expenses, net (Tables) HTML 92K
94: R76 Net finance income (Expense) (Tables) HTML 86K
95: R77 Information by operating segment (Tables) HTML 239K
96: R78 Trade and other receivables (Tables) HTML 124K
97: R79 Inventories (Tables) HTML 73K
98: R80 Trade payables (Tables) HTML 72K
99: R81 Taxes (Tables) HTML 220K
100: R82 Employee benefits (Tables) HTML 537K
101: R83 Provisions for legal proceedings, judicial HTML 229K
deposits and contingent liabilities (Tables)
102: R84 Provision for decommissioning costs (Tables) HTML 103K
103: R85 Other assets and liabilities (Tables) HTML 98K
104: R86 Property, plant and equipment (Tables) HTML 228K
105: R87 Intangible assets (Tables) HTML 117K
106: R88 Impairment (Tables) HTML 272K
107: R89 Exploration and evaluation of oil and gas reserves HTML 113K
(Tables)
108: R90 Consortia (partnerships) in E&P activities HTML 145K
(Tables)
109: R91 Investments (Tables) HTML 454K
110: R92 Disposal of assets and other transactions (Tables) HTML 173K
111: R93 Finance debt (Tables) HTML 289K
112: R94 Lease liability (Tables) HTML 217K
113: R95 Equity (Tables) HTML 157K
114: R96 Risk management (Tables) HTML 372K
115: R97 Related-party transactions (Tables) HTML 198K
116: R98 Supplemental information on statement of cash HTML 96K
flows (Tables)
117: R99 Supplementary information on Oil and Gas HTML 907K
Exploration and Production (Unaudited) (Tables)
118: R100 Basis of preparation (Details) HTML 69K
119: R101 Climate Change (Details) HTML 74K
120: R102 Climate Change (Details Narrative) HTML 103K
121: R103 New standards and interpretations (Details) HTML 81K
122: R104 Capital Management (Details Narrative) HTML 69K
123: R105 Cash and cash equivalents and Marketable HTML 88K
securities (Details)
124: R106 Cash and cash equivalents and Marketable HTML 82K
securities (Details 1)
125: R107 Cash and cash equivalents and marketable HTML 76K
securities (Details Narrative)
126: R108 Sales revenues (Details) HTML 113K
127: R109 Sales revenues (Details 1) HTML 87K
128: R110 Sales revenues (Details 2) HTML 111K
129: R111 Sales revenues (Details Narrative) HTML 75K
130: R112 Costs and expenses by nature (Details) HTML 73K
131: R113 Costs and expenses by nature (Details 1) HTML 74K
132: R114 Costs and expenses by nature (Details 2) HTML 72K
133: R115 Other income and expenses, net (Details) HTML 105K
134: R116 Net finance income (Expense) (Details) HTML 100K
135: R117 Information by operating segment (Details) HTML 168K
136: R118 Information by operating segment (Details 1) HTML 76K
137: R119 Information by operating segment (Details 2) HTML 115K
138: R120 Trade and other receivables (Details) HTML 95K
139: R121 Trade and other receivables (Details 1) HTML 80K
140: R122 Trade and other receivables (Details 2) HTML 75K
141: R123 Trade and other receivables (Details Narrative) HTML 85K
142: R124 Inventories (Details) HTML 81K
143: R125 Inventories (Details Narrative) HTML 66K
144: R126 Trade payables (Details) HTML 72K
145: R127 Trade payables (Details Narrative) HTML 65K
146: R128 Taxes (Details) HTML 79K
147: R129 Taxes (Details 1) HTML 96K
148: R130 Taxes (Details 2) HTML 73K
149: R131 Taxes (Details 3) HTML 104K
150: R132 Taxes (Details 4) HTML 83K
151: R133 Taxes (Details 5) HTML 69K
152: R134 Taxes (Details 6) HTML 73K
153: R135 Taxes (Details 7) HTML 95K
154: R136 Taxes (Details Narrative) HTML 97K
