Eni: results for the third quarter and nine months of 2026

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Eni: results for the third quarter and nine months of 202 6 3Q operational and financial results support further upgrade to FY ’26 outlook with record low debt and enhanced shareholders’ returns through extraordinary dividend and increased buyback

• 3Q ’26 performance reflects the strength of our strategy, continued execution and disciplined investment into high -

quality opportunities.

• Considering the excellent operating and financial performance of the nine months ‘26 and an improved cash flow projection for the ‘26 FY (€16. 5 bln), Eni has resolved to distribute an extraordinary dividend of € 0.46 per sh. (ca. € 1.3 bln) in December and a further increase of 12% in the buyback program to € 3.8 bln.

• Underlying E&P production up 7% to 1.83 mln boe/d driven by projects ramp -ups and full quarter contribution from Searah JV.

• A strategic contract to relaunch production at the giant Junin 5 field in Venezuela has been signed, materially enhanc ing future upstream growth options .

• Plenitude deconsolidation create s an efficient platform for acceleration in the next phase of growth.

• Dual exploration sale of 10% stake in Baleine project and monetization of infrastructure portfolio reflect efficient capital management. Binding agreements signed to farm out retained 10% stake in the Kutei basin in Indonesia.

• Strong cash generation and discipline d capital allocation reduce proforma gearing to historic low of 9%, reinforcing resilience and capacity to invest for growth.

Rome , October 23, 2026 - Eni's Board of Directors, chaired by Giusepp ina Di Foggia , yesterday approved the consolidated results for the third quarter and nine months of 2026 . Eni CEO Claudio Descalzi said:

“Eni’s excellent results in 3Q were driven by the strength of our operating model and disciplined investments into a well -diversified portfolio of advantaged assets.

Due to our strong fundamentals , continuously improving growth prospects , and a historically robust financial performance, we are well positioned to continue delivering to our customers affordable, secure and increasingly decarbonized supplies. In 3Q, E&P again delivered outstanding underlying production growth of 7%, reflecting project ramp -ups and full operativity of our assets and the benefit of the start -up of our Searah JV in Southe ast Asia . Moreover, during this quarter we have fast tracked a new wave of material initiatives in South America, Africa and Southeast Asia , which will enhance growth and cash generation for years to come.

Finally , thanks to our outstanding exploration activities, this year we have discovered 1.2 3 bln barrels of new hydrocarbon resources, well above our budget target, while also reducing our exploration costs . While growing upstream and ensuring steady results in our gas and power businesses and refining, we are also recording transition businesses results in excess of our expectations , increasingly contributing to the diversification of the Group’s earnings. The capital raise and the new governance of Plenitude have further derisked Eni’s balance sheet and will enable th is satellite to grow in a self-funded way.

Thanks to our key businesses , industrial execution and larger optionality, we are able to generate robust and recurring cash flows over wide market conditions.

Based on those fundamentals and the revised FY ‘26 cash flow outlook and with proforma gearing at historic lows, we are further raising the distribution by an extraordinary dividend of € 0.46 per share to be paid in 4Q and increasing again the buyback to € 3.8 bln, underscoring our continued commitment to sharing upside with shareholders .” Key operating and financial results Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

1,789 Hydrocarbon production kboe/d 1,829 1,756 4 1,805 1,691 7 6.0 Installed capacity from renewables at period end GW 6.1 4.8 27 6.1 4.8 27 5,375 Proforma adjusted EBIT ⁽ᵃ⁾ € million 5,994 2,996 100 14,905 9,358 59 3,516 subsidiaries 3,699 2,073 78 9,633 6,562 47 1,859 main JV /Associates ⁽ᵇ⁾ 2,295 923 149 5,272 2,796 89 Proforma adjusted EBIT (by segment ) ⁽ᵃ⁾

4,769 E&P 4,631 2,638 76 12,757 8,368 52

503 Global Gas & LNG Portfolio (GGP) and Power 445 346 29 1,275 1,206 6 521 Transition Businesses 601 331 82 1,473 929 59 (40) Refining, Chemicals and Sites in transformation 472 (53) .. 172 (580) ..

(378) Corporate, other activities and consolidation adjustments (155) (266) (772) (565) 3,857 Adjusted net profit before taxes ⁽ᵃ⁾ 4,330 2,273 90 10,565 7,222 46 2,333 Adjusted net profit (loss ) ⁽ᵃ⁾⁽ᶜ⁾ 2,801 1,247 125 6,436 3,793 70 3,319 Net profit (loss) ⁽ᶜ⁾ 3,205 803 299 7,595 2,518 202 4,469Cash flow from operations before changes in working capital at replacement cost ⁽ᵃ⁾4,287 3,297 30 11,634 9,486 23 4,270 Net cash from operations 4,359 3,078 42 10,056 8,980 12 1,838 Organic capital expenditure ⁽ᵈ⁾ 1,345 1,990 (32) 5,055 5,904 (14) 11,271 Net borrowings before lease liabilities ex IFRS 16 6,702 9,931 (33) 6,702 9,931 (33) 56,930 Shareholders' equity including non-controlling interest 57,640 52,966 9 57,640 52,966 9 15 Proforma gearing before lease liabilities ex IFRS 16 ⁽ᵃ⁾ (%) 9 9 (d) Net of expenditures relating to business combinations, purchase of minority interests and other non-organic items, also excludes the share of capex of sanctioned joint operators funded by Eni.(a) Non-GAAP measures. For further information see the paragraph "Non-GAAP measures" on pages 19 and subsequent.

(c) Attributable to Eni's shareholders.Q3 Nine months (b) The main JV/associates are listed in the "Reconciliation of Group proforma adjusted EBIT" on page 23.

PRICE SENSITIVE

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Strategic and financial highlights E&P excellent results underpinned by accretive production growth, while strengthening the portfolio with new material

initiatives

• In 3Q ’26, E&P reported a robust underlying production growth of 7% compared to 3Q ’25, net of price effects, and of 2% sequentially to 1 .83 mln boe /d, driven by new project s ramp -ups in West Africa, Mexico offshore , and Norway, and full operativity of the Searah JV.

• In Venezuela we signed strategic agreements with PDVSA to revitalize the giant Junin 5 oilfield under revised contractual terms and to export gas from the Perla field, gaining access to ca. 5.5 b ln boe of recoverable resources .

• In Argentina, the consortium YPF/Eni/XRG engaged in developing a massive integrated LNG project with a target export capacity of initial 12 mln tonnes/y, has applied for the Country’s fiscal regime to incentivize large investments (RIGI), marking a milestone towards the project’s FID , expected around the end of this year .

• New access via the farm -in of an exploration block off Uruguay and signed agreement for an adjacent block. Also awarded the Sapukala block with 100% participating interest in the Kutei Basin, in Indonesia, within the framework of the first Indonesia Petroleum Bidding Round 2026.

Continuing momentum at transition businesses translated into outperformance and increasing contribution to Group’s

earnings

• Enilive and Plenitude delivered adjusted EBITDA of €1 .8 bln in the nine -month ’26 (+20% vs last year) .

• Completed the agreement with Ares to establish joint control over Plenitude by means of a non -proportional share capital increase diluting Eni’s interest from 70% to 65% . With the new governance, this result ed in the deconsolidation of the entity from Eni’s balance sheet as of end of September ’26 .

• Thanks to the new structure , Plenitude can pursue efficient, self-funded sustainable long -term growth a nd is on track to reach the targeted installed capacity of 6 .5 GW at year -end.

• Enilive delivered strong results thanks to better biorefin ing margin environment , again confirming the importance of this emerging new source of clean fuel for transportation .

Portfolio management as a tool to anticipate asset monetization and to obtain an optimal risk -reward profile of the business • Closed a long -term partnership agreement with private equity investors relating to an infrastructural based E&P portfolio in exchange for a €1.8 bln capital contribution cashed in the quarter, which will be invested in higher -return projects.

• Completed the divestment of a 10% interest in the Baleine oilfield to Socar in line with our Dual -Exploration model.

• In October signed binding agreement s to farm out Eni’s retained 10% w.i. in two pools of Indonesian gas assets in the Kutei Basin to Pertamina and Medco, comprising the two giant development projects of the Northern and Southern hubs and the Geliga discovery.

Improved performance at the Transformation businesses • Better plant utilization rates in a favorable scenario drove a strong quarter at the Refining business.

• Reconversion to the transition of the main Versalis hubs of Brindisi/Priolo is progressing, while the scenario in the petrochemicals legacy business has taken another leg down.

Excellent 3Q results driven by volume growth, plant reliability and portfolio optimizations enabl ed the Company to fully capture the scenario upside. Proforma gearing at 9%, below the low end of the guided range , and €1 .9 bln of cash returns to shareholders.

3Q ‘26 Group’s proforma adjusted EBIT was € 6 bln, doubled y-o-y (up by 12% sequentially) due to robust performance across all businesses, including notable contributions from the E&P satellites, plus continuing restructuring benefits of the chemic als sector and lower central function overheads. Adjusted net profit more than doubled y -o-y to €2.8 bln.

• E&P reported € 4.63 bln of proforma adjusted EBIT, up 76% vs. 3Q’ 25 , driven by volume growth and improved mix in a supportive commodity environment, translating into better realizations of equity production.

• GGP and Power reported €0.4 5 bln of proforma adjusted EBIT, with GGP at €0.4 1 bln up 4 6% vs. 3Q ‘25 due to continued asset portfolio optimization in a more volatile market.

• Enilive reported proforma adjusted EBIT to €0. 41 bln up 80% vs 3Q ‘25 , driven by the biorefining business, which benefited from an improved market scenario and strong performance . Plenitude reported €0. 19 bln of proforma adjusted EBIT, up 95% y-o-y, driven by volume growth in the renewables business.

• Refining reported €0.7 3 bln of proforma adjusted EBIT, a significant increase over 3Q ’25 , driven by improved plant utilization rates into a strong scenario, partly capped by higher shipping costs and unfavorable differentials between heavy/sour vs light/sweet crudes. Versalis’ chemicals business continue s making progress in delivering the benefits of the ongoing restructuring and last year’s plant closures, but a loss of €0.1 8 bln, reflects a sharp deterioration in products margins .

3Q ’26 Group’s adjusted CFFO before working capital was € 4.29 bln, funding organic capex of € 1.3 bln. Cash returns to shareholders were € 1.9 bln, compris ing the first tranche of the ‘26 dividend (€0. 8 bln) and execution of the ‘26 buyback program (€ 1.1 bln). Net debt was € 6.7 bln at the end of 3Q ‘26, with proforma gearing at 9%.

3 Outlook 202 6 2026 developing as a year of outperformance thanks to solid business trends , enabling us to capture the upside of a supportive commodity scenario. This is translating into exceptional shareholders’ returns.

Specifically, our updated segmental guidance is providing:

• FY’26 underlying oil & gas production growth is raised to a range of 6-7%.

• FY’26 GGP adjusted proforma EBIT guidance is raised to around €1.5 bln, representing an increase of 50% compared with the initial level.

• Enilive FY proforma adjusted EBITDA is raised at €1. 4 bln, almost 30% higher than the original assumption while Plenitude EBITDA is expected at around €1.2 bln.

• Year -end installed renewable capacity at 6.5 GW, with further 1.2 GW under construction (Plenitude @100%); biorefinery capacity of 0.5 MTPA, in addition to available 1.65 MTPA, expected to reach mechanical completion at year end; further 1.5 MTPA of capaci ty is progressing (net Enilive).

