Oil and Gas Reserve Estimation and Disclosures (unaudited) The following tables provide supplementary information in respect of the Group’s oil and gas activities. In the absence of detailed disclosure rules in this area under IFRS, the Group has elected to voluntarily disclose the data that would have been required under the ASC 932 as if it was reporting under US GAAP. To the extent that information refers to financial statements data, the information is based on the primary financial statements (IFRS financial statements). The regional structure is presented below*Regions listed in the Director’s Report ‘Central and Eastern Europe’ (includes Romania and Black Sea as well as Austria) and ‘Asia-Pacific’ (includes New Zea-land and Australia as well as Malaysia) are split further in this disclosure to provide the information in a more detailed manner. : Romania and Black Sea Bulgaria, Kazakhstan (until May 2021) and Romania Austria Austria Russia Russia North Sea Norway Middle East and Africa Iran (evaluation on hold), Kurdistan Region of Iraq, Libya, Tunisia, United Arab Emirates, Yemen, Madagascar (until 2019) New Zealand and Australia Australia and New Zealand Malaysia SapuraOMV*Includes not only Malaysia but also SapuraOMV subsidiaries in New Zealand, Australia and Mexico. Acquisitions There were no major acquisitions during 2021 and 2020. On January 31, 2019, OMV acquired a 50% stake of the issued share capital in SapuraOMV Upstream Sdn. Bhd. As OMV has the decision power over relevant activities, the new entity and its subsidiaries are fully consolidated. Besides future growth in daily production in Malaysian offshore gas fields, this transaction gives OMV access to exploration blocks in New Zealand, Australia and Mexico. SapuraOMV Upstream Sdn. Bdn. and its subsidiaries are depicted in the Malaysia region in the upcoming tables. Disposals As per May 14, 2021, OMV Petrom finalized the sale of its 100% share in Kom-Munai LLP and Tasbulat Oil Corporation LLP (both based in Aktau, Kazakhstan). On August 1, 2021, SapuraOMV Upstream Sdn. Bhd. sold its share in SapuraOMV Upstream (PM) Inc., which held interests in various producing assets located offshore Peninsular Malaysia. There were no major disposals during 2020 and 2019. Non-controlling interest As OMV holds 51% of OMV Petrom, it is fully consolidated; figures therefore include 100% of OMV Petrom assets and results. OMV has a share of 50% in SapuraOMV and it is fully consolidated; figures therefore include 100% of SapuraOMV assets and results. Equity-accounted investments OMV holds a 10% interest in Pearl Petroleum Company Limited (Middle East and Africa region). OMV has a 24.99% interest in OJSC Severneftegazprom (Russia region). The disclosures of equity-accounted investments in below tables represent the interest of OMV in the companies. The subsequent tables may contain rounding differences. Tables a) Capitalized costs Capitalized costs represent the sum of capitalized oil and gas assets, including other intangible assets and property, plant and equipment such as land, plant and machinery, concessions, licenses and rights. (XLSX:) Download Capitalized costs – subsidiaries In EUR mn 2021 2020 2019 Unproved oil and gas properties 2,137 2,461 3,211 Proved oil and gas properties 27,611 26,988 26,830 Total 29,749 29,449 30,041 Accumulated depreciation (18,136) (17,117) (15,484) Net capitalized costs 11,613 12,333 14,557 (XLSX:) Download Capitalized costs – equity-accounted investments In EUR mn 2021 2020 2019 Unproved oil and gas properties 164 154 173 Proved oil and gas properties 477 346 315 Total 641 501 489 Accumulated depreciation (99) (76) (67) Net capitalized costs 542 424 421 b) Costs incurred Costs incurred