155: R137 Employee benefits (Details) HTML 75K
156: R138 Employee benefits (Details 1) HTML 77K
157: R139 Employee benefits (Details 2) HTML 75K
158: R140 Employee benefits (Details 3) HTML 78K
159: R141 Employee benefits (Details 4) HTML 81K
160: R142 Employee benefits (Details 5) HTML 76K
161: R143 Employee benefits (Details 6) HTML 110K
162: R144 Employee benefits (Details 7) HTML 129K
163: R145 Employee benefits (Details 8) HTML 123K
164: R146 Employee benefits (Details 9) HTML 119K
165: R147 Employee benefits (Details 10) HTML 108K
166: R148 Employee benefits (Details 11) HTML 85K
167: R149 Employee benefits (Details 12) HTML 110K
168: R150 Employee benefits (Details 13) HTML 72K
169: R151 Employee benefits (Details 14) HTML 102K
170: R152 Employee benefits (Details 15) HTML 81K
171: R153 Employee benefits (Details Narrative) HTML 99K
172: R154 Provisions for legal proceedings, judicial HTML 75K
deposits and contingent liabilities (Details)
173: R155 Provisions for legal proceedings, judicial HTML 76K
deposits and contingent liabilities (Details 1)
174: R156 Provisions for legal proceedings, judicial HTML 74K
deposits and contingent liabilities (Details 2)
175: R157 Provisions for legal proceedings, judicial HTML 74K
deposits and contingent liabilities (Details 3)
176: R158 Provisions for legal proceedings, judicial HTML 74K
deposits and contingent liabilities (Details 4)
177: R159 Provisions for legal proceedings, judicial HTML 148K
deposits and contingent liabilities (Details 5)
178: R160 Provisions for legal proceedings, judicial HTML 73K
deposits and contingent liabilities (Details
Narrative)
179: R161 Provision for decommissioning costs (Details) HTML 77K
180: R162 Provision for decommissioning costs (Details 1) HTML 82K
181: R163 Provision for decommissioning costs (Details 2) HTML 73K
182: R164 Provision for decommissioning costs (Details 3) HTML 76K
183: R165 Provision for decommissioning costs (Details HTML 78K
Narrative)
184: R166 Other assets and liabilities (Details) HTML 109K
185: R167 The ?Lava Jato (Car Wash) Operation? and its HTML 67K
effects on the Company (Details Narrative)
186: R168 Commitment to purchase natural gas (Details HTML 70K
Narrative)
187: R169 Property, plant and equipment (Details) HTML 132K
188: R170 Property, plant and equipment (Details 1) HTML 79K
189: R171 Property, plant and equipment (Details 2) HTML 131K
190: R172 Property, plant and equipment (Details 3) HTML 94K
191: R173 Intangible assets (Details) HTML 106K
192: R174 Property, plant and equipment (Details Narrative) HTML 67K
193: R175 Impairment (Details) HTML 76K
194: R176 Impairment (Details 1) HTML 78K
195: R177 Impairment (Details 2) HTML 94K
196: R178 Impairment (Details 3) HTML 88K
197: R179 Impairment (Details 4) HTML 69K
198: R180 Impairment (Details 5) HTML 89K
199: R181 Impairment (Details 6) HTML 94K
200: R182 Exploration and evaluation of oil and gas reserves HTML 95K
(Details)
201: R183 Intangible assets (Details Narrative) HTML 136K
202: R184 Exploration and evaluation of oil and gas reserves HTML 80K
(Details 1)
203: R185 Exploration and evaluation of oil and gas reserves HTML 70K
(Details 2)
204: R186 Exploration and evaluation of oil and gas reserves HTML 76K
(Details 3)
205: R187 Exploration and evaluation of oil and gas reserves HTML 87K
(Details Narrative)
206: R188 Collateral for crude oil exploration concession HTML 70K