On the financial side, we are strengthening our cash flow guidance , with proforma gearing falling to an all -time low :

• At our revised scenario1 adjusted CFFO is now expected to amount to €16. 5 bln, representing an underlying improvement of € 1.2 bln vs Group’s sensitivities2 and compared to our initial guidance , reflecting excellent underlying operational performance .

• Gross capex confirmed at €7 bln; net capex is guided to less than € 4.5 bln.

• Proforma gearing seen at the bottom of the 10 -15% guided range.

As a result of the Company’s improved outlook, we are raising cash distributions to shareholders by activating an extraordinary dividend amounting to €1.3 bln or € 0.46 per share and upping again the buyback to €3.8 bln:

• Considering the updated year -to-date scenario and outlook, Eni’s Board has resolved an extraordinary dividend3 of €0.46 per share (totaling € 1.3 bln) that is due to be paid on December 9, in line with the Group stated remuneration policy to return 100% of upside in CFFO due to a scenario above certain thresholds compared to the original assumptions4.

• The 2026 share repurchase plan is raised to €3.8 bln, up 12% from last quarter already revised guidance of €3.4 bln, in line with the Group distribution policy of returning 60% of upside vs. the budgeted CFFO (€11.5 bln) to shareholders till a Brent price of 90 $/bbl. The new buyback amount is almost triple the initial guidance of €1.5 bln at the budgeted cash flow.

• Confirmed the planned 2026 ordinary dividend of €1.1 per share (up 5% vs. 2025).

1 Brent price 95 $/bbl, SERM refining margin at 18 $/bbl (as adjusted to include differential and utility costs) and TTF gas pr ice of 55 €/MWh (exchange rate EUR/USD of 1.15).

2 Group’s sensitivities are confirmed as follows: €0.11 bln and €0.08 bln per each one -dollar change in the Brent price and SERM margin respectively; €0.03 bln for each one -euro per MWh change in the spot price of European gas.

3 Ex-dividend date December 7, 2026. Pursuant to article 83 -terdecies of the Italian Legislative Decree no. 58 of February 24, 1998, the right to receive the payment is determined with reference to the entries on the books of the intermediary – as set out in art. 83 -quater, paragraph 3 of the Italian Legislative Decree no. 58 of February 24, 1998 – at the end of the accounting day of December 8, 2026 (record date).

Holders of ADRs, outstanding at the record date of December 8, 2026, will receive € 0.92 per ADR, payable on January 8, 2027, with each ADR listed on the New York Stock Exchange representing two Eni shares. On ADR payment date, Citibank, N.A. will pay net of the amount of the withholding tax under Ital ian law applicable to all Depository Trust Company Participants.

4 Eni’s shareholders’ distribution policy foresees that 100% of the upside in adjusted CFFO is paid as extraordinary dividend i n case of a forecast Brent price scenario for the FY above 90 $/bbl and other variances, where gas prices and refining margins exceed scenario assumptions by more than 50%.

4 Exploration & Production Production and price s

Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

104.52 Brent dated $/bbl 97.00 69.07 40 94.05 70.85 33 1.163 Average EUR/USD exchange rate 1.151 1.168 (1) 1.161 1.119 4 1,789 Hydrocarbons production ⁽ᵃ⁾ kboe/d 1,829 1,756 4 1,805 1,691 7 832 Liquids kbbl/d 845 860 (2) 846 824 3 5,006 Natural gas mmcf/d 5,148 4,687 10 5,017 4,535 11 69.79 Average realizations ⁽ᵇ⁾ $/boe 69.31 52.07 33 64.77 52.68 23 96.50 Liquids $/bbl 85.59 64.00 34 84.65 65.43 29 8.42 Natural gas $/kcf 9.60 7.40 30 8.39 7.37 14Q3 Nine months (a) In the third quarter 2026 and in the nine month 2026 , it includes 81 and 79 kboe /d, respectively , of production related to certain sanctioned joint‑venture partners .

(b) Prices related to consolidated subsidiaries.

• In Q3 ’26, hydrocarbons production averaged 1.83 mln boe/d, 4% higher than the comparative period (1.8 1 mln boe/d in the nine months ’26, up 7% from the comparative period) driven by project s ramp -ups in Congo and Mexico, and higher contribution from Indonesia/Malaysia benefitting from the full operativity of the Searah JV, as well as operational continuity. Quarterly underlying y -o-y production growth was 7%, adjusted for impact of portfolio transactions and price effects.

• Liquids production was 845 kbbl/d in Q3 ’26, representing a 2% decrease compared to Q3 ’25 (846 kbbl /d in the nine months ’26, up 3% from the comparative period), due to portfolio transactions and price effects offset by growth in Congo, Indonesia/Malaysia and Mexico.

• Natural gas production was 5,1 48 mmcf/d, an increase of 10% compared to Q3 ’25 (5,0 17 mmcf/d in the nine months ’26, 11% higher than the comparative period) mainly due to organic growth in Congo, Indonesia/Malaysia and Norway.

Results

Q2 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

5,861 Upstream turnover 5,686 4,616 23 16,497 14,723 12 4,769 Proforma adjusted EBIT 4,631 2,638 76 12,757 8,368 52 1,793 of which: main JV/Associates 1,927 838 .. 4,794 2,679 79 1,651 Operating profit (loss) of subsidiaries 2,440 1,670 46 5,942 5,116 16 1,325 Exclusion of special items 264 130 2,021 573 2,976 Adjusted operating profit (loss) of subsidiaries 2,704 1,800 50 7,963 5,689 40 3,469 Adjusted profit (loss) before taxes 3,223 2,015 60 9,090 6,428 41 35.2 tax rate (%) 34.8 41.7 35.9 44.8 2,249 Adjusted net profit (loss) 2,100 1,175 79 5,829 3,547 64 167 Exploration expenses: 65 45 44 285 131 ..

81 prospecting, geological and geophysical expenses 57 36 58 191 122 57 86 write-off of unsuccessful wells 8 9-11.1111 94 9 1,526 Capital expenditure 1,091 1,535 (29) 4,232 4,310 (2)Q3 Nine months

Q2 2026 Main JV/Associates 2026 2025 % Ch. 2026 2025 % Ch.

1,793 Adjusted operating profit (Eni's share) (€ million) 1,927 838 .. 4,794 2,679 79 1,217 of which: Vår Energi 1,212 479 .. 3,132 1,488 ..

286 Azule Energy 216 204 6 679 654 4 592 Adjusted net profit 498 299 67 1,289 794 62 250 Total dividends 876 307 .. 1,434 903 59 566 Hydrocarbon production (kboe/d) 648 493 31 580 452 28Q3 Nine months

• In 3Q ’26, Exploration & Production reported a proforma adjusted EBIT of € 4,631 mln, increasing by 76% vs. 3Q ’25 driven by volume growth and improved mix in a supportive commodity environment, translating into better realizations of equity production , higher crude oil realized prices in USD (the Brent marker was up by 40%) and higher gas realizations (up by 30%) . In the nine months ’26, proforma adjusted EBIT was € 12,757 mln, up 52% compared to the nine months ’25, due to the same drivers as for the 3Q. Business segments: operating and financial results

5 • In 3Q ’26, the segment reported an adjusted net profit of € 2,100 mln, an increase of 79% y-o-y and include d a higher contribution from JVs and associates. Adjusted net profit was € 5,829 mln in the nine months ’26, an increase of 64% y-

o-y.

• In 3Q ’26 the tax rate was about 3 5%, lower than in 3Q ’25 (42%) , due to a more favorable geographical mix of pretax profit.

For the disclosure on business segment special charges, see “Special items” in the Group results section.

Strategic developments

• In an exceptional year for exploration, discovered resources in the nine months ‘26 stand at 1.23 bln boe from activities in Angola, Namibia, Côte d’Ivoire, Libya, Egypt, Norway and Indonesia.

• In August, Argentina LNG, the integrated liquefied natural gas (LNG) project promoted by YPF, Eni and XRG, has submitted its application to join Argentina’s Large Investment Incentive Regime (RIGI), supporting the development of a large -scale LNG export pr oject leveraging the resources of the Vaca Muerta formation. The submission of the RIGI application represents an important milestone toward the project’s Final Investment Decision (FID) targeted by the end of 2026.

• In August, Eni and Sonatrach signed a new Memorandum of Intent aimed at expanding cooperation between the two companies in the promotion of concrete initiatives for the decarbonisation of the Oil & Gas sector and the reduction of emissions in Algeria, whil e adopting international best practices. In particular, the parties will cooperate in the field of natural CO ₂ removal initiatives through forestry projects and will strengthen activities for the monitoring, quantification and reduction of methane emissions through the adoption of relevant international Oil & Gas standards.

• In August, Eni signed with MIWEN (a wholly owned subsidiary of YPF) and the Uruguayan National Oil Company ANCAP, the agreement for entering the OFF -5 exploration block offshore Uruguay, following approval by the Uruguayan authorities. Eni is the operator of the OFF -5 block with a 50 % interest. Eni’s entry into Uruguay alongside MIWEN further strengthens the collaboration between Eni and YPF, partners in the integrated upstream -midstream Argentina LNG (ARGLNG) project, as well as Eni’s presence in South America.

• In September, Eni signed the “Contrato de Participación Productiva de Hidrocarburos” (CPPH) for the development of the Junín 5 giant oil field, located onshore in the Orinoco Belt. The signing of the CPPH marks the completion of the process launched with the signing of the Head of Terms in April . The 25-year agreement , with the possibility of extension, grants Eni the role of exclusive operator of the Junín 5 area, with full responsibility for the technical, financial and commercial management of the project. Junín 5 is a heavy oil field containing 35 b ln bbl of certified oil in place. It currently produces approximately 12 kbbl/d.

• In September, Eni announced the completion of the sale of a 10% stake in the Baleine project in Côte d’Ivoire to SOCAR.

The transaction aligns with Eni's strategy of optimising its upstream portfolio through its Dual Exploration approach.

• In September, Eni was awarded a new exploration licence o n the Sapukala block in the prolific Kutei Basin, Indonesia.

• In October, Eni signed two binding agreements to sell interests in certain Indonesian upstream assets operated by Searah , which comprised a 10% interest in the East Sepinggan, North Ganal, and Rapak PSCs to Pertamina, Indonesia’s national energy company and a 10% interest in the West Ganal, East Ganal, Ganal and Muara Bakau PSCs to Medco, a Southeast Asian energy and natural resources company. These transactions help to further confirm the material value created by Eni through the operation of M&A, exploration and project development. Completion of both transactions is subject to governmental and regulatory approvals.