include all costs, capitalized or expensed, during the year in the Group’s oil and gas property acquisition, exploration and development activities. (XLSX:) Download Costs incurred In EUR mn Romania and Black Sea Austria Russia North Sea Middle East and Africa New Zealand and Australia Malaysia Total 2021 Subsidiaries Acquisition of proved properties — — — — — — — — Acquisition of unproved properties 1 — — 0 — — 1 3 Exploration costs 41 6 — 81 25 26 30 210 Development costs 265 38 — 243 165 102 39 852 Costs incurred 307 44 — 324 191 128 70 1,065 Equity-accounted investments — — 62 — 21 — — 83 2020 Subsidiaries Acquisition of proved properties — — — — — — — — Acquisition of unproved properties — — — — — — — — Exploration costs 51 25 — 55 17 46 32 227 Development costs 330 20 — 187 163 60 19 778 Costs incurred 380 45 — 242 180 106 51 1,005 Equity-accounted investments — — 55 — 7 — — 62 2019 Subsidiaries Acquisition of proved properties — — — 1 — 1 604 605 Acquisition of unproved properties — — — — 12 — 683 695 Exploration costs 93 53 — 121 32 40 20 360 Development costs 411 58 — 174 222 65 90 1,021 Costs incurred 504 112 — 296 266 105 1,398 2,681 Equity-accounted investments — — 30 — 15 — — 45 c) Results of operations of oil and gas producing activities The following tables represent only those revenues and expenses which occur directly in connection with OMV´s oil and gas producing operations. The results of oil and gas activities should not be equated to Exploration & Production net income since interest costs, general corporate overhead costs and other costs are not allocated. Income taxes are hypothetically calculated, based on the statutory tax rates and the effect of tax credits on investments and loss carryforwards. (XLSX:) Download Results of operations of oil and gas producing activities In EUR mn Romania and Black Sea Austria Russia North Sea Middle East and Africa New Zealand and Australia Malaysia Total 2021 Subsidiaries Sales to unaffiliated parties1 22 (649) 562 876 556 279 239 1,884 Intercompany sales 1,845 432 — 1,345 1,018 122 — 4,762 1,868 (218) 562 2,221 1,574 400 239 6,646 Production costs (477) (78) — (144) (146) (81) (24) (950) Royalties (404) (66) — — (135) (39) (13) (658) Exploration expenses2 (43) (5) — (108) (43) (18) (65) (281) Depreciation, amortization, impairments and write-ups (499) (102) (70) (381) (246) (127) (101) (1,526) Other costs3 (70) (14) (329) (132) (25) (5) (21) (597) (1,493) (265) (399) (766) (596) (270) (223) (4,012) Results before income taxes 375 (483) 163 1,455 979 130 15 2,635 Income taxes4 (59) 121 (27) (981) (750) (38) (6) (1,740) Results from oil and gas production 316 (362) 135 475 229 92 10 895 Results of equity-accounted investments — — 24 — 31 — — 55 2020 Subsidiaries Sales to unaffiliated parties1 57 (25) 389 569 102 228 209 1,529 Intercompany sales 1,203 186 — 269 365 102 — 2,125 1,260 161 389 838 467 330 209 3,654 Production costs (472) (77) — (144) (125) (77) (24) (920) Royalties (180) (40) — — (67) (34) (4) (325) Exploration expenses2 (179) (96) — (56) (298) (201) (67) (896) Depreciation, amortization, impairments and write-ups (538) (223) (74) (309) (226) (384) (126) (1,880) Other costs3 (63) (16) (343) (135) (14) (23) (26) (619) (1,432) (452) (417) (644) (730) (719) (246) (4,641) Results before income taxes (172) (291) (28) 194 (263) (389) (38) (987) Income taxes4 25 107 5 (122) 118 107 (16) 224 Results from oil and gas production (148) (184) (23) 72 (145) (282) (53) (763) Results of equity-accounted investments — — 15 — 16 — — 31 2019 Subsidiaries Sales to unaffiliated parties1 94 19 550 891 527 335 171 2,586 Intercompany sales 1,909 324 — 379 822 191 — 3,624 2,002 343 550 1,270 1,348 526 171 6,210 Production costs (500) (82) — (158) (124) (98) (30) (991) Royalties (250) (62) — — (103) (65) (16) (496) Exploration expenses2 (53) (45) — (73) (16) (24) (18) (229) Depreciation, amortization, impairments and write-ups (553) (119) (91) (414) (233) (199) (73) (1,681) Other costs3 (93) (29) (429) (132) (45) (20) (13) (761) (1,449) (336) (520) (777) (520) (407) (149) (4,159) Results before income taxes 553 7 30 493 828 119 21 2,051 Income taxes4 (88) 1 (5) (402) (675) (25) (28) (1,222) Results from oil and gas production 465 8 24 91 153 94 (7) 829 Results of equity-accounted investments — — 34 — 11 — — 45 1 Includes hedging effects; Austria Region includes hedging effects of centrally managed derivatives (2021: EUR (675) mn, 2020: EUR (37) mn, 2019: EUR 2 mn). 2 Including impairment losses related to exploration&appraisal 3 Includes inventory changes 4 Income taxes in North Sea and Middle East and Africa include corporation tax and special petroleum tax. d) Oil and gas reserve quantities Proved 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 regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain. Proved oil and gas reserves were estimated based on a 12-month average price, unless prices are defined by contractual arrangements. Proved developed reserves are those proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods, or in which the costs of the required equipment are relatively minor compared with the cost of a new well and through installed extraction equipment and infrastructure operational at the time of the reserves estimate. It should be reasonably certain that the required future expenditure will be made to safeguard existing equipment within the current budget. Proved undeveloped reserves are those proved reserves 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 or substantial new investment is required in order to safeguard or replace ageing facilities. (XLSX:) Download Crude oil and NGL in mn bbl Romania and Black Sea Austria Russia North Sea Middle East and Africa New Zealand and Australia Malaysia Total Proved developed and undeveloped reserves – Subsidiaries January 1, 2019 324.4 37.0 — 48.4 208.3 10.2 — 628.3 Revisions of previous estimates 20.2 2.1 — 13.3 26.7 6.0 — 68.4 Purchases — — — — — — 9.5 9.5 Disposal (3.4) — — — — — — (3.4) Extensions and discoveries 0.1 — — 6.0 — — — 6.1 Production (26.1) (4.0) — (16.6) (21.8) (4.6) (2.1) (75.2) December 31, 2019 315.2 35.2 — 51.1 213.2 11.6 7.4 633.7 Revisions of previous estimates 8.6 2.7 — 8.5 69.7 0.2 1.0 90.7 Purchases — — — — — — — — Disposal — — — — — — — — Extensions and discoveries 0.5 — — — — — — 0.5 Production (25.5) (3.8) — (15.1) (12.8) (3.8) (2.7) (63.7) December 31, 2020 298.8 34.0 — 44.5 270.2 8.0 5.7 661.2 Revisions of previous estimates 4.2 1.0 — 17.2 30.3 7.6 4.9 65.2 Purchases — — — — — — — — Disposal (21.4) — — — — — (2.4) (23.8) Extensions and discoveries 0.3 — — — — 0.8 — 1.0 Production (23.0) (3.6) — (15.3) (24.8) (3.5) (1.7) (71.9) December 31, 2021 258.8 31.4 — 46.4 275.7 12.9 6.5 631.7 Proved developed and undeveloped reserves – Equity-accounted investments December 31, 2019 — — — — 15.3 — — 15.3 December 31, 2020 — — — — 18.4 — — 18.4 December 31, 2021 — — — — 17.5 — — 17.5 Proved developed reserves – Subsidiaries December 31, 2019 287.2 35.2 — 37.2 179.7 7.8 5.7 552.7 December 31, 2020 273.1 33.9 — 32.7 172.7 5.6 5.7 523.8 December 31, 2021 234.2 31.4 — 40.7 189.2 6.0 1.6 503.2 Proved developed reserves – Equity-accounted investments December 31, 2019 — — — — 14.9 — — 14.9 December 31, 2020 — — — — 15.7 — — 15.7 December 31, 2021 — — — — 14.7 — — 14.7 (XLSX:) Download Gas In mn bcf Romania and Black Sea Austria Russia North Sea Middle East and Africa New Zealand and Australia Malaysia