agreements (Details Narrative)
207: R189 Consortia (partnerships) in E&P activities HTML 88K
(Details)
208: R190 Consortia (partnerships) in E&P activities HTML 132K
(Details 1)
209: R191 Consortia (partnerships) in E&P activities HTML 72K
(Details 2)
210: R192 Consortia (partnerships) in E&P activities HTML 67K
(Details Narrative)
211: R193 Investments (Details) HTML 215K
212: R194 Investments (Details 1) HTML 107K
213: R195 Investments (Details 2) HTML 74K
214: R196 Investments (Details 3) HTML 116K
215: R197 Investments (Details 4) HTML 138K
216: R198 Investments (Details Narrative) HTML 84K
217: R199 Disposal of assets and other transactions HTML 81K
(Details)
218: R200 Disposal of assets and other transactions (Details HTML 88K
1)
219: R201 Disposal of assets and other transactions (Details HTML 113K
2)
220: R202 Disposal of assets and other transactions (Details HTML 73K
3)
221: R203 Disposal of assets and other transactions (Details HTML 76K
Narrative)
222: R204 Finance debt (Details) HTML 87K
223: R205 Finance debt (Details 1) HTML 71K
224: R206 Finance debt (Details 2) HTML 86K
225: R207 Finance debt (Details 3) HTML 79K
226: R208 Finance debt (Details 4) HTML 196K
227: R209 Finance debt (Details 5) HTML 84K
228: R210 Finance debt (Details 6) HTML 89K
229: R211 Finance debt (Details Narrative) HTML 85K
230: R212 Lease liability (Details) HTML 87K
231: R213 Lease liability (Details 1) HTML 143K
232: R214 Lease liabilities (Details 2) HTML 94K
233: R215 Lease liabilities (Details 3) HTML 69K
234: R216 Lease liability (Details Narrative) HTML 67K
235: R217 Equity (Details) HTML 73K
236: R218 Equity (Details 1) HTML 68K
237: R219 Equity (Details 2) HTML 85K
238: R220 Equity (Details 3) HTML 82K
239: R221 Equity (Details 4) HTML 70K
240: R222 Equity (Details 5) HTML 71K
241: R223 Equity (Details 6) HTML 78K
242: R224 Equity (Details Narrative) HTML 113K
243: R225 Risk management (Details) HTML 71K
244: R226 Risk management (Details 1) HTML 91K
245: R227 Risk management (Details 2) HTML 95K
246: R228 Risk management (Details 3) HTML 68K
247: R229 Risk management (Details 4) HTML 66K
248: R230 Risk management (Details 5) HTML 76K
249: R231 Risk management (Details 6) HTML 67K
250: R232 Risk management (Details 7) HTML 83K
251: R233 Risk management (Details 8) HTML 76K
252: R234 Risk management (Details 9) HTML 79K
253: R235 Risk management (Details 10) HTML 68K
254: R236 Risk management (Details 11) HTML 163K
255: R237 Risk management (Details 12) HTML 103K
256: R238 Risk management (Details 13) HTML 84K
257: R239 Risk management (Details 14) HTML 85K
258: R240 Related-party transactions (Details) HTML 103K
259: R241 Related-party transactions (Details 1) HTML 112K
260: R242 Related-party transactions (Details 2) HTML 73K
261: R243 Related-party transactions (Details 3) HTML 89K
262: R244 Supplemental information on statement of cash HTML 78K
flows (Details)
263: R245 Supplemental information on statement of cash HTML 69K
flows (Details 1)
264: R246 Supplemental information on statement of cash HTML 72K
flows (Details 2)
265: R247 Subsequent events (Details Narrative) HTML 67K
266: R248 Supplementary information on Oil and Gas HTML 96K
Exploration and Production (Unaudited) (Details)
267: R249 Supplementary information on Oil and Gas HTML 86K
Exploration and Production (Unaudited) (Details 1)
268: R250 Supplementary information on Oil and Gas HTML 114K