6 Global Gas & LNG Portfolio and Power Sales and production Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

Global Gas & LNG Portfolio 47 Spot Gas price at Italian PSV €/MWh 66 36 86 52 41 27

46 TTF 63 32 95 50 38 30

1 Spread PSV vs. TTF 3 3 (3) 2 3 (14) Natural gas sales bcm 5.62 Italy 5.46 4.26 28 18.75 14.70 28 4.27 Rest of Europe 3.80 3.72 2 13.39 12.79 5 0.08 Importers in Italy 0.08 0.09 (11) 0.25 0.59 (58) 4.19 European markets 3.72 3.63 2 13.14 12.20 8 0.86 Rest of World 1.42 1.20 18 3.19 2.82 13 10.75 Worldwide gas sales ⁽ᵃ⁾ 10.68 9.18 16 35.33 30.31 17 2.9 LNG sales 3.1 3.3 (6) 9.4 8.9 6

Power

3.91 Thermoelectric production TWh 5.28 4.83 9 14.51 14.77 (2)Q3 Nine months (a) Data include intercompany sales.

• In 3Q ’26, natural gas sales were 10.68 bcm, an increase of 16% from the comparative period. Sales in Italy increased by 28% vs. 3Q ’25, while sales in the European market s amounted to 3.72 bcm, an increase of 2% vs. 3Q ’25, reflecting higher sales in France . LNG sales in 3Q ‘26 decreased by 6% compared to the same period of 2025 . In the nine months ’26, natural gas sales amounted to 35.33 bcm, up 17% vs the nine months ‘25, mainly thanks to high er gas volumes marketed in Italy (up 28% vs. the nine months ’25) and in the European markets (up 8% vs. the nine months ’25), in particular in Benelux and Germany /Austria.

• Thermoelectric production amounted to 5.28 TWh in 3Q ’26, up by 9% vs. 3Q ’25 with a higher plant utilization rate in order to capture the favorable environment scenario (14.51 TWh in the nine months ‘26, representing a decrease of 2% compared to the same period in 202 5).

Results

Q2 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

4,058 Sales from operations 6,290 3,503 80 15,723 12,537 25 503 Proforma adjusted EBIT 445 346 29 1,275 1,206 6

468 GGP 407 279 46 1,190 910 31

8 of which: main JV/Associates 6 4 50 23 23 -

35 Power 38 67 (43) 85 296 (71) 523 Operating profit (loss) of subsidiaries (703) 227 .. (322) 1,585 ..

(28) Exclusion of special items 1,142 115 1,574 (402) 495 Adjusted operating profit (loss) of subsidiaries 439 342 28 1,252 1,183 6 497 Adjusted profit (loss) before taxes 441 348 27 1,262 1,200 5 311 Adjusted net profit (loss) 268 216 24 783 758 3 14 Capital expenditure 7 14 (50) 29 51 (43)Q3 Nine months

• In 3Q ’26, the Global Gas & LNG Portfolio business achieved a proforma adjusted EBIT of €4 07 mln, an almost 50% increase over the 3Q ‘25, due to continued asset portfolio optimizations and the benefits associated with capturing the heightened scenario volatility. In the nine months ’26, proforma adjusted EBIT amounted to € 1,190 mln, up by 31% compared to the nine months ’25 reflecting the same drivers as in the third quarter ‘26 and higher supplied volumes of LNG , as well as specific benefits relating to renegotiations and settlements.

• In 3Q ’26, the Power generation business reported a proforma adjusted EBIT of € 38 mln down by 43% compared to the 3Q ‘25, due to the circumstance that the 2025 results were impacted by a one -off item, as well as higher expenses, partly offset by improved electricity crack spreads. In the nine months ‘26, proforma adjusted EBIT was € 85 mln, down by € 211 mln or 71% compared to the nine months ’25 due to the same driver s as for the quarter.

For the disclosure on business segment special charges, see “Special items” in the Group results section.

7 Transition Businesses

Enilive

Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

Enilive

1,732 Spread EU HVO UCO-based vs UCO (CIF) $/tonnes 1,609 1,143 41 1,618 899 80 1,122 Spread US RD ⁽ᵃ⁾ UCO-based vs UCO 1,512 420 .. 1,128 449 ..

275 Bio throughputs ktonnes 262 315 (17) 789 881 (10) 74 Average bio refineries utilization rate % 71 85 70 79 5.24 Total Enilive sales mmtonnes 5.67 5.75 (1) 15.59 16.41 (5) 2.11 Retail sales 2.20 2.10 5 6.20 5.85 6 1.57 of which: Italy 1.65 1.49 11 4.61 4.14 11 2.47 Wholesale sales 3.00 3.21 (7) 7.85 8.92 (12) 1.74 of which: Italy 2.04 2.42 (16) 5.43 6.78 (20) 0.66 Other sales 0.47 0.44 7 1.54 1.64 (6)Q3 Nine months (a) Renewable Diesel.

• In 3Q ’26, bio throughputs were 0.26 mmtonnes, decreasing by 17% vs. the comparative period , driven by lower volumes processed at the Gela and Venice biorefiner ies following the planned shutdown , in order to enhance biorefinery configuration , partially offset by better performance of Chalmette biorefinery. In the nine months ‘26, bio throughputs decreased by 10% compared to the same period of 202 5, mainly reflecting the shutdown at Venice .

• In 3Q ’26, retail sales were 2.20 mmtonnes, a 5% increase vs 3Q ’25, supported by a positive performance in Italy . In the nine months ‘26, retail sales amounted to 6.20 mmtonnes, up by 6% vs. the nine months ’25, following the same driver of the quarter.

• In 3Q ’26, wholesale sales were 3 mmtonnes, a reduction of 7% y-o-y due to portfolio optimization in a competitive market in Italy. In the nine months ‘26, wholesale sales amounted to 7.85 mmtonnes, a reduction of 12% vs. the nine months ‘25, following the same drivers of the quarter.

Q2 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

6,917 Sales from operations 7,726 5,206 48 19,400 14,742 32 375 Proforma adjusted EBITDA 490 317 55 1,082 698 55 295 Proforma adjusted EBIT 410 233 76 843 457 84 28 of which: main JV/Associates 57 (8) .. 87 (32) ..

192 Operating profit (loss) of subsidiaries 389 219 78 764 393 94 70 Exclusion of inventory holding (gains) losses (154) (8) (189) 34 5 Exclusion of special items 118 30 181 62 267 Adjusted operating profit (loss) of subsidiaries 353 241 46 756 489 55 287 Adjusted profit (loss) before taxes 407 225 81 821 438 87 208 Adjusted net profit (loss) 296 163 82 597 304 96 293 Cash flow from operations before changes in working capital at replacement cost 404 283 43 862 608 42 (438) Net borrowings (882) (1,338) 34 (882) (1,338) 34 56 Capital expenditure 103 98 5 222 199 12Q3 Nine months

• In 3Q ’26 Enilive reported a proforma adjusted EBIT of € 410 mln, up by 76% compared to 3Q ’25 (€843 mln in the nine months ’26, compared to € 457 mln in the nine months ’25, up by 84%) mainly thanks to the biorefining business , which benefited from an improved market scenario , despite the Venice plant shutdown .

• Proforma adjusted EBITDA amounted to € 490 mln, increasing by 55% compared to the 3Q ’25 (€ 317 mln). In the nine months ’26 Enilive reported a proforma adjusted EBITDA of € 1,082 mln, compared to a n EBITDA of €698 mln in the nine months ’25 (up by 55%).

For the disclosure on business segment special charges, see “Special items” in the Group results section.

Strategic developments

• Starting from 1st September, BWT Alpine Formula One Team is using HVOlution, Enilive’s diesel biofuel produced from 100% renewable raw materials, to power its logistics vehicles during European rounds of the FIA Formula One World Championship.

• In September, Eni and Teha presented at the Cernobbio Forum the strategic study “Sustainable biofuels as a strategic lever for industrial competitiveness, energy security and decarbonization”. The study highlights renewable biofuels, including HVO and SAF, as an already available solution to support transport decarbonisation , strengthen energy security,

8 diversify supplies, reduce GHG emissions across the value chain, and preserve industrial competitiveness, capacity and skills of European countries.

• In September, Eni and Petronas signed a Feasibility Agreement (FA) to evaluate the development of high -performance bio-gasoline based on Ecofining ™ technology. The agreement will assess the technical, market, sustainability and performance aspects of renewable bio -gasolines for motor -sport and other commercial applications in supporting transport decarbonization.

• At the end of September, Eni launched the initiative “Eni for Italy” by introducing a price cap on fuels marketed on the Enilive stations at €2.19/l for diesel and €1.99/l for petrol, approximately 17 cents lower than current average levels , intended to help Italian customers withstand the rising energy costs . The price cap is linked to the excise tax relief in effect, and has been applied starting September 28, for an initial period of 30 days, with the possibility to be extended through the end of the year depending on market and supply trends.

• In October, Eni extended the price reduction on fuels marketed to the agricultural and fishing sectors, through a discounted price of 20% net of VAT. The discount will apply until October 31, and may be extended until the end of the year, depending on market conditions and product availability.

Plenitude

Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

Plenitude

124 Italian PUN Index GME €/MWh 182 110 65 145 117 24 10.8 Retail and business customers at period end mln pod 10.8 9.9 9 10.8 9.9 9 0.65 Retail and business gas sales to end customers bcm 0.41 0.47 (13) 3.33 3.54 (6) 5.14 Retail and business power sales to end customers TWh 6.41 4.84 32 16.74 13.83 21 6.0 Installed capacity from renewables at period end GW 6.1 4.8 27 6.1 4.8 27 2.2 Energy production from renewable sources TWh 2.2 1.6 38 6.2 4.3 44 23.2 EV charging points at period end thousand 23.3 22.1 5 23.3 22.1 5Q3 Nine months

• As of September 30, 202 6, retail and business customers were 10.8 mln (gas and electricity), an increase of 0.9 mln compared to September 30, 2025 mainly benefitting from the acquisition of the Acea Energia customer portfolio.

• Retail and business gas sales to end customers amounted to 0.41 bcm in 3Q ’26, decreasing by 13% compared to 3Q ’25. In the nine months ‘26, gas sales amounted to 3.33 bcm, decreasing by 6% vs. the comparative period, due to greater competitive pressure .

• Retail and business power sales to end customers were 6.41 TWh in 3Q ’26, reflecting an increase of 32% compared to 3Q ’25, due to higher sales in Italy. In the nine months ’26 power sales amounted to 16.74 TWh (+21%), benefitting from increasing customer portfolio in the domestic business segment , following the above mentioned Acea Energia acquisition.

• As of September 30, 202 6, the installed capacity from renewables was 6.1 GW, with an increase of 1.3 GW compared to September 30, 2025, reflecting the organic development in Spain, the UK, Greece and Italy, as well as the acquisitions in France.

• Energy production from renewable sources was 2.2 TWh in 3Q ’26, up by 38% y -o-y, mainly thanks to the increased capacity in France and the development of organic projects in Spain and UK (6.2 TWh in the nine months ’26, +44% vs.

the comparative period).

• As of September 30, 202 6, EV charging points amounted to 23.3 thousand, up by 5% compared to 22.1 thousand as of September 30, 2025, thanks to network development, mainly in Italy, France and Germany.

9 Q2

2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

2,075 Sales from operations 2,444 1,818 34 7,749 7,421 4 233 Proforma adjusted EBITDA 204 221 (8) 745 835 (11) 226 Proforma adjusted EBIT 191 98 95 630 472 33 52 Operating profit (loss) of subsidiaries 864 23 .. 1,690 87 ..

147 Exclusion of special items (707) 69 (1,134) 371 199 Adjusted operating profit (loss) of subsidiaries 157 92 71 556 458 21 189 Adjusted profit (loss) before taxes 165 84 96 558 420 33 130 Adjusted net profit (loss) 120 53 .. 384 276 39 154 Cash flow from operations before changes in working capital at replacement cost 117 163 (28) 519 743 (30) 118 Capital expenditure 142 190 (25) 361 530 (32)Q3 Nine months • In 3Q ’26 Plenitude reported a proforma adjusted EBIT of € 191 mln, up by 95% vs 3Q ’25 , benefiting from volume growth in the renewables business and the halting of depreciation connected to the deconsolidation transaction . In the nine months ’26 Plenitude reported a proforma adjusted EBIT of € 630 mln, an increase of 33% compared to a proforma adjusted EBIT of € 472 mln in the nine months ’25.

