Earnings release
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https://investors.ypf.com Webcast on Oct 29, 2026 9:00 am ET / 10:00 am BAT MARGARITA CHUN – IR MANAGER VALENTINA LÓPEZ – IR CHRISTIAN GONZÁLEZ – IR INVESTOR RELATIONS CENTER Inversoresypf@ypf.com IR TEAM CLICK HERE 3Q26 Margarita.chun@ypf.com
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Page 2/13 YPF 3Q26 3Q26 YPF MAIN HIGHLIGHTS OF 3Q26 In US$ million, unless noted otherwise. EBITDA = Operating income + Depreciation of PP&E + Depreciation of the right of use a ssets + Amortization of intangible assets + Unproductive exploratory drillings + (Reversal) / Deterioration of PP&E. Adjusted EBITDA = EBITDA that excludes IFRS 16 effects +/- one-off items. Net Leverage Ratio = Net Debt / LTM Adj. EBITDA. FCF = Cash flow from Operations less CAPEX (Investing activities) , M&A (Investing activities), and interest and leasing payments (Financing activit ies). Fuels = diesel + gasoline. R&M is refining and marketing business, excluding petrochemicals, figures restated due to reallocation of agribusiness from Midstream & Downstream to New Energies segment. (1) Includes additional 4.9% of Bandurria Sur block as from May-26, not consolidated in YPF balance sheet. (2) Underlying lifting costs exclude specific well servicing costs. Including them, lifting costs would have been (US$/BOE, total and shale oil hub, respectively): 8.1 and 5.0 (3Q26); 8.7 and 4.7 (2Q26); 8.8 and 4.3 (3Q25); 8.6 and 4.6 (9M26); and 12.2 and 4.5 (9M25). (3) Local Fuels Volume Sold & Imported Fuels include Refinor as from Oct-25. Adjusted EBITDA reached US$2,503 million ( -11% q/q; +84% y/y), YPF’s second-highest quarterly result after the record set in 2Q26. The Adjusted EBITDA margin remained strong at 38%. The sequential decline primarily reflected inventory valuation effects and lower refined product realizations prices as international prices declined in 3Q26. These impacts were partly offset by seasonally higher natural gas sales and lower price-linked costs, mainly third-party crude purchases, royalties and other taxes. Year-on-year growth was primarily driven by higher pricing environment, lower lifting costs as exposure to conventional assets declined, combined with growing shale output and increased refinery throughput. CAPEX totaled US$1,287 million (-4% q/q; +26% y/y), with 70% allocated to unconventional operations. The sequential decline mainly reflected the signing bonus accrued in 2Q26 for unconventional concessions covering five blocks dedicated to the Argentina LNG Project, partly offset by increased drilling and workover activity in 3Q26. Shale oil production averaged 224 kbbl/d (+5% q/q; +32% y/y), accounting for 86% of total oil production, up from 80% in 2Q26 and 71% in 3Q25. We remain firmly on track to meet our 2026 average production target of 215 kbbl/d and comfortably achieve a December 2026 exit rate of 250 kbbl/d. YPF acquired the remaining 25% stake in YPF Luz for US$430 million through acquisition financing, bringing ownership to 100% and fully consolidating the company. The transaction positions YPF to capture the value of a leading power generation platform, with long-term growth opportunities in efficient thermal generation and renewables. Refinery throughput remained strong at 344 kbbl/d (-2% q/q; +5% y/y). Despite scheduled maintenance at La Plata in September 2026, YPF again met domestic demand without fuel imports, increased fuel exports and achieved record premium gasoline production in 3Q26. Free cash flow reached US$901 million (+US$77 million q/q; +US$1.7 billion y/y), YPF’s second-highest quarterly result. Strong Adjusted EBITDA and initial proceeds from the sales of Metrogas and the Mendoza Non-Operated and Chachahuen conventional clusters comfortably covered CAPEX and regular interest and income tax payments. Consequently, net leverage declined to 0.8x, its lowest level in a decade. In September 2026, YPF returned to international capital markets with a US$1.2 billion 9-year bond at a 7.85% yield and a record-low spread for YPF of ~300 basis points over U.S. Treasuries. A portion of the proceeds pre-funded 2027 and 2029 maturities. Key project milestones: • VMOS: The two monobuoys arrived at the port in Río Negro Province in early October 2026. With ~85% progress as of September 2026, the project remains on track for commercial operation (COD) by year-end, with first oil expected in early 2027. • Argentina LNG: YPF received a non-binding financing proposal of up to US$6 billion from US EXIM bank to support development of the project’s integrated LNG export value chain. 3Q26 2Q26 Q/Q Δ 3Q25 Y/Y Δ 9M26 9M25 Δ Revenues 6,557 6,574 0% 4,643 41% 18,077 13,892 30% Adjusted EBITDA 2,503 2,804 -11% 1,357 84% 6,901 3,726 85% Net Result 1,196 1,205 -1% (198) N/A 2,810 (150) N/A CAPEX 1,287 1,340 -4% 1,017 26% 3,607 3,391 6% FCF 901 824 9% (759) N/A 2,596 (2,081) N/A Net Debt 6,596 7,654 -14% 9,595 -31% 6,596 9,595 -31% Net Leverage Ratio (x) 0.81 1.09 -26% 2.10 -62% 0.81 2.10 -62% Hydrocarbon Production (Kboe/d) (1) 532.0 544.4 -2% 523.1 2% 533.8 540.2 -1% Crude Oil (Kbbl/d) 261.4 265.5 -2% 239.8 9% 265.9 252.4 5% Natural Gas (Mm3/d) 36.5 37.3 -2% 38.4 -5% 35.5 38.5 -8% NGL (Kbbl/d) 41.3 44.6 -8% 41.9 -2% 44.5 45.7 -3% Crude Oil Price (US$/bbl) 81.4 91.1 -11% 60.0 36% 80.3 62.6 28% Natural Gas Price (US$/MBTU) 4.4 4.2 4% 4.3 1% 3.9 3.8 2% Crude Oil Exports (Kbbl/d) 32.2 33.8 -5% 38.3 -16% 34.7 39.5 -12% Shale Oil Production (Kbbl/d) 224.1 212.7 5% 170.0 32% 214.1 154.2 39% Total Lifting Cost (US$/boe) (2) 7.8 8.5 -8% 8.8 -12% 8.4 12.1 -31% Lifting cost shale oil hub (US$/boe) (2) 4.2 4.2 0% 4.1 3% 4.1 4.5 -8% Crude Processed (Kbbl/d) 344.0 350.8 -2% 326.2 5% 346.4 315.2 10% Refineries' Utilization Rate (%) 102% 104% -2% 97% 5% 102% 93% 10% Local Fuels Volume Sold (Km3) (3) 3,733 3,869 -4% 3,655 2% 11,234 10,591 6% Local Fuels Net Price (US$/m3) 865 920 -6% 608 42% 836 648 29% Imported Fuels (Km3) (3) - - N/A 50 N/A - 222 N/A R&M Adj. EBITDA (US$/bbl) 25.6 22.5 14% 7.1 258% 21.0 11.9 76% KPI FinancialUpstreamMidstream & Dw