Exploration and Production (Unaudited) (Details 2)
269: R251 Supplementary information on Oil and Gas HTML 96K
Exploration and Production (Unaudited) (Details 3)
270: R252 Supplementary information on Oil and Gas HTML 97K
Exploration and Production (Unaudited) (Details 4)
271: R253 Supplementary information on Oil and Gas HTML 102K
Exploration and Production (Unaudited) (Details 5)
272: R254 Supplementary information on Oil and Gas HTML 121K
Exploration and Production (Unaudited) (Details 6)
273: R255 Supplementary information on Oil and Gas HTML 91K
Exploration and Production (Unaudited) (Details 7)
274: R256 Supplementary information on Oil and Gas HTML 106K
Exploration and Production (Unaudited) (Details 8)
275: R257 Supplementary information on Oil and Gas HTML 67K
Exploration and Production (Unaudited) (Details
Narrative)
277: XML IDEA XML File -- Filing Summary XML 576K
280: XML XBRL Instance -- pbrform20f_2023_htm XML 14.29M
276: EXCEL IDEA Workbook of Financial Report Info XLSX 689K
15: EX-101.CAL XBRL Calculations -- pbr-20231231_cal XML 428K
16: EX-101.DEF XBRL Definitions -- pbr-20231231_def XML 2.74M
17: EX-101.LAB XBRL Labels -- pbr-20231231_lab XML 3.32M
18: EX-101.PRE XBRL Presentations -- pbr-20231231_pre XML 3.35M
14: EX-101.SCH XBRL Schema -- pbr-20231231 XSD 1.07M
278: JSON XBRL Instance as JSON Data -- MetaLinks 994± 1.37M
279: ZIP XBRL Zipped Folder -- 0001292814-24-001340-xbrl Zip 9.91M
5001 Spring Valley Road
Suite 800 East
Petróleo Brasileiro S.A.
Av. Henrique Valadares, 28
8th Floor – B tower – Centro
CEP 20231-030
Rio de Janeiro – RJ-Brazil
Ladies and Gentlemen:
Pursuant to your request, this report of third party presents an independent evaluation, as of December 31, 2023, of the estimated net proved oil, condensate, and gas reserves of certain properties in which Petróleo Brasileiro S.A. (Petrobras) has represented it holds an interest. The properties evaluated are located in Brazil. This evaluation was completed on February 7, 2024. Petrobras has represented that these properties account for 96.5 percent on a net equivalent barrel basis of Petrobras’ total net proved reserves as of December 31, 2023, and 97.0 percent of Petrobras’ net proved reserves in Brazil. Petrobras has represented that the net proved reserves estimates were prepared in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the United States Securities and Exchange Commission (SEC). It is our opinion that the procedures and methodologies employed by Petrobras for the preparation of its proved reserves estimates as of December 31, 2023, comply with the current requirements of the SEC. We have reviewed information provided by Petrobras that it represents to be Petrobras’ estimates of the net reserves, as of December 31, 2023, for the same properties as those which we evaluated. This report was prepared in accordance with guidelines specified in Item 1202 (a)(8) of Regulation S–K and is to be used for inclusion in certain SEC filings by Petrobras.
Reserves estimates included herein are expressed as net reserves as represented by Petrobras. Gross reserves are defined as the total estimated petroleum remaining to be produced from these properties after December 31, 2023. Net reserves are defined as that portion of the gross reserves attributable to the interests held by Petrobras after deducting all interests held by others.