• In 3Q ’26, proforma adjusted EBITDA amounted to € 204 mln, down by 8% vs 3Q ’25 , reflecting the current competitive environment in retail and scenario conditions in particular renewable markets, offsetting renewables growth . In the n ine months ’26 proforma adjusted EBITDA was €745 mln, down by 11% compared to the nine months ’25 (€835 mln).

For the disclosure on business segment special charges, see “Special items” in the Group results section.

Strategic developments

• In September, Plenitude JV GreenIT started production at two photovoltaic facilities located in Northern Italy. The plants are expected to generate around 30 GWh of electricity annually, with a combined installed capacity of approximately 19 MW.

• From 1st October 2026, as part of the “Eni for Italy” initiative, Plenitude has been offering customers a 30% discount on the raw material component of its contractual offer for the supply of electricity and gas compared with its main fixed -

price offer, with price s locked in for two years. The initiative applicable to contracts signed by October 24, 2026 will support Italian customers in withstanding the current energy scenario , with Plenitude absorb ing the increase in costs of raw materials .

• In October, Plenitude’s shareholders Eni, Ares and EIP completed the reorganization of the ownership structure of the investee , effective as of September 30, 2026, as they closed a non -proportional capital increase of €1.56 bln, subscribed by Eni for 30% and resulting in the dilution of its participation interest at 65%. The transaction implied a pre -money 100% equity valuation of Plenitude of about €10.8 bln and an Enterprise Value of €13 bln . The new ownership structure is complemented by a governance model based on the joint control of Eni and Ares and has triggered loss of control of Eni over Plenitude with the consequent derecognition of all Plenitude’s assets and liabilities and recogniti on of the participation interest at fair value which will be accounted based on the equity -method going forward. For further information on the transaction see “Basis of presentation” below.

10 Refining , Chemical s and Sites in transformation Production and sales Q2 2026 2026 2025 % Ch. 2026 2025 % Ch.

Refining

8.3 Standard Eni Refining Margin (SERM) ⁽ᵃ⁾ $/bbl 28.1 8.9 .. 15.5 5.8 ..

3.37 Throughputs in Italy on own account mmtonnes 4.14 3.81 9 10.28 10.88 (5) 1.73 Throughputs in the rest of World on own account 2.47 2.79 (12) 6.43 7.95 (19) 5.10 Total throughputs on own account 6.61 6.60 0 16.71 18.83 (11) 74 Average refineries utilization rate % 86 84 76 81

Chemicals

0.61 Sales of chemical products mmtonnes 0.60 0.59 3 1.86 2.10 (11) 57 Average plant utilization rate % 43 47 (9) 53 50 6Q3 Nine months (a) Given volatility and market dislocations, the benchmark SERM refining margin has been calculated to factor such conditions.

Refining

• In 3Q ’26, the Standard Eni Refining Margin averaged 28.1 $/barrel vs. 8.9 $/barrel in 3Q ’25 mainly due to more favorable middle distillate crack spreads reflecting the continuing product tightness in connection with disrupted flows from the Middle East and plant outages against a backdrop of refinery closures in the Atlantic Basin (15.5 $/barrel in the nine months ‘26, representing a n increase vs. 5.8 $/barrel reported in the nine months ’25).

• In 3Q ’26, throughputs on own accounts at Eni’s refineries in Italy amounted to 4.14 mmtonnes, up 9% y-o-y, mainly benefitting from higher volumes at the Taranto refinery due to higher plant availability . In the nine months ’26 throughputs amounted to 10.28 mmtonnes, down by 5% vs. the comparative period. Throughputs outside Italy amounted to 2.47 mmtonnes, decreas ing by 12% vs. 3Q ’25, due to lower volumes processed connected to the closure of the Strait of Hormuz . In the nine months ’26, throughputs of 6.43 mmtonnes decreased by 19% vs nine months ’25, following the same drivers of the quarter .

Chemicals

• Sales of chemical products were 0.60 mmtonnes in 3Q ’26, almost in line with the comparative period due to higher production in particular polymers , despite the closing of the Brindisi and Priolo sites, but now under transformation, and weaker demand. In the nine months ‘26, sales amounted to 1.86 mmtonnes, representing a decrease of 11% from the comparative period due to the same drivers of the quarter .

• Margins remained weak across the board as commodity prices did not recover feedstock and energy input expenses due to European industry headwinds, sluggish economic activity, and competitive pressures from players with advantaged cost structure.

Results

Q2 2026 (€ million ) 2026 2025 % Ch. 2026 2025 % Ch.

6,441 Sales from operations 7,050 4,545 55 17,603 14,010 26 (40) Proforma adjusted EBIT 472 (53) .. 172 (580) ..

80 Refining ⁽ᵃ⁾ 727 135 439 793 35 ..

3 of which: main JV/Associates 271 83 .. 294 112 ..

(65) Chemicals (178) (188) 5 (401) (615) 35 (55) Sites in transformation (77) 0 (220) 0 (129) Operating profit (loss) of subsidiaries (45) (291) 85 (347) (1,593) 78 (151) Exclusion of inventory holding (gains) losses (300) 69 (855) 496 237 Exclusion of special items 546 86 1,080 405 (43) Adjusted operating profit (loss) of subsidiaries 201 (136) .. (122) (692) 82 (63) Adjusted profit (loss) before taxes 423 (58) .. 101 (608) ..

(87) Adjusted net profit (loss) 313 (74) .. (3) (581) 99 282 Capital expenditure 39 142 (73) 479 430 11Q3 Nine months (a)Due totheshutdown ofthegasoline production unit inthefirst half 2026, theLivorno hub, currently being upgraded toabiorefinery, has been reclassified tothesegment “Sites intransformation ”effective January 1, 2026.

• In 3Q ’26, the Refining business, including the contribution from the ADNOC R&GT associate, reported a massive proforma adjusted profit of €7 27 mln, up more than 400% over the 3Q ‘25. This performance reflected the business’s ability to capture the upside of a very favorable margin scenario due to plan t availability and slightly improved utilization rates and a recovery in ordinary export and trading activities at the associate. Those positives were partly offset by higher

11 shipping expenses , narrowing differentials between heavy/sour vs . light/sweet crudes , which penalized margins at complex cycles and also some hedging factors. In the nine months ’26 , the business reported a proforma adjusted profit of €793 mln, an increase compared to the proforma adjusted profit of €35 mln reported in the nine months ’25.

• In 3Q ’26, the Chemical business’s proforma adjusted loss of €1 78 mln ( slightly lower vs. 3Q ‘25) was affected by an anticipated resumption of the structural weak trends that have been characterizing the European sector for the latest years, following the temporary second quarter rebound due to the fallouts from the crisis of the Strait of Hormuz. In 3Q ‘26, rapidly escalating costs of oil -based feedstock and higher expenses for energy and other plant utilities have not been transferred to commodity plastics final prices due to macro headwinds impacting commodity demands and competitive pressures from play ers with advantaged cost structures in a backdrop of global overcapacity, resulting in products margins falling below the already depressed levels recorded in the year -ago quarter. Negative scenario effects were absorbed by optimization actions and cost efficiencies deriving from ongoing restructuring initiatives and last year’s plant closures. In the nine months ’26, proforma adjusted loss amounted to € 401 mln, 35% better than the € 615 mln loss recorded in the nine months ’25.

• The Sites in transformation business is currently managing restructuring, decommissioning and environmental remediation operations at petrochemical hubs shut down, including the Brindisi and Priolo hubs, to prepare the sites for the next investment transformation phase. The reported loss of €77 mln reflected operating expenses incurred as part of the upgrading plan, while environmental and decommissioning provisions have been classified as special items.

For the disclosure on business segment special charges, see “Special items” in the Group results section.

12 The main developments of the Group strategy aimed at improving Eni’s ESG performance and building longer -term opportunities in the energy market have been:

• In July, Eni open ed up its supercomputing infrastructure to companies, start -ups and research centres , making its computational capacity, specialist expertise and advanced tools available to support the development of artificial intelligence solutions and digital innovation. Among the first companies and institutions to join the initiative are Domyn, Merc uria, Dompé, Almawave, Reply and the Bruno Kessler Foundation. Other companies, institutions and research centres will be able to join the initiative over time through project proposals of mutual interest .

• In September, Eni Foundation inaugurated the maternity ward at Karwasa Health Centre, in the Musanze District of Rwanda. The initiative is part of a project aimed at strengthening maternal and child healthcare services in the country, with a particular foc us on the management of basic and specialized obstetric and neonatal emergencies.

• In September, Eni signed an agreement with Generative Bionics, an Italian deep -tech company specialising in the development of humanoid robots powered by Physical AI, to assess potential areas of technological and industrial collaboration in advanced robotics.

• In September, Systema Foundation was established , an Italian alliance that brings together businesses, industry, finance, associations, and institutions , including Eni and other ma in companies, with the target of strengthening the competitiveness of production chains through collaboration, shared models and the Open -es platform.

• In September, Eni ranked first out of 28 companies in Bloomberg ESG scores.

• In October, Eni CCUS Holding announced that Liverpool Bay CCS has completed the installation of the new Douglas CCS platform in Liverpool Bay, marking a major step forward in the delivery of the CO2 Transportation and Storage project that serves as the bac kbone of the HyNet industrial decarbonisation cluster in the UK. The new Douglas CCS is the first purpose -built offshore platform dedicated to Carbon Capture and Storage for industrial decarbonisation in the world.

• In October, the Bouri Gas Utilization Project was completed in Libya, allowing the recovery of associated gas from the field. The project represents one of the most significant emission -reduction initiatives in Libya’s energy sector, with greenhouse gas emissions expected to decrease by approximately 1.5 million tonnes of CO₂ per year. The recovered gas will be used to meet domestic demand.

• In October, for the third consecutive year, Eni has received the “Gold Standard reporting” designation from the Oil and Gas Methane Partnership 2.0 for its commitment to reporting emissions with the highest levels of data quality.

Sustainability and other developments

13 Q2

2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

24,375 Sales from operations 28,072 20,204 39 75,409 61,536 23 1,898 Operating profit (loss) 2,477 1,344 84 6,548 4,834 35 (151) Exclusion of inventory holding (gains) losses (383) 117 .. (968) 475 ..

1,769 Exclusion of special items ⁽ᵃ⁾ 1,605 612 .. 4,053 1,253 ..

3,516 Adjusted operating profit (loss) 3,699 2,073 78 9,633 6,562 47 1,859 main JV/Associates adjusted EBIT 2,295 923 .. 5,272 2,796 89 5,375 Proforma adjusted EBIT 5,994 2,996 .. 14,905 9,358 59

4,769 E&P 4,631 2,638 76 12,757 8,368 52

503 Global Gas & LNG Portfolio (GGP) and Power 445 346 29 1,275 1,206 6 521 Transition Businesses 601 331 82 1,473 929 59 (40) Refining, Chemicals and Sites in transformation 472 (53) .. 172 (580) ..