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Page 3/13 YPF 3Q26 3Q26 YPF Buenos Aires, 28/10/2026 – YPF (ByMA: YPFD | NYSE: YPF1). Information based on financial statements (FS) prepared according to IFRS in force in Argentina. The sum of the parts of certain figures is subject to rounding. The Company’s functional currency is US$. 1. ANALYSIS OF CONSOLIDATED RESULTS OF 3Q26 Net Revenues amounted to US$6,557 million, essentially flat q/q, primarily driven by lower local fuel prices, particularly diesel (2Q26 recorded extraordinary sales to other refineries, in addition to diesel seasonal impact), besides lower crude oil exports amid decreased Brent prices. These effects were largely offset by higher seasonal local natural gas sales and increased exports of fuels, mainly gasoline, virgin naphtha and grain and flour. OPEX posted US$1,538 million (+5% q/q), mainly due to higher costs in real terms across business units, and to a minor extent, updated environmental provisions, mostly in non-operated assets, partially mitigated by lifting cost savings related to reduced exposure to conventional fields. Other Costs were US$1,531 million (-5% q/q), largely due to non- recurring PP&E depreciation in 2Q26 (reassessment of useful lives of certain assets ), while 3Q26 recorded lower royalties, other revenue-related taxes and export duties, explained by decreased oil prices, partially offset by higher depreciation at Bajo del Toro block in 3Q26 with higher production. Purchases & Stock Variations totaled US$1,728 million (+18% q/q). Purchases were broadly unchanged q/q, as lower third-party crude oil prices were partly offset by seasonally higher natural gas purchases. YPF again operated without diesel or gasoline imports in 3Q26. Stock Variations were negative at US$93 million, compared to positive US$178 million in 2Q26, reaching a total gap of US$271 million, mainly reflecting the exceptionally high valuation of inventories during 2Q26 with peak international prices. Other operating net results totaled positive US$161 million (vs. negative US$203 million in 2Q26), mainly due to the positive result in 3Q26 from sale of conventional assets, while 2Q26 recorded a negative result from changes in the fair value of conventional assets held for sale and reassessment of commitments, also mostly related to mature fields. 1 1 ADR = 10 share. Total issued capital stock amounted to 3,933,127,930 shares as of Sep-26 (51% Argentina Government; 29% NYSE and 20% ByMA). Consolidated Revenues Breakdown Unaudited Figures, in US$ million Diesel 2,146 2,430 1,467 -11.7% 46.3% 6,239 4,514 38.2% Gasoline 1,294 1,332 929 -2.8% 39.3% 3,756 2,890 30.0% Natural gas as producers (third parties) 536 456 523 17.3% 2.3% 1,275 1,276 -0.1% Other 1,435 1,257 1,067 14.2% 34.5% 3,689 3,081 19.8% Total Domestic Market 5,411 5,475 3,986 -1.2% 35.7% 14,959 11,760 27.2% Jet fuel 172 184 87 -6.5% 97.6% 514 254 102.5% Grain and flours 241 216 139 11.4% 73.1% 600 444 35.2% Crude oil 264 304 238 -13.2% 10.9% 823 732 12.5% Petchem & Other 470 395 193 18.8% 143.3% 1,181 703 68.0% Total Export Market 1,146 1,099 657 4.3% 74.5% 3,118 2,132 46.2% Total Revenues 6,557 6,574 4,643 -0.3% 41.2% 18,077 13,892 30.1% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ Unaudited Figures, in US$ million Lifting cost (401) (427) (426) -6.0% -5.8% (1,245) (1,795) -30.6% Other Upstream (139) (112) (184) 23.9% -24.3% (339) (489) -30.6% OPEX Downstream (549) (540) (517) 1.7% 6.2% (1,564) (1,571) -0.4% Other Midstream & Downstream (177) (165) (113) 7.4% 56.5% (539) (330) 63.2% LNG & IG, New Energies, Corp. & Other (271) (223) (117) 21.4% 132.8% (712) (444) 60.5% Total OPEX (1,538) (1,468) (1,356) 4.8% 13.4% (4,400) (4,629) -5.0% Depreciation & Amortization (834) (878) (836) -5.0% -0.2% (2,455) (2,430) 1.0% Royalties (310) (348) (235) -11.1% 31.6% (906) (740) 22.3% Other costs (387) (393) (287) -1.3% 35.1% (1,111) (921) 20.7% Total Other Costs (1,531) (1,619) (1,358) -5.4% 12.7% (4,472) (4,091) 9.3% Fuels imports (including jet fuel) (9) (4) (35) 108.4% -75.8% (15) (147) -89.7% Crude oil purchases to third parties (771) (878) (688) -12.1% 12.0% (2,320) (1,615) 43.6% Biofuel purchases (304) (305) (208) -0.4% 46.2% (891) (678) 31.4% Agro products purchases (262) (263) (226) -0.6% 16.0% (650) (568) 14.4% Other purchases (290) (191) (221) 51.6% 31.2% (678) (606) 11.8% Stock variations (93) 178 54 N/A N/A 90 (9) N/A Total Purchases & Stock Variations (1,728) (1,463) (1,324) 18.1% 30.5% (4,463) (3,623) 23.2% Other operating results, net 161 (203) (48) N/A N/A (122) (397) -69.3% Inventories write-down and reversal of impairment losses of property, plant and equipment - (8) (5) N/A N/A (8) 4 N/A Operating Costs + Purchases + Impairment of Assets (4,636) (4,761) (4,091) -2.6% 13.3% (13,465) (12,736) 5.7% Stock variations include price effects by (US$37) million in 3Q26, US$219 million for 2Q26, (US$4) million for 3Q25, US$ 159 million for 9M26 and (US$ 96) million for 9M25. 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆
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Page 4/13 YPF 3Q26 3Q26 YPF Financial net results posted a loss of US$228 million (vs. a loss of US$130 million in 2Q26), as 2Q26 recorded lower liabilities in dollar terms. The income tax recorded a charge of US$631 million (+6% q/q), reflecting a recurring charge in line with the applicable corporate income tax rate. Consequently, net result totaled a gain of US$1,196 million (vs. US$1,205 million in 2Q26). 2. ADJ. EBITDA & CAPEX 2.1 ADJ. EBITDA RECONCILIATION 2.2 ADJ. EBITDA & CAPEX BY SEGMENT Consolidated Net Income Breakdown Unaudited Figures, in US$ million Operating income / (loss) 1,921 1,813 552 6.0% 248.0% 4,612 1,156 299.0% Result from equity interests in associates and joint ventures 134 115 32 16.5% 318.8% 350 107 227.1% Financial results, net (228) (130) (245) 75.4% -6.9% (685) (746) -8.2% Net result before tax 1,827 1,798 339 1.6% 438.7% 4,277 517 727.3% Income tax (631) (593) (537) 6.4% 17.5% (1,467) (667) 119.9% Net result 1,196 1,205 (198) -0.7% N/A 2,810 (150) N/A Net Income before impairment of assets 1,196 1,210 (195) -1.2% N/A 2,815 (153) N/A 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ Reconciliation of Adjusted EBITDA Unaudited Figures, in US$ million Net result 1,196 1,205 (198) -0.7% N/A 2,810 (150) N/A Financial results, net 228 130 245 75.4% -6.9% 685 746 -8.2% Result from equity interests in associates and joint ventures (134) (115) (32) 16.5% 318.8% (350) (107) 227.1% Income tax 631 593 537 6.4% 17.5% 1,467 667 119.9% Unproductive exploratory drillings - 3 - N/A N/A 12 1 N/A Depreciation & amortization 834 878 836 -5.0% -0.2% 2,455 2,430 1.0% Inventories write-down and (reversal) of impairment losses of property, plant and equipment - 8 5 N/A N/A 8 (4) N/A EBITDA 2,755 2,702 1,393 2.0% 97.8% 7,087 3,583 97.8% Leasing (77) (94) (88) -18.5% -13.2% (257) (255) 0.7% Provision for operating optimizations (1) (13) 60 -92.3% N/A 56 90 -37.8% Result from sale of assets (171) - (34) N/A 402.9% (175) (216) -19.0% Result from changes in fair value of assets held for sale - 147 (4) N/A N/A 133 240 -44.6% Provision for severance indemnities 5 (6) 2 N/A 150.0% (1) 28 N/A Provision for obsolescence of materials and equipment (17) (11) (19) 54.5% -10.5% (37) 240 N/A Result from revaluation of companies - - - N/A N/A - (45) N/A Result from liabilities for agreements - 82 - N/A N/A 82 - N/A Miscellaneous – Mature Fields & Others 9 (3) 48 N/A -81.2% 13 61 -79.2% Adjusted EBITDA 2,503 2,804 1,357 -10.7% 84.4% 6,901 3,726 85.2% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ 3Q26 2Q26 Q/Q Δ 3Q25 Y/Y Δ 9M26 9M25 Δ Upstream 1,575 1,725 -9% 1,046 51% 4,449 2,614 70% Midstream & Downstream 1,030 947 9% 384 169% 2,572 1,398 84% LNG & IG (5) (2) 150% (1) 283% (7) (6) 12% New Energies 102 59 72% 61 66% 191 125 53% Corp (164) (154) 7% (103) 59% (465) (284) 64% Eliminations & Others (36) 228 N/A (30) 17% 161 (122) N/A Total Adj. EBITDA 2,503 2,804 -11% 1,357 84% 6,901 3,726 85% Upstream 932 1,066 -13% 751 24% 2,781 2,595 7% Midstream & Downstream 280 213 31% 218 28% 643 668 -4% LNG & IG 17 23 -26% 9 89% 58 26 123% New Energies 10 8 25% 7 33% 27 26 4% Corp 49 31 57% 31 56% 99 77 29% Total CAPEX 1,287 1,340 -4% 1,017 26% 3,607 3,391 6% Note: Midstream & Dw Adjusted EBITDA excludes inventories price effect of oil products, which are included in Eliminations & Other. By Segment Adj. EBITDACAPEX
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Page 5/13 YPF 3Q26 3Q26 YPF 3. ANALYSIS OF RESULTS BY SEGMENT 3.1 UPSTREAM (*) Underlying lifting costs exclude specific well servicing costs. Including them, lifting costs would have been (US$/BOE, total and shale oil hub, respectively): 8.1 and 5.0 (3Q26); 8.7 and 4.7 (2Q26); 8.8 and 4.3 (3Q25); 8.6 and 4.6 (9M26); and 12.2 an d 4.5 (9M25). Revenues totaled US$2,536 million (-7% q/q), primarily reflecting a 10% q/q decline in realized oil prices, driven by lower Brent prices and a return to the customary domestic discount of Medanito price to Brent in 3Q26, compared with an exceptional premium in 2Q26 . Revenues were also impacted by lower conventional oil production under the divestment program. These effects were partially offset by seasonally peak natural gas sales (+9% in volume and +4% in price) and continued growth in shale output. Depreciation and amortization amounted to US$577 million (-9% q/q), largely explained by the non-recurring PP&E depreciation in 2Q26, slightly offset by higher activity at Bajo del Toro shale oil block in 3Q26. Lifting costs reached US$7.8/BOE (-8% q/q), mostly due to the continued divestment of conventional assets, partially offset by higher costs in real terms . It is worth noting that lifting costs declined by 1 2% interannually, reflecting the progress achieved in our conventional divestment strategy. Lifting costs at the shale oil hub2 remained competitive at US$4.2/BOE on a 100% working-interest basis. Royalties and other taxes averaged US$7.4/BOE (-13% q/q), primarily reflecting lower realized oil prices, partly offset by peak seasonal natural gas prices. Other costs declined to US$39 million (-90% q/q), mainly reflecting the positive impact of closing the sale of the Malargüe conventional cluster in September 2026. By comparison, 2Q26 included a negative change in the fair value of assets held for sale (Manantiales Behr) and the reassessment of commitments, primarily related to mature fields. Adj. EBITDA totaled US$1,575 million (-9% q/q), primarily reflecting lower realized oil prices as Brent contracted from its 2Q26 rally. The decline was partly offset by peak winter natural gas sales, lower price-linked royalties and reduced lifting costs following the divestment of the Manantiales Behr conventional block. CAPEX totaled US$932 million (-13% q/q), with 97% allocated to unconventional assets, primarily drilling and facilities. The sequential decline mainly reflected the signing bonus accrued in 2Q26 for unconventional concessions covering five blocks assigned to the Argentina LNG Project, partly offset by increased activity at La Angostura Sur in 3Q26. 