Certain fields evaluated herein are subject to the terms of production sharing contracts (PSC). Net reserves for these fields are defined as that portion of the gross reserves attributable to the interest of Petrobras based on the terms of the PSCs. The terms of the PSCs generally allow for working interest participants to be reimbursed for capital costs and operating expenses as well as to share in the profits. The reimbursements and profit proceeds, net to Petrobras based on its working interest share, are converted to a volumetric equivalent by dividing by product prices to estimate the Petrobras “entitlement quantities.” These entitlement quantities are equivalent in principle to net reserves and are used to calculate an equivalent net share, termed an “entitlement interest.” Petrobras has advised that royalties for these fields are paid in cash, as per the terms of the PSCs, and has requested that the royalty volumes be included in the net reserves estimated herein.
Estimates of reserves should be regarded only as estimates that may change as further production history and additional information become available. Not only are such reserves estimates based on that information which is currently available, but such estimates are also subject to the uncertainties inherent in the application of judgmental factors in interpreting such information.
Information used in the preparation of this report was obtained from Petrobras. In the preparation of this report we have relied, without independent verification, upon information furnished by Petrobras with respect to the property interests being evaluated, production from such properties, current costs of operation and development, current prices for production, agreements relating to current and future operations and sale of production, and various other information and data that were accepted as represented. A field examination was not considered necessary for the purposes of this report.
Definition of Reserves
Petroleum reserves included in this report are classified as proved. Only proved reserves have been evaluated for this report. Reserves classifications used in this report are in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC. Reserves are judged to be economically producible in future years from known reservoirs under existing economic and operating conditions and assuming continuation of current regulatory practices using conventional production methods and equipment. In the analyses of production-decline curves, reserves were estimated only to the limit of economic rates of production under existing economic and operating conditions using prices and costs consistent with the effective date of this report, including consideration of changes in existing prices provided only by contractual arrangements but not including escalations based upon future conditions. The petroleum reserves are classified as follows:
Proved oil and gas reserves – Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.
(i) The area of the reservoir considered as proved includes:
(A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.
(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.
(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.
(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:
(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.
(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be 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.
Developed oil and gas reserves – Developed oil and gas reserves are reserves of any category 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 by means not involving a well.
Undeveloped oil and gas reserves – Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.
(i) Reserves on undrilled acreage shall be 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.
(ii) Undrilled locations can be 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.
(iii) Under no circumstances shall estimates for undeveloped reserves be 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, as defined in [section 210.4–10 (a) Definitions], or by other evidence using reliable technology establishing reasonable certainty.
Methodology and Procedures
Estimates of reserves were prepared by the use of appropriate geologic, petroleum engineering, and evaluation principles and techniques that are in accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC and with practices generally recognized by the petroleum industry as presented in the publication of the Society of Petroleum Engineers entitled “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information (revised June 2019) Approved by the SPE Board on 25 June 2019.” The method or combination of methods used in the analysis of each reservoir was tempered by experience with similar reservoirs, stage of development, quality and completeness of basic data, and production history.
Based on the current stage of field development, production performance, the development plans provided by Petrobras, and analyses of areas offsetting existing wells with test or production data, reserves were classified as proved.
The undeveloped reserves estimated herein were based on opportunities identified in the plan of development provided by Petrobras.
Petrobras has represented that its senior management is committed to the development plan provided by Petrobras and that Petrobras has the financial capability to execute the development plan, including the drilling and completion of wells and the installation of equipment and facilities.
The volumetric method was used to estimate the original oil in place (OOIP) and original gas in place (OGIP) for the fields, as required. For those fields that required volumetric evaluation, geologic models provided by Petrobras were reviewed and found to reasonably represent the distribution of reservoir properties and quantities of OOIP and OGIP. When applicable, structure maps were prepared to delineate each reservoir, and isopach maps were constructed to estimate reservoir volume. Electrical logs, radioactivity logs, core analyses, and other available data were used to prepare these maps.