Total Proved developed and undeveloped reserves – Subsidiaries January 1, 2019 1,124.7 196.8 — 429.4 55.5 235.6 — 2,041.9 Revisions of previous estimates 58.2 10.1 — 76.0 9.6 145.4 — 299.3 Purchases — — — — — — 351.2 351.2 Disposals (6.3) — — — — — — (6.3) Extensions and discoveries 2.2 — — 7.4 — — — 9.5 Production (158.0) (29.2) — (90.0) (3.2) (65.2) (15.5) (360.9) December 31, 20191 1,020.7 177.8 — 422.8 61.9 315.8 335.7 2,334.7 Revisions of previous estimates 61.3 2.5 — 58.3 27.5 (62.8) 93.9 180.7 Purchases — — — — — — — — Disposals — — — — — — — — Extensions and discoveries 7.2 — — — — — — 7.2 Production (148.6) (24.9) — (97.5) (7.0) (57.7) (53.3) (389.0) December 31, 20201 940.7 155.3 — 383.6 82.4 195.3 376.3 2,133.6 Revisions of previous estimates 76.2 17.7 — 7.8 80.7 115.3 212.0 509.6 Purchases — — — — — — — — Disposals (22.3) — — — — — (9.1) (31.5) Extensions and discoveries 1.5 — — — — 15.4 — 17.0 Production (130.6) (20.6) — (102.3) (17.3) (51.8) (64.5) (387.0) December 31, 20211 865.5 152.4 — 289.2 145.8 274.2 514.7 2,241.7 Proved developed and undeveloped reserves – Equity-accounted investments December 31, 2019 — — 1,376.8 — 277.3 — — 1,654.1 December 31, 2020 — — 1,321.0 — 383.8 — — 1,704.8 December 31, 2021 — — 1,167.1 — 369.2 — — 1,536.4 Proved developed reserves – Subsidiaries December 31, 2019 923.0 110.2 — 407.8 57.4 203.2 124.0 1,825.5 December 31, 2020 851.9 76.1 — 335.7 55.2 143.5 376.3 1,838.7 December 31, 2021 779.5 84.0 — 287.0 62.5 115.4 291.9 1,620.2 Proved developed reserves – Equity-accounted investments December 31, 2019 — — 880.2 — 262.9 — — 1,143.1 December 31, 2020 — — 1,003.1 — 293.5 — — 1,296.6 December 31, 2021 — — 1,090.7 — 278.9 — — 1,369.7 1 2021: Including approximately 67.6 bcf of cushion gas held in storage reservoirs2020: Including approximately 67.6 bcf of cushion gas held in storage reservoirs2019: Including approximately 67.6 bcf of cushion gas held in storage reservoirs e) Standardized measure of discounted future net cash flows The future net cash flow information is based on the assumption that the prevailing economic and operating conditions will persist throughout the time during which proved reserves will be produced. Neither the effects of future pricing changes nor expected changes in technology and operating practices are considered. Future cash inflows represent the revenues received from production volumes, including cushion gas held in storage reservoirs, assuming that the future production is sold at prices used in estimating year-end quantities of proved reserves (12 months average price). Future production costs include the estimated expenditures for production of the proved reserves plus any production taxes without consideration of future inflation. Future decommissioning costs comprise the net costs associated with decommissioning wells and facilities. Future development costs include the estimated costs of development drilling and installation of production facilities. For all three categories year-end costs without consideration of inflation are assumed. Future income tax payments are calculated on the basis of the income tax rate applicable in each of the countries in which the Group operates. The present cash value results from the discounting of the future net cash flow at a discount rate of 10% per year. The standardized measure does not purport to be an estimate of the fair value of the Group’s proven reserves. An estimate of fair value would also take into account, amongst many other factors, the expected recovery of reserves in excess of proved reserves, anticipated changes in future prices and costs as well as a discount factor representative of the risks inherent in the production of oil and