(378) Corporate, other activities and consolidation adjustments (155) (266) (772) (565) 3,857 Adjusted profit (loss) before taxes 4,330 2,273 90 10,565 7,222 46 2,434 Adjusted net profit (loss) 2,931 1,315 .. 6,740 3,943 71 3,376 Net profit (loss) 3,492 865 .. 8,147 2,621 ..

3,319 Net profit (loss) attributable to Eni's shareholders 3,205 803 .. 7,595 2,518 ..

(120) Exclusion of inventory holding (gains) losses (235) 87 .. (633) 333 ..

(866) Exclusion of special items ⁽ᵃ⁾ (169) 357 .. (526) 942 ..

2,333 Adjusted net profit (loss) attributable to Eni's shareholders 2,801 1,247 .. 6,436 3,793 70Q3 Nine months (a) For further information see table "Breakdown of special items".

• In 3Q ’26, Eni Group earned €6 bln of adjusted proforma EBIT , doubled from 3Q ‘25, up € 3 bln, with improved performance across almost all businesses, which were able to capture the upsides of a favorable commodity scenario thanks to volume growth, cost efficiencies and margin optimizations. E&P delivered €4 .6 bln of adjusted proforma EBIT, a €2 bln improvement driven by organic production growth and a solid contribution from its satellites, particularly with the ramp -

up of the Searah JV in Southeast Asia . The refining business marked a solid quarter due to a very profitable margin environment. The Transition -related satellites achieved €0 .6 bln, almost double the amount of the 3Q ‘25, thanks to volume growth and margin expansion. In a challenging scenario, the Chemical arm was nonetheless able to pair a decline in commodity margins leveraging the ongoing restructuring efforts, while the rec onversion of old sites to the transition is progressing.

• In 3Q ’26 adjusted profit before taxes was €4.3 3 bln, 9 0% higher than 3Q ’25, reflecting the trend in the Group adjusted EBIT and higher profits reported at equity -accounted entities, partly offset by increased finance expenses (up €0.06 bln) over the third quarter 2025 due to higher rates of gross debt and lower income of fair valued held -for-trading securities driven by higher yields. In the nine months ‘26, the Group reported an adjusted profit before taxes of €10. 57 bln, up 4 6% compared to the nine months ’25.

• In 3Q ’26 adjusted net profit attributable to Eni’s shareholders of €2 .80 bln more than doubled compared to 3Q ’25, factoring in a lower adjusted tax rate down to 3 2% from 4 2%, due to a better geographical mix of profits before taxes in E&P reflecting higher contribution from jurisdictions with lower -than -average tax rates and improved results of Italian subsidiaries driving a higher contribution to Group results . In the nine months ‘26, the Group reported an adjusted net profit attributable to Eni’s shareholders of €6 .44 bln, up 7 0% compared to the nine months ’25.

Group results

14 Net borrowings and cash flow from operations Q2 2026 (€ million ) 2026 2025 Change 2026 2025 Change 3,376 Net profit (loss) 3,492 865 2,627 8,147 2,621 5,526 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

140 - depreciation, depletion and amortization and other non monetary items (352) 1,505 (1,857) 1,424 5,063 (3,639)

- net gains on disposal of assets (45) (32) (13) (50) (38) (12) 1,539 - dividends, interests and taxes 1,274 891 383 3,974 3,275 699 269 Changes in working capital related to operations 178 435 (257) (1,338) 627 (1,965) 578 Dividends received by equity investments 1,112 417 695 1,980 1,296 684 (1,196) Taxes paid (1,148) (812) (336) (3,199) (3,042) (157) (436) Interests (paid) received (152) (191) 39 (882) (822) (60) 4,270 Net cash provided by operating activities 4,359 3,078 1,281 10,056 8,980 1,076 (2,041) Capital expenditure (1,415) (2,017) 602 (5,423) (5,790) 367 (735) Investments and acquisitions (134) (229) 95 (934) (580) (354) (281) Disposal of consolidated subsidiaries, businesses, tangible and intangible assets and investments 215 1,275 (1,060) (56) 1,359 (1,415) 240 Other cash flow related to investing activities (244) (93) (151) 11 (268) 279 1,453 Free cash flow 2,781 2,014 767 3,654 3,701 (47) 9 Net cash inflow (outflow) related to financial activities (1,895) (459) (1,436) (2,725) (649) (2,076) 104 Changes in short and long-term financial debt 1,669 (97) 1,766 4,129 (1,421) 5,550 (327) Repayment of lease liabilities (272) (303) 31 (941) (978) 37 (1,452) Dividends paid, share repurchases, changes in non-controlling interests and reserves 907 (1,371) 2,278 (1,620) 193 (1,813) (156) Issue of perpetual hybrid bond and interest payment (30) (1) (29) 774 125 649 8 Effect of changes in consolidation and exchange differences of cash and cash equivalent 57 2 55 80 (202) 282

(361) NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENT 3,217 (215) 3,432 3,351 769 2,582

4,469 Adjusted net cash before changes in working capital at replacement cost 4,287 3,297 990 11,634 9,486 2,148 Q2 2026 (€ million ) 2026 2025 Change 2026 2025 Change 1,453 Free cash flow 2,781 2,014 767 3,654 3,701 (47) (327) Repayment of lease liabilities (272) (303) 31 (941) (978) 37 (9) Net borrowings of acquired companies (9) (9) (238) Net borrowings of divested companies 1,846 1,846 1,608 1,608 307 Supplier financing agreements, exchange differences and other changes (663) (72) (591) (640) (797) 157 (1,452) Dividends paid and changes in non-controlling interest and reserves 907 (1,371) 2,278 (1,620) 193 (1,813) (156) Issue of perpetual hybrid bond and interest payment (30) (1) (29) 774 125 649

(422) CHANGE IN NET BORROWINGS BEFORE LEASE LIABILITIES 4,569 267 4,302 2,826 2,244 582

327 Repayment of lease liabilities 272 303 (31) 941 978 (37) (141) Inception of new leases and other changes (445) (113) (332) (855) (43) (812)

(236) CHANGE IN NET BORROWINGS AFTER LEASE LIABILITIES 4,396 457 3,939 2,912 3,179 (267)Q3

Q3Nine months

Nine months

In the nine months ’26, net cash provided by operating activities was €10,0 56 mln and included €1,980 mln of dividends received by Eni’s equity -accounted investments.

Adjusted net cash before changes in working capital at replacement cost was € 11,634 mln in the nine months ’26 (€4,28 7 mln in the Q 3 ’26) and is net of the following items:

• inventory holding gains or losses relating to oil and products ;

• the reversing of timing difference between gas inventories accounted at weighted average cost and management’s own measure of performance leveraging inventories to optimize margins ;

• the fair value of commodity derivatives lacking the formal criteria to be designated as hedges or prorated on an accrual

basis ;

• extraordinary risk and environmental provisions and other e xtraordinary charges/gains (the third quarter cash flow includes also the reversal of a gain accrued in the previous quarter relating to dividend distribution to JV Searah’s shareholders).

15 A reconciliation of adjusted net cash before changes in working capital at replacement cost to net cash provided by operating activities is provided below :

Q2 2026 (€ million) 2026 2025 Change 2026 2025 Change 4,270 Net cash provided by operating activities 4,359 3,078 1,281 10,056 8,980 1,076 (269) Changes in working capital related to operations (178) (435) 257 1,338 (627) 1,965 (123) Exclusion of commodity derivatives 828 50 778 900 (3) 903 (151) Exclusion of inventory holding (gains) losses (383) 117 (500) (968) 475 (1,443) 3,727 Net cash before changes in working capital at replacement cost 4,626 2,810 1,816 11,326 8,825 2,501 742 Extraordinary (gains) charges and other items (339) 487 (826) 308 661 (353) 4,469 Adjusted net cash before changes in working capital at replacement cost 4,287 3,297 990 11,634 9,486 2,148Q3 Nine months

In the nine months ’26 organic capex was € 5.06 bln (down 14% y-o-y) and excluded the share of capex that was reimbursed or is expected to be reimbursed upon closing of ongoing asset disposals, which has been used to net disposals of the period or reclassified in other cash flow s related to investing activities. Organic capex also excluded the share of capex pertaining to sanctioned joint operators, which was funded by Eni.

Net borrowings before lease liabilities ex IFRS 16 decreased by around € 2.8 bln in the nine months ’26 to €6.7 bln . The main inflows comprised the adjusted operating cash flow (€ 11.6 3 bln), a third -party capital contribution relating to the monetization of an upstream infrastructur al portfolio (€1.7 5 bln) and the issuance of a hybrid bond (€ 0.99 bln) which were utilized to fund cash outflows related to organic capex (€ 5.06 bln), working capital needs (€1. 4 bln), dividend payments to Eni’s shareholders and share repurchases of € 4.30 bln (dividend payments of € 2.33 bln and share repurchases of € 1.96 bln), repayment of lease liabilities and hybrid bond interest (€ 1.3 bln), acquisitions and other portfolio transactions (€1.3 bln) and the inception of supplier financing agreements and other changes (€ 1 bln). Group’s net borrowings benefited from Plenitude deconsolidation for approximately €2.75 bln.

Eni, following the authorization granted by the Shareholders' Meeting held on May 6, 2026, started a new share buyback program to be executed through April 2027 within the limit of the maximum authorized amount of €4 bln . In line with the Group remuneration policy, Eni’s management is planning to execute a buy -back program of €3.8 bln. As part of this, until October 16, 2026, around 85 mln shares have been purchased, for a cash outlay of € 1.95 bln .

16 Summarized Group Balance Sheet (€ million)Dec. 31, 2025 Sept. 30, 2026 Change

Fixed assets

Property, plant and equipment 50,536 49,997 (539) Right of use 5,184 5,100 (84) Intangible assets 6,022 1,525 (4,497) Inventories - Compulsory stock 1,187 1,787 600 Equity-accounted investments and other investments 14,484 25,791 11,307 Receivables financing and securities held for operating purposes 974 1,020 46 Net payables related to capital expenditure (1,337) (1,416) (79) 77,050 83,804 6,754 Net working capital Inventories 5,143 8,011 2,868 Trade receivables 8,986 11,288 2,302 Trade payables (13,901) (17,899) (3,998) Net tax assets (liabilities) 1,506 1,973 467 Provisions (14,580) (14,131) 449 Other current assets and liabilities (1,572) (4,235) (2,663) (14,418) (14,993) (575) Provisions for employee benefits (596) (719) (123) Assets held for sale including related liabilities 5,979 1,864 (4,115)

CAPITAL EMPLOYED, NET 68,015 69,956 1,941

Eni's shareholders equity 47,940 54,508 6,568 Non-controlling interest 4,847 3,132 (1,715) Shareholders' equity 52,787 57,640 4,853 Net borrowings before lease liabilities ex IFRS 16 9,528 6,702 (2,826) Lease liabilities 5,700 5,614 (86) Net borrowings after lease liabilities ex IFRS 16 15,228 12,316 (2,912)

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 68,015 69,956 1,941

Gearing before lease liabilities ex IFRS 16 0.15 0.10 Gearing after lease liabilities ex IFRS 16 0.22 0.18

As of September 30 , 202 6, fixed assets (€83.8 bln) increased by approximately €6.8 bln from December 31, 202 5, mainly due to initial recognition of the retained equity -accounted 65% ownership interest in Plenitude for €6. 8 bln following loss of control, and the initial recognition in June 2026 of the 50% investment in the JV Searah for € 4.9 bln resulting from the contribution in -kind of Eni’s gas assets in Indonesia . Capital expenditure for the period was €5.4 bln offset by DD&A . Positive exchange rate translation differences (the period -end exchange rate of EUR vs. USD was 1.135 down by 3 % compared to 1.176 as of December 31, 202 5) increased the euro reported amounts of dollar -denominated assets for € 2 bln.