Estimates of ultimate recovery took into account the type of energy inherent in the reservoir, as well as reservoir and well performance. Reservoir fluid properties, relative permeability, and other reservoir data were analyzed, and appropriate characterizations were generated for this analysis. In certain fields, a review was made of reservoir simulation studies performed by Petrobras. The available data related to future field development were also examined. In reservoirs where enhanced recovery methods had been implemented or were scheduled, recovery efficiency was estimated by fractional flow analysis and other engineering methods. Where adequate data were available, ultimate recovery was estimated using the material-balance method.
For depletion-type reservoirs or those whose performance disclosed a reliable decline in producing-rate trends or other diagnostic characteristics, reserves were estimated by the application of appropriate decline curves or other performance relationships.
In certain cases, reserves were estimated by incorporating elements of analogy with similar wells or reservoirs for which more complete data were available.
Estimates of reserves were limited to the economic limit as defined under the Definition of Reserves heading of this report or the expiration date of a fiscal agreement, whichever occurs first. In addition, reserves for the Atapu, Itapu, Sépia, Búzios, Sul de Berbigão, and Sul de Tupi fields were also limited by the terms of the Cessão Onerosa agreement as represented by Petrobras and described herein.
Petrobras has further represented that the Cessão Onerosa (also known as Transfer of Rights) terms are part of an agreement between Petrobras and the government of Brazil signed in September 2010 in which Petrobras made payment to the government of Brazil for the rights to produce up to a total of 5 billion barrels of oil equivalent (boe) from the fields included in this agreement (the Cessão Onerosa agreement). In the Cessão Onerosa agreement, Petrobras was assigned a specific quantity for each field. For the Búzios, Atapu, Sépia, Itapu, Sul de Tupi, and Sul de Berbigão fields, the assigned quantities were 3.15 billion boe, 0.55 billion boe, 0.50 billion boe, 0.35 billion boe, 0.35 billion boe, and 0.10 billion boe, respectively. The Surplus Quantities for the Búzios, Atapu, Itapu, and Sépia fields are the estimated quantities of potentially recoverable oil and gas in excess of the quantities assigned to Petrobras for each field under the terms of the Cessão Onerosa agreement. The Surplus Quantities are part of various agreements between the government of Brazil and a consortium (for the Búzios, Atapu, and Sépia fields) or between the government of Brazil and Petrobras (for the Itapu field). The tract participation factors for the Surplus Quantities were approved in 2021 by the Agência Nacional do Petróleo, Gás Natural e Biocombustíveis (ANP). At the request of Petrobras, the Surplus Quantities from the Búzios, Atapu, Sépia, and Itapu fields are referred to herein as the Búzios Eco, Atapu Eco, Sépia Eco, and Itapu Eco fields, respectively.
Data provided by Petrobras from wells drilled through December 31, 2023, and made available for this evaluation were used to prepare the reserves estimates herein. These reserves estimates were based on consideration of monthly production data available for certain properties only through September or October 2023. Estimated cumulative production, as of December 31, 2023, was deducted from the estimated gross ultimate recovery to estimate gross reserves. This required that production be estimated for up to 3 months.
Oil and condensate reserves estimated herein are to be recovered by normal field separation. Oil and condensate reserves reported herein are expressed in millions of barrels (106bbl). In these estimates, 1 barrel equals 42 United States gallons. For reporting purposes, oil and condensate reserves have been estimated separately and are presented herein as a summed quantity.
Gas quantities estimated herein are expressed as natural gas and fuel gas. Natural gas is defined as the total gas to be produced from the reservoirs after reduction for injection, flare, and shrinkage resulting from field separation and processing but not from fuel usage. Fuel gas is defined as that portion of the gas consumed in field operations and is included in the natural gas and is estimated herein as reserves. Gas quantities are expressed at a temperature base of 20 degrees Celsius (°C) and at a pressure base of 1 atmosphere (atm). Gas quantities included in this report are expressed in billions of cubic feet (109ft3).