2 Five shale oil blocks operated by YPF: La Angostura Sur I and II (YPF owns 100%), Loma Campana (50%), La Amarga Chica (50%), Bandurria Sur (40% as of 1Q26, and 44.9% as from May-26) and Aguada del Chañar (51%). La Angostura Sur is south-hub block and the rest core-hub blocks. Upstream Financials Unaudited Figures, in US$ million Crude oil 1,920 2,179 1,323 -11.9% 45.1% 5,743 4,293 33.8% Natural gas 610 537 611 13.4% -0.2% 1,493 1,546 -3.4% Other 6 25 33 -74.1% -80.4% 62 90 -31.6% Revenues 2,536 2,741 1,967 -7.5% 28.9% 7,298 5,929 23.1% Depreciation & amortization (577) (632) (615) -8.7% -6.2% (1,731) (1,805) -4.1% Lifting cost (401) (427) (426) -6.0% -5.8% (1,245) (1,795) -30.6% Royalties (307) (346) (234) -11.3% 31.1% (899) (736) 22.2% Other costs (39) (381) (273) -89.8% -85.8% (640) (1,086) -41.1% Operating income before impairment of assets 1,212 955 419 26.9% 189.3% 2,783 507 448.9% Operating income / (loss) 1,212 955 419 26.9% 189.3% 2,783 507 448.9% Depreciation & amortization 577 632 615 -8.7% -6.2% 1,731 1,805 -4.1% Unproductive exploratory drillings - - - N/A N/A 9 1 800.0% EBITDA 1,789 1,587 1,034 12.7% 73.0% 4,523 2,313 95.5% Leasing (39) (55) (42) -30.2% -6.8% (143) (142) 0.8% Provision for operating optimizations (1) (13) 60 -92.3% N/A 56 90 -37.8% Result from sale of assets (171) - (34) N/A 402.9% (175) (216) -19.0% Result from changes in fair value of assets held for sale - 147 (4) N/A N/A 133 240 -44.6% Provision for severance indemnities 5 (6) 2 N/A 150.0% (1) 28 N/A Provision for obsolescence of materials and equipment (17) (11) (19) 54.5% -10.5% (37) 240 N/A Result from liabilities for agreements - 82 - N/A N/A 82 - N/A Miscellaneous – Mature Fields 9 (5) 48 N/A -81.3% 10 61 -82.9% Adjusted EBITDA 1,575 1725 1046 -8.7% 50.7% 4,449 2,614 70.2% CAPEX 932 1,066 751 -12.6% 24.0% 2,781 2,595 7.2% Unit Cash Costs Unaudited Figures, in US$/boe Lifting Cost (*) 7.8 8.5 8.8 -8.3% -11.9% 8.4 12.1 -31.0% Royalties and other taxes 7.4 8.5 6.0 -13.1% 23.9% 7.4 6.4 16.5% Other Costs 3.0 2.5 4.0 18.4% -25.5% 2.3 3.4 -31.4% Total Cash Costs (US$/boe) 18.6 19.7 18.8 -5.3% -0.9% 18.5 23.6 -21.8% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ Y/Y ∆3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25
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Page 6/13 YPF 3Q26 3Q26 YPF Gross unconventional horizontal oil wells recorded strong metrics in 3Q26: • Drilled wells increased 14% q/q, recording 64 wells (66% average working interest or “avg. WI”) vs. 56 wells (66% avg. WI) in 2Q26, all of them operated by YPF; • Completion activity remained strong, stable q/q at 61 wells (71% avg. WI) vs. 61 wells (53% avg. WI) in 2Q26, all of them operated by YPF and 50 operated by YPF, respectively; and • Tied‑in wells decreased 11% q/q to 58 wells (72% avg. WI) vs. 65 wells in 2Q26 (53% avg. WI), all of them operated by YPF and 54 operated by YPF, respectively. During 3Q26, YPF achieved a new milestone in our drilling operations. We managed to drill the longest slim well of 4,770 meters of horizontal length in a single run. The result was subsequently replicated in 3 additional wells within ~10 days, demonstrating scalability and consistency of our operation across different rigs and service providers. In terms of efficiencies within our unconventional operations, drilling and fracking performance remained at strong levels in 9M26. We averaged 354 meters/day of drilling in our shale oil hub blocks and reached 11.1 stages/set/day on unconventional fracking (equivalent to 294 stages per set per month), supported with 18.8 pumping hours per day. Crude oil production recorded 261 kbbl/d (-2% q/q), reflecting the ongoing divestment program for conventional fields, largely offset by shale oil growth, supported by the strong increase from Bandurria Sur, Bajo del Toro Norte, La Calera, and La Angostura Sur. As a result, shale oil accounts for 86% of total crude oil production. Natural gas production declined to 36.5 mm3/d (-2% q/q), mainly explained by lower conventional output ( -9% q/q), while shale gas remained similar and representing 74% of our total natural gas production, mostly led by La Calera, Rincón del Mangrullo and Aguada Pichana Oeste blocks. NGLs production decreased by -8% q/q to 41.3 kbbl/d, primarily driven by lower net production at MEGA facility as a result of maintenance activities and temporary restrictions in gas supply, partially offset by higher volumes from other processing facilities. Upstream Operating data Unaudited Figures Net Production Breakdown Crude Production (Kbbld) 261.4 265.5 239.8 -1.5% 9.0% 265.9 252.4 5.4% Conventional 36.4 52.0 69.0 -30.0% -47.2% 51.0 97.1 -47.5% Shale 224.1 212.7 170.0 5.3% 31.8% 214.1 154.2 38.8% Tight 0.9 0.7 0.9 35.0% 5.5% 0.8 1.1 -27.9% NGL Production (Kbbld) 41.3 44.6 41.9 -7.5% -1.5% 44.5 45.7 -2.7% Conventional 6.3 6.6 11.3 -4.5% -44.2% 6.6 12.2 -46.2% Shale 34.8 37.9 30.4 -8.1% 14.6% 37.8 33.1 14.2% Tight 0.2 0.1 0.3 18.9% -38.4% 0.2 0.5 -63.7% Gas Production (Mm3d) 36.5 37.3 38.4 -2.1% -5.0% 35.5 38.5 -7.7% Conventional 6.3 6.9 8.7 -9.2% -27.9% 6.9 10.4 -34.2% Shale 27.1 27.5 26.3 -1.2% 3.3% 25.8 24.5 5.2% Tight 3.0 2.8 3.4 6.0% -10.2% 2.9 3.5 -19.5% Total Production (Kboed) 532.0 544.4 523.1 -2.3% 1.7% 533.8 540.2 -1.2% Conventional 82.3 102.3 135.2 -19.5% -39.1% 100.7 174.8 -42.4% Shale 429.6 423.4 365.6 1.5% 17.5% 414.2 341.6 21.3% Tight 20.0 18.7 22.2 7.1% -9.9% 18.9 23.8 -20.7% Average realization prices Crude Oil (USD/bbl) 81.4 91.1 60.0 -10.7% 35.6% 80.3 62.6 28.2% Natural Gas (USD/MMBTU) 4.4 4.2 4.3 4.4% 1.0% 3.9 3.8 2.0% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆
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Page 7/13 YPF 3Q26 3Q26 YPF 3.2 MIDSTREAM & DOWNSTREAM Revenues totaled US$5,123 million (-5% q/q), mostly driven by lower prices in local fuel and oil exports in 3Q26, while 2Q26 recorded extraordinary sales of diesel to other refineries, besides seasonal effects. The decreased revenue level in 3Q26 was partially offset by higher gasoline demand and increased fuel exports, mainly gasoline. Downstream OPEX totaled US$549 million, remaining broadly stable q/q (+2%). Fuel imports were limited to a marginal amount of jet fuel, with import costs increasing by US$4 million q/q due to higher jet fuel prices. As the previous quarter, in 3Q26 YPF operated without gasoline or diesel imports, which accounted for 0% of total fuel sales. Crude oil purchases (intersegment and third-party) totaled US$2,679 million (-12% q/q), primarily reflecting lower crude oil prices and reduced refinery throughput during scheduled maintenance at La Plata in September 2026. Biofuel purchases remained broadly stable q/q: a 4% decline in biodiesel purchases (-4% in price; -1% in