Net working capital amount was €15 bln, a modest decrease over December 31, 2025 . Higher inventory book value because of the weighted average cost of supplies in an environment of rising commodity prices and net provisions utilizations were more than offset by the balance between trade receivables and payables (€1.7 bln) and the other current assets and liabilities (€2.7 bln) due to fair value changes of derivative instruments.

Asset held for sale included certain held -for-sale E&P properties.

Eni’s s hareholders equity (€54.5 bln) increased by € 6.6 bln from December 31, 202 5, mainly due to net profit for the period (€7.6 bln) and positive foreign currency translation differences (€ 1.7 bln), partly offset by the negative change in the cash flow hedge reserve of € 2.2 bln as well as by shareholders remuneration of approximately € 4.3 bln ( dividends and share buyback) . It was also recognized as Group equity a capital contribution of €1.8 bln from a pool of investors to participate in the future dividend stream from a portfolio of E&P infrastructural assets .

Non -controlling interests of €3.1 bln mainly included: i) a minority participating interest acquired by the private equity fund KKR in the share capital of Enilive (€ 0.9 bln) in 2025 ; ii) a perpetual subordinated hybrid bond (€ 1.8 bln) issued by a Group subsidiary in 2024, classified as equity since the Group retains an unconditional right to avoid transferring cash or other financial assets to the bondholders , (iii) while the €2 bln minority interest in Plenitude representing equity investments made by Ares and Eip funds was derecognized following loss of control over Plenitude by the Eni Group .

17 Net borrowings5 before lease liabilities as of September 30 , 202 6 of €6.7 bln were down by approximately €2.8 bln from December 31, 202 5. Gearing6 - the ratio of net borrowings to net capital employed before lease liabilities - was 0.10 on September 30 , 202 6.

Considering the portfolio transactions underway mainly relating to the sale of a 10% stake of the Indonesian assets, the Group proforma gearing stands at 0.09 .

Special items

The breakdown of pre -tax special items recorded in operating profit by segment (net charges of €4,0 53 mln and € 1,605 mln in the nine months ’26 and Q3 ’26, respectively) is as follows:

• E&P: net charges of € 2,021 mln were incurred in the nine months ’26 (€ 264 mln in Q3 ‘26). Those mainly comprised impairment losses at oil&gas properties driven by re -prioritization of investment capital away from future phases of development of marginal properties and instead a focus on the core projects in the portfolio consis tent with strategy, as well as downward reserves revisions (€1,231 mln and €28 mln in the nine months ’26 and Q3 ’26, respectively); credit loss provisions (€102 mln and €10 mln in the nine months ’26 and Q3 ’26, respectively), decommissioning activities in compliance with applicable regulations (€67 mln in both reporting period s), risk provisions (€44 mln and €33 mln in the nine months ’26 and Q3 ’26, respectively) and provisions for redundancy incentives (€38 mln and €29 mln in the nine months ’26 and Q3 ’26, respectively);

• GGP and Power: net charges of €1,574 mln in the nine months ’26 (net charges of €1,142 mln in Q3 ‘26) mainly relating to the accounting effect of certain fair -valued commodity derivatives lacking the formal criteria to be classified as hedges or to be waived from fair value accounting under the own use exemption (charge of €1,619 mln and €1,305 mln in the nine months ’26 and Q3 ’26, respectively). The reclassification of the positive balance of €176 mln (€24 mln in Q3 ‘26) related to derivatives covering margin exposure to foreign currency exchange rate movements and exchange translation differences of commercial payables and receivables;

• Transition Businesses: net gains of €953 mln (net gains of €589 mln in Q3 ‘26) mainly related to the fair values of commodity derivatives lacking the formal criteria to be classified as hedges under IFRS relating exposure to the gas commodity (gain of €1,102 mln and of €693 mln in the nine months ’26 and Q3 ‘26, respectively);

• Refining, Chemicals and Sites in t ransformation: net charges of €1,080 mln (€546 mln in Q3 ’26) mainly related to the fair values of commodity derivatives lacking the formal criteria to be classified as hedges under IFRS (€360 mln and €182 mln in the nine months ’26 and Q3 ’26, respectively); the write -down of capital expenditures made for compliance and stay -in-business at certain CGU with expected negative cash flows in Refining business (€210 mln and €48 mln in the nine months ’26 and Q3 ’26, respectively) as well as environmental charges of €316 mln (€226 mln in Q3 ’26).

Belo w operating profit, the main special items comprised a gain of around €2 bln on the contribution of gas assets in Indonesia to the Searah JV with Petronas made in June 2026 in exchange for a 50% participating interest in the new equity -

accounted entity and a round €1.5 bln gain on the alignment of the book value of the retained ownership interest in Plenitude at the fair value underlying the transaction with the private equity fund Ares triggering the loss of control over the former subsidiary and reme asurement of the retained ownership interest.

5 Details on net borrowings are furnished on page 2 5.

6 Non -GAAP financial measures and other alternative performance indicators disclosed throughout this press release are accompanied by explanatory notes and tables in line with guidance provided by ESMA guidelines on alternative performance measures (ESMA/20 15/1415), published on October 5, 2015. For further information, see the section “Non -GAAP measures” of this press release. See pages 19 and subsequent.

18 Other information, basis of presentation and disclaimer This press release on Eni’s unaudited results for the third quarter and the nine months of 2026 has been prepared on a voluntary basis according to article 82‐ter, Regulations on issuers (CONSOB Regulation No. 11971 of May 14, 1999, and subsequent amendments and inclusions ). The disclosure of results and business trends on a quarterly basis is consisten t with Eni’s policy to provide the market and investors with regular information about the Company’s financial and industrial performances and business prospects considering the reporting policy followed by oil&g as peers who are communicating results on quarterly basis.

Results and cash flow are presented for the second and third quarter of 202 6, the nine months of 202 6 and for the third quarter and the nine months of 202 5. Information on the Company’s financial position relates to end of the periods as of September 30, 202 6 and December 31, 202 5.

Accounts set forth herein have been prepared in accordance with the evaluation and recognition criteria set by the Internatio nal Financial Reporting Standards (IFRS) issued by the International Accounting Standards Board (IASB) and adopted by the European Commission according to the procedure set forth in Article 6 of the European Regulation (CE) No. 1606/2002 of the European Parliament and European Counci l of July 19, 2002.

These criteria are unchanged from the 202 5 Annual Report on Form 20‐F filed with the US SEC on March 23, 202 6, which investors are urged to read.

The Annual Report on Form 20 -F 2025 is published on Eni’s website (eni.com) in the “Publications” section.

Shareholders can request a hard copy of Eni’s Annual Report on Form 20 -F 2025, free of charge, by emailing a request to segreteriasocietaria.azionisti@eni.com or to investor.relations@eni.com .

Effective September 30, 2026, Eni and private equity investor Ares have closed a non -proportional share capital increase at Eni’s former subsidiary Plenitude, which was subscribed for 30% by Eni and the remaining by Ares, resulting in Eni diluting its owne rship interest to 65%. As part of the transaction, the two shareholders have agreed to a new governance framework, which is establishing joint control over the ent ity. Therefore, at closing Plenitude’s assets and liabilities have been derecognized from Eni Group consolidated accounts and the retained 65% ownership interest in the investee has been recognized at the net asset fair value underlying the transaction with the recording of a gain of around €1.5 billion given by difference between the book value of the derecognized net assets and the fair value of shareholding at the transaction date . This gain has been reported within results from discontinued operations. Going forward, the shareholding in Plenitude will be recognized as a joint venture acco unted with the equity method.

* * *

Non‐GAAP financial measures and other alternative performance indicators disclosed throughout this press release are accompan ied by explanatory notes and tables in line with guidance provided by ESMA guidelines on alternative performance measures (ESMA/201 5/1415), published on October 5, 2015. For further information, see the section “Alternative performance measures (Non‐GAAP measures)” of this press releas e.

The manager responsible for the preparation of the Company’s financial reports, Francesco Esposito, declares pursuant to rule 154‐bis paragraph 2 of Legislative Decree No. 58/1998 that data and information disclosed in this press release correspond to the Company’s evidence and accounting books and records.

* * *

Disclaimer

This press release contains certain forward‐looking statements particularly those regarding capital expenditure, development and management of oil and gas resources, dividends, share repurchases, allocation of future cash flow from operations, future opera ting performance, gearing, targets of production and sales growth, new markets and the progress and timing of projects. By their nature, forward‐looking statements involve risks and uncertainties because they relate to events and depend on circumstances th at will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the impact of the pandemic disease, the timing of bringing new fields on stream; management’s ability in car rying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply;

demand and pricing; operational issues; general economic conditions; political stability and economic growth in relevant area s of the world; changes in laws and governmental regulations; development and use of new technology; changes in public expectations and other changes in business conditions;

the actions of competitors and other factors discussed elsewhere in this document. Due to the seas onality in demand for natural gas and certain refined products and the changes in a number of external factors affecting Eni’s operations, such as prices and margins of hydrocarbo ns and refined products, Eni’s results from operations and changes in net bor rowings for the quarter of the year cannot be extrapolated on an annual basis.

Company Contacts

Press Office: Tel. +39.0252031875 ‐ +39.0659822030 Freephone for shareholders (from Italy): 800940924 Freephone for shareholders (from abroad): +80011223456 Switchboard: +39 ‐0659821

ufficio.stampa@eni.com

segreteriasocietaria.azionisti@eni.com

investor.relations@eni.com

website: www.eni.com

Eni Società per Azioni, Rome, Piazzale Enrico Mattei, 1 Share capital: €4,005,358,876 fully paid.

Tax identification number 00484960588 Tel.: +39 0659821 ‐ Fax: +39 0659822141

This press release for the third quarter and the nine months of 202 6 results (not subject to audit) is also available on Eni’s website eni.com.

19 Management evaluates underlying business performance on the basis of Non -GAAP financial measures, which are not provided by IFRS (“Alternative performance measures”), such as adjusted operating profit, adjusted net profit, which are arrived at by excluding from reported results certain gains and losses, defined special items, which include, among others, asset impairments, including impairments of deferred tax assets, gains on disposals, risk provisions, restructuring charges, the accounting effect of fair -valued derivatives used to hedge exposure to the commodity, exchange rate and interest rate risks, which lack the formal criteria to be accounted as hedges, and analogously evaluation effects of assets and liabilities utilized in a relation of natural hedge of the above mentioned market risks. Furthermore, in determining the business segments’ adjusted results, finance charges on finance debt and interest income are excluded (see below). In determining adjusted results, inventory holding gains or losses are excluded from base business performance, which is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold calculated using the weighted average co st method of inventory accounting as required by IFRS, except in those business segments where inventories are utilized as a lever to optimize margins. Finally, the same special charges/gains are excluded from the Eni’s share of results at JVs and other equity accounted entiti es, including any profit/loss on inventory holding.

Management is disclosing Non -GAAP measures of performance to facilitate a comparison of base business performance across periods, and to allow financial analysts to evaluate Eni’s trading performance on the basis of their forecasting models.