Gas quantities are identified by the type of reservoir from which the gas will be produced. Nonassociated gas is gas at initial reservoir conditions with no oil present in the reservoir. Associated gas is both gas-cap gas and solution gas. Gas-cap gas is gas at initial reservoir conditions and is in communication with an underlying oil zone. Solution gas is gas dissolved in oil at initial reservoir conditions. Gas quantities estimated herein include both associated and nonassociated gas.
At the request of Petrobras, gas reserves estimated herein were converted to oil equivalent using an energy equivalent factor of 5,614.65 cubic feet of gas per 1 barrel of oil equivalent.
Primary Economic Assumptions
This report has been prepared using initial prices, expenses, and costs provided by Petrobras. Prices were provided in United States dollars (U.S.$) and expenses and costs were provided in Brazilian reais (R$) and U.S.$. Future prices were estimated using guidelines established by the SEC and the Financial Accounting Standards Board (FASB). The following economic assumptions were used for estimating the reserves reported herein:
Oil and Condensate Prices
Petrobras has represented that the oil and condensate prices were based on a reference price, 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, unless prices are defined by contractual agreements. Petrobras supplied differentials by field to a Brent reference price of U.S.$83.27 per barrel. The volume-weighted average adjusted price attributable to the estimated proved reserves over the lives of the fields was U.S.$79.36 per barrel of oil and condensate. These prices were not escalated for inflation.
Gas Prices
Petrobras has represented that the gas prices were based on a 12-month average price, 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, unless prices are defined by contractual agreements. The volume-weighted average adjusted price attributable to the estimated proved reserves over the lives of the fields was U.S.$5.94 per thousand cubic feet (103ft3) of gas. This price was based on contract prices and the 12-month average regulation prices from the ANP, as provided by Petrobras. The ANP regulation prices are the prices disclosed by the ANP to upstream operators for payment of royalties and taxes. These prices were not escalated for inflation.
Operating Expenses, Capital Costs, and Abandonment Costs
Estimates of operating expenses, provided by Petrobras and based on existing economic conditions, were held constant for the lives of the properties. Future capital expenditures were estimated using 2023 values, provided by Petrobras, and were not adjusted for inflation. In certain cases, future expenditures, either higher or lower than current expenditures, may have been used because of anticipated changes in operating conditions, but no general escalation that might result from inflation was applied. Estimates of abandonment costs, which are those costs associated with the removal of equipment, plugging of wells, and reclamation and restoration associated with the abandonment, were provided by Petrobras and included as an operating expense in the relevant year. Estimates of operating expenses, capital costs, and abandonment costs were considered, as appropriate, in determining the economic viability of the undeveloped reserves estimated herein.
Exchange Rate
An exchange rate of R$5.01 per U.S.$1.00 was provided by Petrobras and used to convert the respective currencies, as needed.
In our opinion, the information relating to estimated proved reserves of oil, condensate, and gas contained in this report has been prepared in accordance with Paragraphs 932-235-50-7 and 932-235-50-9 of the Accounting Standards Update 932-235-50, Extractive Industries – Oil and Gas (Topic 932): Oil and Gas Reserve Estimation and Disclosures (January 2010) of the FASB and Rules 4–10(a) (1)–(32) of Regulation S–X and Rules 302(b), 1201, 1202 (3), (4), (8), and 1203(a) of Regulation S–K of the SEC; provided, however, that estimates of proved developed and proved undeveloped reserves are not presented at the beginning of the year.
To the extent the above-enumerated rules, regulations, and statements require determinations of an accounting or legal nature, we, as engineers, are necessarily unable to express an opinion as to whether the above-described information is in accordance therewith or sufficient therefor.