gas. (XLSX:) Download Standardized measure of discounted future net cash flows In EUR mn Subsidiaries and equity-accounted investments Romania and Black Sea Austria Russia North Sea Middle East and Africa New Zealand and Australia Malaysia Total 2021 Subsidiaries Future cash inflows 17,585 3,336 2,625 5,608 16,545 1,905 1,433 49,038 Future production and decommissioning costs (9,221) (1,612) (2,148) (2,293) (5,419) (1,647) (490) (22,831) Future development costs (1,422) (246) — (281) (776) (380) (257) (3,362) Future net cash flows, before income taxes 6,942 1,479 477 3,034 10,350 (122) 685 22,845 Future income taxes (577) (264) (97) (2,541) (6,893) 116 (175) (10,432) Future net cash flows, before discount 6,366 1,214 380 493 3,457 (6) 510 12,413 10% annual discount for estimated timing of cash flows (3,089) (630) (71) (109) (1,100) 175 (216) (5,040) Standardized measure of discounted future net cash flows 3,276 584 309 384 2,357 169 294 7,373 Equity-accounted investments — — 187 — 336 — — 523 2020 Subsidiaries Future cash inflows 12,167 1,513 2,497 2,628 9,914 928 959 30,607 Future production and decommissioning costs (7,748) (1,159) (2,276) (1,857) (3,907) (1,257) (450) (18,654) Future development costs (1,632) (297) — (373) (698) (226) (24) (3,249) Future net cash flows, before income taxes 2,787 58 220 399 5,308 (554) 486 8,704 Future income taxes (69) — (60) (1) (2,954) 199 (104) (2,990) Future net cash flows, before discount 2,718 58 160 397 2,354 (355) 382 5,714 10% annual discount for estimated timing of cash flows (1,038) (5) 1 (40) (696) 153 (103) (1,727) Standardized measure of discounted future net cash flows 1,680 53 161 357 1,659 (202) 279 3,987 Equity-accounted investments — — 100 — 233 — — 333 2019 Subsidiaries Future cash inflows 19,932 2,554 3,402 4,432 12,597 1,972 1,246 46,135 Future production and decommissioning costs (9,156) (1,704) (2,779) (2,196) (3,398) (1,785) (461) (21,480) Future development costs (2,081) (370) — (527) (563) (325) (36) (3,901) Future net cash flows, before income taxes 8,696 479 622 1,709 8,637 (138) 749 20,754 Future income taxes (819) (21) (125) (959) (5,188) 101 (178) (7,191) Future net cash flows, before discount 7,877 458 497 750 3,448 (37) 570 13,563 10% annual discount for estimated timing of cash flows (3,918) (47) (117) (286) (1,025) 184 (126) (5,334) Standardized measure of discounted future net cash flows 3,960 411 381 464 2,424 147 444 8,230 Equity-accounted investments — — 101 — 136 — — 238 f) Changes in the standardized measure of discounted future net cash flows (XLSX:) Download Changes in the standardized measure of discounted future net cash flows In EUR mn 2021 2020 2019 Subsidiaries Beginning of year 3,987 8,230 9,304 Oil and gas sales produced, net of production costs (2,262) (3,397) (3,942) Net change in prices and production costs 8,231 (7,040) (1,810) Net change due to purchases and sales of minerals in place (67) — 531 Net change due to extensions and discoveries 5 22 72 Development and decommissioning costs incurred during the period 657 1,031 674 Changes in estimated future development and decommissioning costs (269) 259 (398) Revisions of previous reserve estimates 1,854 757 1,216 Accretion of discount 341 732 828 Net change in income taxes (incl. tax effects from purchases and sales) (4,935) 3,625 1,646 Other1 (168) (232) 108 End of year 7,373 3,987 8,230 Equity-accounted investments 523 333 238 1 Contains movements in foreign exchange rates vs. the EUR schließen IFRSs International Financial Reporting Standards schließen Pearl Pearl Petroleum Company Limited schließen net income Net operating profit or loss after interest and tax 38 – Direct and indirect investments of OMV AktiengesellschaftExecutive Board