Non -GAAP financial measures should be read together with information determined by applying IFRS and do not stand in for them. Ot her companies may adopt different methodologies to determine Non -GAAP measures.

Follows the description of the main alternative performance measures adopted by Eni. The measures reported below refer to the performance of the reporting periods disclosed in this press release:

Adjusted operating and net profit Adjusted operating profit and adjusted net profit are determined by excluding inventory holding gains or losses, special item s and, in determining the business segments’ adjusted results, finance charges on finance debt and interest income. The adjusted op erating profit of each business segment reports gains and losses on derivative financial instruments entered into to manage exposure to movements in foreign currency exchange rates, w hich impact industrial margins and translation of commercial payables and receivables. Accordingly, also currency translation effects recorded through profit and loss are reported within business segments’ adjusted operating profit. The taxation effect of the items excluded from adjusted operating or net profit is determined ba sed on the specific rate of taxes applicable to each of them.

Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. Therefore, t he adjusted net profit of business segments includes finance charges or income deriving from certain segment operated assets, i.e., interest income on certain receivable financin g and securities related to operations and finance charge pertaining to the accretion of certa in provisions recorded on a discounted basis (as in the case of the asset retirement obligations in the Exploration & Production segment).

Inventory holding gain or loss This is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes sold calculated using the weighted average cost method of inventory accounting as requi red by IFRS.

Special items

These include certain significant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non -recurring items under such circumstances; (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past periods or are likely to occur in future ones. Exchange rate differences and derivatives relating to industrial activities and commer cial payables and receivables, particularly exchange rate deriva tives to manage commodity pricing formulas which are quoted in a currency other than the functional currency are reclassified in operating profit with a corresponding adjustment to net finance charges, notwithstanding the handling of foreign currency excha nge risks is made centrally by netting off naturally -occurring opposite positions and then dealing with any residual risk exposure in the derivative market. Finally, special item s include the accounting effects of fair -valued commodity derivatives relating to commercial exposures, in addition to those which lack the criteria to be designed as hedges, also those which are not eligible for the own use exemption, including the ineffective portion of cash flow hedges, as well a s the accounting effects of settle d commodity and exchange rates derivatives whenever it is deemed that the underlying transaction is expected to occur in future reporting periods.

Correspondently, special charges/gains also include the evaluation effects relating to assets/liabilities utilized in a natur al hedge relation to offset a market risk, as in the case of accrued currency differences at finance debt denominated in a currency other than the reporting currency, where the cash outflows for the reimbursement are matched by highly probable cash inflows in the same currency. The deferral of both the unrealized portion o f fair -valued commodity and other derivatives and evaluation ef fects are reversed to future reporting periods when the underlying transaction occurs.

As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non -recurring material income or charges are to be clearly reported in the management’s discussion and financial tables.

Gearing

Gearing is calculated as the ratio between net borrowings and capital employed net and measures how much of capital employed net is financed recurring to third -party funding. Gearing ex -IFRS 16 is calculated by excluding lease liabilities and right -of-use assets from numerator and denominator , respectively . On a proforma basis gearing is calculated net of pending portfolio transactions.

Cash flow from operations before changes in working capital at replacement cost (Adjusted net cash before changes in working capital at replacement cost ) This is defined as net cash provided from operating activities before changes in working capital at replacement cost. It also excludes certain non -recurring charges such as extraordinary credit allowances and, considering the high market volatility, chang es in the fair value of commodity derivatives lacking the formal criteria to be designed as hedges, including derivatives which were not eligible for the own use exemption, the ineffective p ortion of cash flow hedges, as well as the effects of certain sett led commodity derivatives whenever it is deemed that the underlying transaction is expected to occur in future reporting peri ods.

Free cash flow Free cash flow represents the link existing between changes in cash and cash equivalents (deriving from the statutory cash fl ows statement) and in net borrowings (deriving from the summarized cash flow statement) that occurred from the beginning of the per iod to the end of period. Free cash flow is the cash in excess of capital expenditure needs. Starting from free cash flow it is possible to determine either: (i ) changes in cash and cash equivalents for the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to fi nancing activities), shareholders’ equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange rate differences; (ii) changes in net borrowings for the period by adding/deducting cash flows relating to shareholders’ equity and the effect of changes in consolidation and of exchange rate differences.

Net borrowings

Net borrowings is calculated as total finance debt less cash, cash equivalents, financial assets measured at fair value throu gh profit or loss and financing receivables held for non -operating purposes. Financial activities are qualified as “not related to operations” when these are not strictly related to the business operations.

Proforma adjusted EBIT Is the measure adding the operating margin of the equity accounted entities to the adjusted EBIT, introduced by the managemen t to reflect the increasing contribution from the JV/associates also in connection with the Eni satellite model. Alternative performance indicators (Non -GAAP measures)

20 Reconciliation tables of Non -GAAP results to the most comparable measures of financial performance determined in accordance to GAAPs

(€ million ) Third Quarter 2026

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 2,440 (703) 389 864 (45) (448) (20) 2,477 (864) 249 (615) 1,862 Exclusion of inventory holding (gains) losses (154) (300) 71 (383) (383) Exclusion of special items:

environmental charges 7 226 159 392 392 impairment losses (impairment reversals), net 28 1 28 63 5 125 125 net gains on disposal of assets (9) (2) (11) (11) risk provisions 33 (1) (4) 28 28 provision for redundancy incentives 29 10 55 1 56 87 238 (1) (1) 237 commodity derivatives 34 1,305 28 (721) 182 828 721 (722) (1) 827 exchange rate differences and derivatives (7) 24 (1) 1 17 17 other 156 (198) 1 13 21 (5) (12) (13) (13) (25) Special items of operating profit (loss) 264 1,142 118 (707) 546 242 1,605 707 (722) (15) 1,590 Adjusted operating profit (loss) of subsidiaries (a) 2,704 439 353 157 201 (206) 51 3,699 (157) (473) (630) 3,069 main JV/Associates adjusted EBIT (b) 1,927 6 57 34 271 2,295 (34) (34) 2,261 Proforma adjusted EBIT (c)=(a)+(b) 4,631 445 410 191 472 (206) 51 5,994 (191) (473) (664) 5,330 Finance expenses and dividends of subsidiaries (d) 21 (4) 3 (3) (174) (157) (3) 2 (1) (158) Finance expenses and dividends of main JV/associates (e) (196) 3 (3) (21) 2 (215) 21 21 (194) Income taxes of main JV/associates (f) (1,233) (3) (8) (48) (1,292) 8 8(1,284) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 498 6 54 5 225 788 (5) (5) 783 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 3,223 441 407 165 423 (380) 51 4,330 (165) (471) (636) 3,694 Income taxes (i) (1,123) (173) (111) (45) (110) 180 (17) (1,399) 45 (7) 38 (1,361) Tax rate (%) 32.3 36.8 Adjusted net profit (loss) (j)=(h)+(i) 2,100 268 296 120 313 (200) 34 2,931 (120) (478) (598) 2,333

of which:

- Adjusted net profit (loss) of non-controlling interest 130 267 397

- Adjusted net profit (loss) attributable to Eni's shareholders 2,801 (865) 1,936 Reported net profit (loss) attributable to Eni's shareholders 3,205 (1,757) 1,448 Exclusion of inventory holding (gains) losses (235) (235) Exclusion of special items (169) 892 723 Adjusted net profit (loss) attributable to Eni's shareholders 2,801 (865) 1,936Impact of unrealized

intragroup profit

elimination

GROUPDiscontinued operations

exclusion

CONTINUING

OPERATIONSExploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Plenitude

Refining, Chemicals

and Sites in

transformation

Corporate and other

activities

(€ million)

Third Quarter 2025

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 1,670 227 219 23 (291) (418) (86) 1,344 (23) (489) (512) 832 Exclusion of inventory holding (gains) losses (8) 69 56 117 117 Exclusion of special items:

environmental charges (expense recovered from third-parties) 2 11 19 32 32 impairment losses (impairment reversals), net 109 9 59 4 181 181 risk provisions 38 170 208 208 provision for redundancy incentives 3 1 1 1 3 10 19 (1) (1) 18 commodity derivatives 16 (32) 1 66 (1) 50 (66) 64 (2) 48 exchange rate differences and derivatives (32) 17 (1) (1) (17) (17) other (6) 129 8 2 7 (1) 139 (2) (2) 137 Special items of operating profit (loss) 130 115 30 69 86 182 612 (69) 64 (5) 607 Adjusted operating profit (loss) of subsidiaries (a) 1,800 342 241 92 (136) (236) (30) 2,073 (92) (425) (517) 1,556 main JV/Associates adjusted EBIT (b) 838 4 (8) 6 83 923 (6) (6) 917 Proforma adjusted EBIT (c)=(a)+(b) 2,638 346 233 98 (53) (236) (30) 2,996 (98) (425) (523) 2,473 Finance expenses and dividends of subsidiaries (d) (84) (4) (6) (6) 3 (75) (172) 6 4 10 (162) Finance expenses and dividends of main JV/associates (e) (137) 3 (2) (9) (19) (164) 9 9 (155) Income taxes of main JV/associates (f) (402) 3 1 11 (387) (1) (1) (388) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 299 10 (10) (2) 75 372 2 2 374 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 2,015 348 225 84 (58) (311) (30) 2,273 (84) (421) (505) 1,768 Income taxes (i) (840) (132) (62) (31) (16) 114 9 (958) 31 (5) 26 (932) Tax rate (%) 42.1 52.7 Adjusted net profit (loss) (j)=(h)+(i) 1,175 216 163 53 (74) (197) (21) 1,315 (53) (426) (479) 836

of which:

- Adjusted net profit (loss) of non-controlling interest 68 (48) 20

- Adjusted net profit (loss) attributable to Eni's shareholders 1,247 (431) 816 Reported net profit (loss) attributable to Eni's shareholders 803 (448) 355 Exclusion of inventory holding (gains) losses 87 87 Exclusion of special items 357 17 374 Adjusted net profit (loss) attributable to Eni's shareholders 1,247 (431) 816Impact of unrealized

intragroup profit

elimination

GROUPDiscontinued operations

exclusion

CONTINUING

OPERATIONSExploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Plenitude

Refining, Chemicals

and Sites in

transformation

Corporate and other

activities

21

(€ million)