Summary of Conclusions
DeGolyer and MacNaughton has performed an independent evaluation of the extent of the estimated net proved oil, condensate, and gas reserves of certain properties in which Petrobras has represented it holds an interest. Petrobras has represented that its estimated net proved reserves attributable to the evaluated properties were based on the definition of proved reserves of the SEC. Petrobras’ estimates of the net proved reserves, as of December 31, 2023, attributable to these properties, which represent 96.5 percent of Petrobras’ reserves on a net equivalent basis, are summarized as follows, expressed in millions of barrels (106bbl), billions of cubic feet (109ft3), and millions of barrels of oil equivalent (106boe):
|
Estimated by Petrobras Net Proved Reserves as of | ||||||
|
Oil and Condensate (106bbl) |
Natural Gas (109ft3) |
Oil Equivalent (106boe) | ||||
|
Properties Evaluated by |
||||||
| Brazil | ||||||
| Proved Developed | 4,507.2 | 5,308.3 | 5,452.6 | |||
| Proved Undeveloped | 4,418.3 | 3,777.5 | 5,091.1 | |||
| Total Proved | 8,925.5 | 9,085.8 | 10,543.7 | |||
|
Notes: 1. Natural gas reserves estimated herein were converted to oil equivalent using an energy equivalent factor of 5,614.65 cubic feet of gas per 1 barrel of oil equivalent. 2. The natural gas reserves estimated herein include fuel gas. The fuel gas portion of the natural gas reserves estimated herein represents 25.8 percent of the proved developed natural gas reserves, 49.2 percent of the proved undeveloped natural gas reserves, and 35.5 percent of the total proved natural gas reserves. | ||||||
In comparing the detailed net proved reserves estimates prepared by DeGolyer and MacNaughton and by Petrobras, differences have been found, both positive and negative, resulting in an aggregate difference of 0.08 percent when compared on the basis of net equivalent barrels. It is DeGolyer and MacNaughton’s opinion that the net proved reserves estimates prepared by Petrobras on the properties reviewed and referred to above, when compared on the basis of net equivalent barrels, in aggregate, do not differ materially from those prepared by DeGolyer and MacNaughton.
While the oil and gas industry may be subject to regulatory changes from time to time that could affect an industry participant’s ability to recover its reserves, we are not aware of any such governmental actions which would restrict the recovery of the December 31, 2023, estimated reserves.
DeGolyer and MacNaughton is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1936. DeGolyer and MacNaughton does not have any financial interest, including stock ownership, in Petrobras. Our fees were not contingent on the results of our evaluation. This report has been prepared at the request of Petrobras. DeGolyer and MacNaughton has used all assumptions, data, procedures, and methods that it considers necessary and appropriate to prepare this report.
Submitted,
Texas Registered Engineering Firm F-716
/s/ Federico Dordoni | |
[SEAL] |
Federico Dordoni, P.E. |
Executive Vice President | |
CERTIFICATE of QUALIFICATION
I, Federico Dordoni, Petroleum Engineer with DeGolyer and MacNaughton, 5001 Spring Valley Road, Suite 800 East, Dallas, Texas, 75244 U.S.A., hereby certify:
| 1. | That I am an Executive Vice President with DeGolyer and MacNaughton, which firm did prepare the report
of third party addressed to Petrobras dated February 7, 2024, and that I, as Executive Vice President, was responsible for the preparation of this report of third party. |
| 2. | That I attended Buenos Aires Institute of Technology (ITBA) University, and that I graduated with a degree in Petroleum Engineering in the year 2004; that I am a Registered Professional Engineer in the State of Texas; that I am a member of the Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers; and that I have in excess of 18 years of experience in oil and gas reservoir studies and reserves evaluations. |
/s/ Federico Dordoni | |
[SEAL] |
Federico Dordoni, P.E. |
Executive Vice President | |
| This ‘20-F’ Filing | Date | Other Filings | ||
|---|---|---|---|---|
 | ||||
| Filed as of: | 4/12/24 | 6-K | ||
| Filed on: | 4/11/24 | 6-K | ||
| 2/7/24 | ||||
| For Period end: | 12/31/23 | 6-K, 6-K/A | ||
| List all Filings | ||||