volume) was largely offset by a 5% increase in bioethanol purchases (+4% in volume), in line with stronger gasoline demand. Stock variations were positive at US$187 million, compared with negative US$196 million in 2Q26, primarily reflecting the favorable mark-to-market impact on inventories of higher reference prices at the end of September 2026 versus lower prices at the end of June 2026. Adj. EBITDA, excluding oil product inventory price effects, increased 9% q/q to US$1,030 million in 3Q26. Growth was primarily driven by lower crude oil purchases (Medanito crude returning to discount to Brent, following an exceptional premium in 2Q26), and wider refin ed product spreads. These benefits were partly offset by lower refinery throughput and domestic fuel prices. Adj. EBITDA of the Refining & Marketing business, in unit terms, expanded to US$25.6/bbl, compared to US$22.5/bbl in 2Q26, reflecting the effects mentioned above. CAPEX totaled US$280 million (+31% q/q), primarily driven by scheduled maintenance at La Plata in September 2026 and increased maintenance and integrity activities at the La Plata and Luján de Cuyo refineries during 3Q26. Investment was allocated to refining (56%), oil and gas midstream (25%), logistics (12%), and commercial and other activities (7%). In our refineries, during 3Q26 CAPEX was mainly allocated to the following projects: • New fuel specifications project, following the startup of the new diesel hydrotreating unit at Luján de Cuyo in Jul- 26, in compliance with Resolution No. 492/2023 (Secretary of Energy), YPF continued advancing the hydrotreating projects at La Plata and Plaza Huincul after reaching FID in 2Q26. Once completed, the entire refining system will comply with the latest diesel specifications. Midstream & Downstream Financials Unaudited Figures, in US$ million Diesel (third parties) 2,146 2,430 1,467 -11.7% 46.3% 6,239 4,514 38.2% Gasoline (third parties) 1,294 1,332 929 -2.8% 39.3% 3,756 2,890 30.0% Other domestic market 809 760 593 6.4% 36.3% 2,141 1,754 22.1% Export market 874 850 480 2.9% 82.2% 2,427 1,575 54.1% Revenues 5,123 5,372 3,469 -4.6% 47.7% 14,563 10,732 35.7% Depreciation & amortization (204) (182) (185) 12.1% 10.3% (562) (512) 9.8% OPEX Downstream (549) (540) (517) 1.7% 6.2% (1,564) (1,571) -0.4% Fuels imports (including jet fuel - third parties) (9) (4) (35) 108.4% -75.8% (15) (147) -89.7% Crude oil purchases (intersegment + third parties) (2,679) (3,042) (2,012) -11.9% 33.2% (8,028) (5,908) 35.9% Biofuel purchases (third parties) (304) (305) (208) -0.4% 46.2% (891) (678) 31.4% Stock variations 187 (196) 9 N/A N/A 673 (32) N/A Other (438) (407) (334) 7.6% 31.0% (1,273) (958) 32.9% Operating income / (loss) before impairment of assets 1,127 695 187 62.1% 502.6% 2,904 926 213.6% Operating income / (loss) 1,127 695 187 62.1% 502.6% 2,904 926 213.6% Depreciation & amortization 204 182 185 12.1% 10.3% 562 512 9.8% EBITDA 1,331 877 372 51.7% 257.8% 3,466 1,438 141.0% Leasing (37) (38) (46) -1.8% -18.6% (105) (110) -4.7% Result from revaluation of companies - - - N/A N/A - (44) N/A Miscellaneous – Others - - (1) N/A N/A - (1) N/A Adjusted EBITDA 1,294 839 325 54.2% 297.8% 3,361 1,283 161.9% Inventories price effect of oil products 263 (108) (58) N/A N/A 789 (115) N/A Adjusted EBITDA excl. inventories price effect of oil products 1,030 947 384 8.8% 168.6% 2,572 1,398 84.0% CAPEX 280 213 218 31.4% 28.2% 643 668 -3.7% Stock variations include price effects by US$264 million for 3Q26, (US$110) million for 2Q26, (US$58) million in 3Q25, US$ 788 million for 9M 26 and (US$ 115) million for 9M 25. 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆
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Page 8/13 YPF 3Q26 3Q26 YPF In our midstream oil business unit, we continued moving forward in our main projects: • VMOS (Allen – Punta Colorada, ~440-km dedicated oil export pipeline, YPF: 30%): In Oct-26, construction of the pipeline was completed, and the project entered the commissioning phase. Construction of the onshore and offshore terminal facilities is ongoing, and overall project progress reached 85% as of Sep -26. First oil is expected in early 2027 (~180 kbbl/d), increasing to ~550 kbbl/d in 2H27. • VMOC Third Loop Expansion: construction progress reached ~90%, with mechanical completion expected in Oct- 26. • La Angostura Sur Evacuation Project: In Aug-26, we completed construction of the new pipeline connecting the South Hub with the LLL-Centenario Pipeline, further enhancing evacuation capacity from Vaca Muerta. In our midstream gas business unit, we also continued making progress on our main projects: • South Hub gathering project: In Sep-26 we completed the gas evacuation infrastructure associated with the Puesto López–LLL gas pipelines, with all pipeline sections already operational. • North Hub gathering project, following the completion of gas pipeline Narambuena and Bajo del Toro blocks – El Portón Industrial Complex, YPF continued advancing the gas treatment facilities, expected COD by 1Q27. In logistics, following the successful commissioning of the revamped Luján de Cuyo -Monte Cristo product pipeline in 2Q26, increasing the product evacuation capacity from the Luján de Cuyo refinery, the Company continued advancing integrity works along the pipeline network supplying the La Plata refinery. Refinery throughput averaged 344 kbbl/d (-2% q/q), primarily reflecting scheduled maintenance at the La Plata refinery beginning in September 2026. Refinery utilization nevertheless remained strong at 102%. This operating performance generated surplus gasoline and middle distillates, enabling YPF to meet domestic demand without fuel imports, supply other local refiners and further increase fuel exports, primarily gasoline. Domestic fuel sales volumes (YPF stand-alone) totaled 3,731 thousand m3 (-3% q/q). The decline primarily reflected lower diesel sales (-6% q/q), following exceptionally high sales to local refiners in 2Q26, alongside softer demand from industrial and agribusiness customers in 3Q26. Higher gasoline sales (+1% q/q) partly offset the decline. Petrochemical sales volumes declined 16% q/q, primarily reflecting lower domestic sales of propylene and aromatics, as well as reduced methanol exports due to plant shutdowns. Higher paraffin exports partly offset these declines. Average net domestic fuel prices in U.S. dollar terms declined 6% q/q, reflecting YPF’s pricing buffer strategy to support demand amid international price volatility. Midstream & Downstream Operating data Unaudited Figures Crude processed (Kbbld) 344.0 350.8 326.2 -1.9% 5.5% 346.4 315.2 9.9% Refinery utilization (%) 101.8% 103.8% 96.5% -202bps 526bps 102.5% 93.3% 922bps Sales volume to third parties (YPF stand alone) Sales of refined products (Km3) 5,191 5,193 4,842 0.0% 7.2% 15,407 14,136 9.0% Total domestic market 4,455 4,565 4,425 -2.4% 0.7% 13,295 12,753 4.3% of which Gasoline 1,522 1,500 1,501 1.5% 1.4% 4,600 4,394 4.7% of which Diesel 2,209 2,360 2,154 -6.4% 2.6% 6,620 6,198 6.8% Total export market 736 628 417 17.1% 76.5% 2,113 1,383 52.7% Sales of petrochemical products (Ktn) 197 236 179 -16.4% 10.0% 634 561 12.9% Domestic market 122 138 114 -11.3% 7.8% 380 342 11.3% Export market 75 98 65 -23.7% 13.9% 254 220 15.5% Net average prices Gasoline (USD/m3) (domestic market) 776 824 567 -5.8% 36.8% 751 601 25.1% Diesel (USD/m3) (domestic market) 922 981 637 -6.0% 44.8% 893 682 31.0% Net Average domestic prices for gasoline and diesel are net of taxes, commissions, commercial bonuses and freights. 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆
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Page 9/13 YPF 3Q26 3Q26 YPF 3.3 LNG & INTEGRATED GAS Adj. EBITDA remained broadly stable q/q, with a loss of US$5 million compared with a loss of US$2 million in 2Q26. The increased natural gas purchases to meet winter demand and higher provisions for doubtful receivables was largely offset by higher seasonal natural gas sales, particularly for residential and industrial customers. CAPEX continued to focus primarily on the Argentina LNG project. In August 2026, YPF submitted the Argentina LNG project under the RIGI framework. It represents Argentina’s largest- ever private investment project and the largest application submitted under RIGI. Total investment is expected to reach approximately US$51 billion over the life of the project, with approximately US$29 billion expected by 2031: US$24 billion for integrated LNG infrastructure and US$5 billion for upstream development. Project finance debt is expected to fund 60–70% of infrastructure investment. 3.4 NEW ENERGIES Adj. EBITDA reached US$102 million (+72% q/q), primarily explained by higher seasonal natural gas sales from our subsidiary Metrogas, driven by stronger residential demand, partially offset by higher natural gas purchases , while agribusiness remained essentially flat. In August 2026, YPF accepted Edenor’s offer to acquire YPF’s 70% equity stake in Metrogas and Metroenergía for US$780 million, advancing YPF’s portfolio optimization strategy, subject to closing . Until the transaction closes, the results of Metrogas and Metroenergía will continue to be consolidated within this business segment. LNG & Integrated Gas Unaudited Figures, in US$ million Natural gas (intersegment + third parties) 619 552 634 12.2% -2.2% 1,521 1,556 -2.2% Other 24 30 28 -18.4% -13.8% 76 71 7.5% Revenues 644 582 662 10.6% -2.7% 1,597 1,627 -1.8% Depreciation & amortization (6) (33) (2.0) -81.8% 200.0% (40) (3) N/A Natural gas purchases (intersegment + third parties) (607) (550) (624) 10.4% -2.7% (1,500) (1,561) -3.9% Operating cost & Other (42) (34) (39) 22.9% 6.9% (104) (71) 46.4% Operating profit or loss before impairment of assets (11) (35) (3.0) -68.1% 270.4% (47) (8) 482.8% Operating profit or loss (11) (35) (3.0) -68.1% 270.4% (47) (8) 482.8% Depreciation & amortization 6 33 2.0 -81.8% 200.0% 40 3 N/A EBITDA (5) (2) (1.0) 179.6% 411.1% (7) (5) 32.5% Leasing - - (0) N/A N/A - (1) N/A Adjusted EBITDA (5) (2) (1) 179.6% 291.8% (7) (6) 5.9% CAPEX 17 23 9 -26.1% 88.9% 58 26 123.1% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ New Energies Unaudited Figures, in US$ million Natural gas retail (third parties) 338 195 201 73.5% 68.1% 685 536 28.0% Agro products 344 291 260 18.1% 32.6% 826 671 23.1% Other 67 63 38 6.5% 74.3% 182 137 32.9% Revenues 749 549 499 36.4% 50.1% 1,694 1,344 26.0% Depreciation & amortization (15) (7) (9) 114.3% 66.7% (36) (34) 5.9% Natural gas purchases (intersegment + third parties) (186) (110) (106) 68.4% 76.1% (378) (265) 42.3% Agro products purchases (third parties) (262) (263) (226) -0.6% 16.0% (650) (568) 14.4% Operating cost & Other (200) (122) (107) 64.2% 87.4% (481) (385) 24.8% Operating income before impairment of assets 87 47 52 85.1% 66.0% 150 91 64.1% Reversal / (impairment) of property, plant and equipment - (8) (5) N/A N/A (8) 4 N/A Operating income 87 39 47 123.1% 83.5% 142 95 48.8% Depreciation & amortization 15 7 9 114.3% 66.7% 36 34 5.9% Unproductive exploratory drillings (Lithium) - 3 - N/A N/A 3 - N/A Reversal / (impairment) of property, plant and equipment - 8 5 N/A N/A 8 (4) N/A EBITDA 102 57 61 78.9% 66.1% 189 125 50.7% Miscellaneous - Result from sale of companies - 2 - N/A N/A 2 - N/A Adjusted EBITDA 102 59 61 72.1% 66.1% 191 125 52.5% CAPEX 10 8 7 25.0% 33.4% 27 26 3.8% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ New Energies Unaudited Figures Sales volume to third parties (YPF stand alone) Sales of fertilizers, grain and flours (Ktn) 681 601 535 13.3% 27.2% 1,667 1,489 11.9% Domestic market 163 118 196 38.2% -16.9% 365 403 -9.5% Export market 517 483 339 7.2% 52.8% 1,302 1,086 19.9% 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆
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Page 10/13 YPF 3Q26 3Q26 YPF Fertilizers’ sales volume (100% local) expanded by 83% q/q, reflecting stronger agricultural activity and seasonal demand, while grain and flour sales volumes, almost fully allocated to exports (99.7% in 3Q26, 94% in 2Q26 and 98% in 3Q25) increased by 1% q/q, driven by stronger export market conditions. 4. LIQUIDITY AND SOURCES OF CAPITAL 4.1 CASH FLOW SUMMARY Free cash flow remained strong at US$901 million in 3Q26, the second-highest quarterly level in YPF’s history. Adjusted EBITDA of US$2.5 billion comfortably covered CAPEX of US$1.3 billion, regular interest payments of US$278 million and income tax payments of US$225 million. Cash generation also benefited from US$175 million in M&A proceeds, primarily initial collections from the sales of Metrogas and the Mendoza Non-Operated and Chachahuen conventional clusters, as well as a modest US$13 million contribution from working capital and other items. Strong cash generation, together with a US$279 million contribution from new debt and other items, increased cash and short-term investments to approximately US$3.7 billion at the end of 3Q26, up from US$2.5 billion at the end of 2Q26, covering more than 2 years and a half of YPF’s debt maturity profile. Financing activity included the successful issuance of a US$1.2 billion international bond due in 2035 and the completion in September of tender offers for approximately US$531 million of international bonds due in 2027 and 2029. Notes: YPF S.A. standalone. [1] Approximation of cash flow evolution, highlighting key figures. Cash & equivalents include Argentine sovereign bonds and Treasury notes. [2] M&A includes initial collection from the divestment of Chachahuen cluster (40) and the sale of Metrogas (78), both transactions subject to closing, among other collections. [3] Consider higher seasonal gas sales, dividend collections from affiliates (+19), contribution to affiliates ( -50), among others. [4] Others include mainly FX differences and net collection for sale of financial assets. 4.2 NET DEBT As of September 30, 2026, YPF’s consolidated net debt totaled US$6,596 million (US$1,058 million lower q/q), driven by strong free cash flow generation that strengthen ed the Company’s liquidity position. As a result, our net leverage ratio improved from 1.09x in 2Q26 to 0.81x in 3Q26. This level also represents a 62% reduction from the peak in 3Q25 (2.10x) and positioned as the lowest level of net leverage achieved by YPF in more than a decade. Net debt breakdown Unaudited Figures, in US$ million Short-term debt 1,578 1,607 2,653 -1.8% Long-term debt 8,672 8,521 7,958 1.8% Total debt 10,250 10,128 10,611 1.2% Avg. Interest rate for US$-debt 7.3% 7.0% 6.7% % of debt in USD 100.0% 99.5% 98.7% Cash + short term investments 3,654 2,474 1,016 47.7% % of liquidity dollarized 83.0% 67.6% 70.5% Net debt 6,596 7,654 9,595 -13.8% Average interest rates for US$ debt refer to YPF on a stand-alone basis. 3Q26 2Q26 3Q25 Q/Q ∆
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Page 11/13 YPF 3Q26 3Q26 YPF In terms of financing during 3Q26, YPF successfully returned to the international capital market, with a US$1.2 billion unsecured bond due in 2035 at a 7.85% yield. The transaction marked YPF’s largest bond issuance in 11 years and achieved a record-low spread of approximately 300 basis points over U.S. Treasuries. As part of its liability management strategy, the Company used a portion of the proceeds to repurchase US$531 million of international bonds maturing between 2027 and 2029, extending its debt maturity profile and reducing near-term refinancing needs. In the local capital markets, YPF raised an additional US$171 million at a 5.5% yield through a reopening of its US$- MEP bond due in April 2030, originally issued in April 2026 for US$122 million. Following quarter -end, the Company raised an additional US$72 million US$-MEP bond at a 6.0% yield and initiated the early redemption of a US$140 million US$-MEP bond due in May 2027, scheduled for November 2026. Regarding our maturity profile, for the remaining 3 months of 2026, the Company faces US$208 million of manageable maturities: US$88 million of local bonds (US$14.9 million repurchased after 3Q26); US$72 million of international bonds and the remaining in other local and international debts. The following chart presents YPF’s consolidated debt maturity profile as of September 30, 2026, excluding interest:
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Page 12/13 YPF 3Q26 3Q26 YPF 5. TABLES 5.1 CONSOLIDATED BALANCE SHEET Consolidated Balance Sheet Unaudited Figures 30-Sep-26 31-Dec-25 Non-current Assets Intangible assets 846 1,068 Properties, plant and equipment 19,893 19,085 Right-of-use assets 735 537 Investments in associates and joint ventures 2,243 1,610 Deferred income tax assets, net 24 9 Other receivables 678 648 Trade receivables 3 5 Total Non-current Assets 24,422 22,962 Current Assets Assets held for disposal 1,670 1,019 Inventories 1,559 1,447 Contract assets 3 3 Other receivables 896 1,159 Trade receivables 1,975 1,654 Investment in financial assets 1,667 262 Cash and cash equivalents 1,987 933 Total Current Assets 9,757 6,477 Total Assets 34,179 29,439 Total Shareholders´ Equity 14,016 11,044 Non-current Liabilities Provisions 951 610 Deferred income tax liabilities, net 476 373 Contract liabilities 243 180 Income tax liability 756 830 Other taxes payable 11 18 Salaries and social security 171 63 Lease liabilities 442 273 Loans 8,672 8,226 Other liabilities 569 373 Accounts payable 5 6 Total non-current Liabilities 12,296 10,952 Current Liabilities Liabilities directly associated with assets held for sale 739 1,181 Provisions 299 229 Contract liabilities 150 117 Income tax liability 1,233 73 Taxes payable 401 217 Salaries and social security 366 336 Lease liabilities 324 298 Loans 1,578 2,355 Other liabilities 546 399 Accounts payable 2,231 2,238 Total Current Liabilities 7,867 7,443 Total Liabilities 20,163 18,395 Total Liabilities and Shareholders’ Equity 34,179 29,439 Note: Information reported in accordance with International Financial Reporting Standards (IFRS).
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Page 13/13 YPF 3Q26 3Q26 YPF 5.2 CONSOLIDATED INCOME STATEMENT 5.3 SUMMARY OF CONSOLIDATED CASHFLOW STATEMENT 6. ABOUT YPF YPF is the largest energy company in Argentina, fully integrated in the oil and gas value chain. Our main businesses are: (i) in the upstream, we produce ~30% of the country’s oil and gas, and we are the largest shale producer in Vaca Muerta, in process of divestment of conventional mature fields; (ii) in the downstream, we operate 3 refineries (+50% of Argentina’s refining capacity) and lead the local diesel and gasoline sales (market share >55%); and (iii) in new energies, YPF Luz, our subsidiary, is the third largest power generation company in Argentina. The Government is the controlling shareholder with a 51% stake, and YPF is listed in the NYSE and ByMA. 7. DISCLAIMER Additional information about YPF S.A., a sociedad anónima organized under the laws of Argentina (the “Company” or “YPF”) can be found in the “Investors” section on the website at www.ypf.com. This document does not constitute an offer to sell or the solicitation of any offer to buy any securities of the Company, in any jurisdiction. Securities may not be offered or sold in the United States absent registration with the U.S. Securities Exchange Commission (“SEC”), the Comisión Nacional de Valores (Argentine National Securities and Exchange Commission, or “CNV”) or an exemption from such registrations. No reliance may be placed for any purpose whatsoever on the information contained in this document or on its completeness. Certain information contained in this document may have been obtained from published sources, which may not have been independently verified or audited. No representation or warranty, express or implied, is given or will be given by or on behalf of the Compa ny, or any of its affiliates (within the meaning of Rule 405 under the Act, “Affiliates”), members, directors, officers or employees or any other person (the “Related Parties”) as to the accuracy, completeness or fairness of the information or opinions contained in this document or any other material discussed verbally, and any reliance you place on them will be at your sole risk. Any opinions presented herein are based on general information gathered at the time of writing and are subject to change without notice. In addition, no responsibility, obligation or liability (whether direct or indirect, in contract, tort or otherwise) is or will be accepted by the Company or any of its Related Parties in relation to such information or opinions or any other matter in connection with this document or its contents or otherwise arising in connection therewith. This document may also include certain non-IFRS (International Financial Reporting Standards) financial measures which have not been subject to a financial audit for any period. The information and opinions contained in this document are provided as at the date of this document and are subject to verification, completion and change without notice. This document includes “forward-looking statements” concerning the future. The words such as “believes,” “thinks,” “forecasts,” “expects,” “anticipates,” “intends,” “should,” “seeks,” “estimates,” “future” or similar expressions are included with the intention of identifying statements about the future. For the avoidance of doubt, any projection, guidance or similar estimation about the future or future results, performance or achievements is a forward-looking statement. Although the assumptions and estimates on which forward-looking statements are based are believed by our management to be reasonable and based on the best currently available inform ation, such forward-looking statements are based on assumptions that are inherently subject to significant uncertainties and contingencies, many of which are beyond our control. Forward-looking statements speak only as of the date on which they were made, and we undertake no obligation to release publicly any updates or revisions to any forward-looking statements contained herein because of new information, future events or other factors. In light of these limitations, undue reliance should not be placed on forward-looking statements contained in this document. Further information concerning risks and uncertainties associated with these forward- looking statements and YPF’s business can be found in YPF’s public disclosures filed on EDGAR (www.sec.gov) or at the web page of the Argentine National Securities and Exchange Commission (www.argentina.gob.ar/cnv). You should not take any statement regarding past trends or activities as a representation that the trends or activities will continue in the future. Accordingly, you should not put undue reliance on these statements. This document is not intended to constitute and should not be construed as investment advice. The information contained herein has been prepared to assist interested parties in making their own evaluations of YPF. Income Statement Unaudited Figures, in US$ million Revenues 6,557 6,574 4,643 -0.3% 41.2% 18,077 13,892 30.1% Costs (3,822) (3,609) (3,309) 5.9% 15.5% (10,619) (10,064) 5.5% Gross profit 2,735 2,965 1,334 -7.8% 105.0% 7,458 3,828 94.8% Selling expenses (626) (601) (462) 4.2% 35.6% (1,716) (1,468) 16.9% Administrative expenses (334) (323) (251) 3.4% 33.2% (948) (743) 27.7% Exploration expenses (15) (17) (17) -11.8% -11.8% (52) (68) -23.5% Inventories write-down and reversal of impairment losses of property, plant and equipment - (8) (5) N/A N/A (8) 4 N/A Other net operating results 161 (203) (48) N/A N/A (122) (397) -69.3% Operating income 1,921 1,813 552 6.0% 248.0% 4,612 1,156 299.0% Income from equity interests in associates and joint ventures 134 115 32 16.5% 318.8% 350 107 227.1%- - - Financial Income 31 63 28 -50.8% 10.7% 126 72 75.0% Financial Cost (304) (312) (257) -2.6% 18.3% (920) (821) 12.1% Other financial results 45 119 (16) -62.2% N/A 109 3 N/A Net financial results (228) (130) (245) 75.4% -6.9% (685) (746) -8.2% Net profit before income tax 1,827 1,798 339 1.6% 438.7% 4,277 517 727.3% Income tax (631) (593) (537) 6.4% 17.5% (1,467) (667) 119.9% Net (loss) / profit for the period 1,196 1,205 (198) -0.7% N/A 2,810 (150) N/A Net (loss) / profit for the period attributable to: Shareholders of the parent company 1,181 1,201 (206) -1.7% N/A 2,786 (172) N/A Non-controlling interest 15 4 8 275.0% 87.5% 24 22 9.1% Earnings per share attributable to shareholders of the parent company (basic and diluted) 0.30 0.31 (0.05) -3.2% N/A 0.71 (0.04) N/A 3Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M26 9M25 Y/Y ∆ Note: Information reported in accordance with International Financial Reporting Standards (IFRS). Summary Consolidated Cash Flow Unaudited Figures, in US$ million Cash BoP 1,318 1,326 774 -0.6% 70.3% 933 1,118 -16.5% Net cash flow from operating activities 2,863 2,372 1,225 20.7% 133.7% 7,100 3,221 120.4% Net cash flow from investing activities (1,955) (2,031) (1,662) -3.7% 17.6% (4,695) (4,303) 9.1% Net cash flow from financing activities (162) (328) 497 -50.6% N/A (1,277) 871 N/A FX adjustments & other (77) (21) (35) 266.7% 120.0% (74) (108) -31.5% Cash EoP 1,987 1,318 799 50.8% 148.7% 1,987 799 148.7% Investment in financial assets 1,667 1,156 217 44.2% 668.2% 1,667 217 668.2% Cash + short-term investments EoP 3,654 2,474 1,016 47.7% 259.6% 3,654 1,016 259.6% FCF 901 824 (759) 9.3% N/A 2,596 (2,081) N/A FCF = Cash flow from Operations less capex (Investing activities), M&A (Investing activities), and interest and leasing payments (Financing activities). 9M263Q26 2Q26 3Q25 Q/Q ∆ Y/Y ∆ 9M25 Y/Y ∆