Nine months 2026

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 5,942 (322) 764 1,690 (347) (1,063) (116) 6,548 (1,690) (1,114) (2,804) 3,744 Exclusion of inventory holding (gains) losses (189) (855) 76 (968) (968) Exclusion of special items:

environmental charges 15 55 316 149 535 535 impairment losses (impairment reversals), net 1,231 1 39 250 78 1,599 1,599 net gains on disposal of assets (14) (2) (16) (16) risk provisions 44 1 2 47 47 provision for redundancy incentives 38 11 56 3 68 94 270 (3) (3) 267 commodity derivatives 23 1,619 42 (1,144) 360 900 1,144 (1,147) (3) 897 exchange rate differences and derivatives 20 176 (3) 17 210 210 other 664 (233) (9) 7 71 8 508 (7) (7) 501 Special items of operating profit (loss) 2,021 1,574 181 (1,134) 1,080 331 4,053 1,134 (1,147) (13) 4,040 Adjusted operating profit (loss) of subsidiaries (a) 7,963 1,252 756 556 (122) (732) (40) 9,633 (556) (2,261) (2,817) 6,816 main JV/Associates adjusted EBIT (b) 4,794 23 87 74 294 5,272 (74) (74) 5,198 Proforma adjusted EBIT (c)=(a)+(b) 12,757 1,275 843 630 172 (732) (40) 14,905 (630) (2,261) (2,891) 12,014 Finance expenses and dividends of subsidiaries (d) (162) (13) (14) 1 2 (495) (681) (1) (10) (11) (692) Finance expenses and dividends of main JV/associates (e) (645) 9 (8) (60) (29) (733) 60 60 (673) Income taxes of main JV/associates (f) (2,860) (9) (13) (44) (2,926) 13 13 (2,913) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 1,289 23 79 1 221 1,613 (1) (1) 1,612 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 9,090 1,262 821 558 101 (1,227) (40) 10,565 (558) (2,271) (2,829) 7,736 Income taxes (i) (3,261) (479) (224) (174) (104) 404 13 (3,825) 174 (18) 156 (3,669) Tax rate (%) 36.2 47.4 Adjusted net profit (loss) (j)=(h)+(i) 5,829 783 597 384 (3) (823) (27) 6,740 (384) (2,289) (2,673) 4,067

of which:

- Adjusted net profit (loss) of non-controlling interest 304 (359) (55)

- Adjusted net profit (loss) attributable to Eni's shareholders 6,436 (2,314) 4,122 Reported net profit (loss) attributable to Eni's shareholders 7,595 (3,124) 4,471 Exclusion of inventory holding (gains) losses (633) (633) Exclusion of special items (526) 810 284 Adjusted net profit (loss) attributable to Eni's shareholders 6,436 (2,314) 4,122Exploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Refining, Chemicals

and Sites in

transformation

Corporate and other

activities

CONTINUING

OPERATIONSGROUPImpact of unrealized

intragroup profit

eliminationPlenitudeDiscontinued operations

exclusion

(€ million)

Nine months 2025

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 5,116 1,585 393 87 (1,593) (957) 203 4,834 (87) (2,864) (2,951) 1,883 Exclusion of inventory holding (gains) losses 34 496 (55) 475 475 Exclusion of special items:

environmental charges (expense recovered from third-parties) 33 136 55 224 224 impairment losses (impairment reversals), net 578 14 218 12 822 822 net gains on disposal of assets (3) (3) (6) (6) risk provisions 38 16 171 225 225 provision for redundancy incentives 12 1 2 1 10 27 53 (1) (1) 52 commodity derivatives (3) (374) 2 358 14 (3) (358) 354 (4) (7) exchange rate differences and derivatives (17) (280) (1) 2 (296) (296) other (32) 251 12 12 12 (21) 234 (12) (12) 222 Special items of operating profit (loss) 573 (402) 62 371 405 244 1,253 (371) 354 (17) 1,236 Adjusted operating profit (loss) of subsidiaries (a) 5,689 1,183 489 458 (692) (713) 148 6,562 (458) (2,510) (2,968) 3,594 main JV/Associates adjusted EBIT (b) 2,679 23 (32) 14 112 2,796 (14) (14) 2,782 Proforma adjusted EBIT (c)=(a)+(b) 8,368 1,206 457 472 (580) (713) 148 9,358 (472) (2,510) (2,982) 6,376 Finance expenses and dividends of subsidiaries (d) (55) (13) (14) (19) (2) (91) (194) 19 75 94 (100) Finance expenses and dividends of main JV/associates (e) (459) 8 (5) (33) (60) (549) 33 33 (516) Income taxes of main JV/associates (f) (1,426) (1) 34 (1,393) (1,393) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 794 30 (37) (19) 86 854 19 19 873 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 6,428 1,200 438 420 (608) (804) 148 7,222 (420) (2,435) (2,855) 4,367 Income taxes (i) (2,881) (442) (134) (144) 27 336 (41) (3,279) 144 (12) 132 (3,147) Tax rate (%) 45.4 72.1 Adjusted net profit (loss) (j)=(h)+(i) 3,547 758 304 276 (581) (468) 107 3,943 (276) (2,447) (2,723) 1,220

of which:

- Adjusted net profit (loss) of non-controlling interest 150 (235) (85)

- Adjusted net profit (loss) attributable to Eni's shareholders 3,793 (2,488) 1,305 Reported net profit (loss) attributable to Eni's shareholders 2,518 (2,569) (51) Exclusion of inventory holding (gains) losses 333 333 Exclusion of special items 942 81 1,023 Adjusted net profit (loss) attributable to Eni's shareholders 3,793 (2,488) 1,305Exploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Refining, Chemicals

and Sites in

transformation

Corporate and other

activities

CONTINUING

OPERATIONSGROUPImpact of unrealized

intragroup profit

eliminationPlenitudeDiscontinued operations

exclusion

22 (€ million ) Second Quarter 2026

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 1,651 523 192 52 (129) (313) (78) 1,898 (52) (669) (721) 1,177 Exclusion of inventory holding (gains) losses 70 (151) (70) (151) (151) Exclusion of special items:

environmental charges 16 31 66 (10) 103 103 impairment losses (impairment reversals), net 1,104 6 108 69 1,287 1,287 risk provisions 11 1 1 6 19 19 provision for redundancy incentives 6 1 6 3 16 (1) (1) 15 commodity derivatives (179) (95) (23) 159 15 (123) (159) 156 (3) (126) exchange rate differences and derivatives (4) 65 (2) 11 70 70 other 371 2 (8) (13) 30 15 397 13 13 410 Special items of operating profit (loss) 1,325 (28) 5 147 237 83 1,769 (147) 156 9 1,778 Adjusted operating profit (loss) of subsidiaries (a) 2,976 495 267 199 (43) (230) (148) 3,516 (199) (513) (712) 2,804 main JV/Associates adjusted EBIT (b) 1,793 8 28 27 3 1,859 (27) (27) 1,832 Proforma adjusted EBIT (c)=(a)+(b) 4,769 503 295 226 (40) (230) (148) 5,375 (226) (513) (739) 4,636 Finance expenses and dividends of subsidiaries (d) (99) (5) (6) (11) 2 (144) (263) 11 (3) 8 (255) Finance expenses and dividends of main JV/associates (e) (235) 2 (2) (20) (14) (269) 20 20 (249) Income taxes of main JV/associates (f) (966) (3) (6) (11) (986) 6 6 (980) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 592 7 26 1 (22) 604 (1) (1) 603 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 3,469 497 287 189 (63) (374) (148) 3,857 (189) (516) (705) 3,152 Income taxes (i) (1,220) (186) (79) (59) (24) 101 44 (1,423) 59 (5) 54 (1,369) Tax rate (%) 36.9 Adjusted net profit (loss) (j)=(h)+(i) 2,249 311 208 130 (87) (273) (104) 2,434 (130) (521) (651) 1,783

of which:

- Adjusted net profit (loss) of non-controlling interest 101 (196) (95)

- Adjusted net profit (loss) attributable to Eni's shareholders 2,333 (455) 1,878 Reported net profit (loss) attributable to Eni's shareholders 3,319 (492) 2,827 Exclusion of inventory holding (gains) losses (120) (120) Exclusion of special items (866) 37 (829) Adjusted net profit (loss) attributable to Eni's shareholders 2,333 (455) 1,878

CONTINUING

OPERATIONSGROUPImpact of unrealized

intragroup profit

eliminationPlenitudeDiscontinued operations

exclusionExploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Refining, Chemicals and Sites in transformation Corporate and other

activities

Breakdown of special items Q2 2026 (€ million) 2026 2025 2026 2025 103 Environmental charges 392 32 535 224 1,287 Impairment losses (impairment reversals), net 125 181 1,599 822 Net gains on disposal of assets (11) (16) (6) 19 Risk provisions 28 208 47 225 16 Provisions for redundancy incentives 238 19 270 53 (123) Commodity derivatives 828 50 900 (3) 70 Exchange rate differences and derivatives 17 (17) 210 (296) 397 Other (12) 139 508 234 1,769 Special items of operating profit (loss) 1,605 612 4,053 1,253 (75) Net finance (income) expense (24) 11 (225) 280

of which:

(70) - exchange rate differences and derivatives reclassified to operating profit (loss) (17) 17 (210) 296 (2,384)Net income (expense) from investments, including net gains on business combinations and other items(1,473) (112) (3,909) (266) (146) Income taxes (401) (145) (652) (285) (836) Total special items of net profit (loss) (293) 366 (733) 982

attributable to:

(866) - Eni's shareholders (169) 357 (526) 942 30 - Non-controlling interest (124) 9 (207) 40Q3 Nine months

23 Reconciliation of Group proforma adjusted EBIT Q2 2026(€ million) 2026 2025 % Ch. 2026 2025 % Ch.

2,976 E&P adjusted Ebit of consolidated subsidiaries 2,704 1,800 50 7,963 5,689 40 1,793 main JV/Associates adjusted Ebit 1,927 838 .. 4,794 2,679 79 4,769 E&P proforma adjusted Ebit 4,631 2,638 76 12,757 8,368 52 495 GGP and Power adjusted Ebit of consolidated subsidiaries 439 342 28 1,252 1,183 6 8 main JV/Associates adjusted Ebit 6 4 50 23 23 -

503 GGP and Power proforma adjusted Ebit 445 346 29 1,275 1,206 6 466 Transition Businesses adjusted Ebit of consolidated subsidiaries 510 333 53 1,312 947 39 55 main JV/Associates adjusted Ebit 91 (2) .. 161 (18) ..

521 Transition Businesses proforma adjusted Ebit 601 331 82 1,473 929 59 (43) Refining, Chemicals and Sites in transformation adjusted Ebit of consolidated subsidiaries 201 (136) .. (122) (692) 82 3 main JV/Associates adjusted Ebit 271 83 .. 294 112 ..

(40) Refining, Chemicals and Sites in transformation proforma adjusted Ebit 472 (53) .. 172 (580) ..

(230) Other segments adjusted Ebit (206) (236) 13 (732) (713) (3) (148) Impact of unrealized intragroup profit elimination 51 (30) .. (40) 148 ..

5,375 Group proforma adjusted Ebit ⁽ᵃ⁾ 5,994 2,996 .. 14,905 9,358 59Q3 Nine months (a) Main JV/Associates are Vår Energi, Azule Energy, Ithaca, Searah, Mozambique Rovuma Venture, Neptune Algeria, SeaCorridor, Adnoc R&GT and St. Bernard Renewables Llc.

Profit and loss reconciliation GAAP vs Non -GAAP

2026

Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

(€ million)Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

2,477 (383) 1,588 17 3,699 Operating profit 6,548 (968) 3,843 210 9,633 (284) (7) (17) (308) Finance income (expense) (663) (15) (210) (888) 2,412 (1,473) 939 Income (expense) from investments 5,729 (3,909) 1,820 (1,113) 115 (401) (1,399) Income taxes (3,467) 294 (652) (3,825) 3,492 (268) (293) 2,931 Net profit 8,147 (674) (733) 6,740 287 (33) (124) 130 - Non-controlling interest 552 (41) (207) 304 3,205 (235) (169) 2,801 Net profit attributable to Eni's shareholders 7,595 (633) (526) 6,436Nine months Third Quarter

2025

Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

(€ million)Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

1,344 117 629 (17) 2,073 Operating profit 4,834 475 1,549 (296) 6,562 (258) (6) 17 (247) Finance income (expense) (668) (16) 296 (388) 559 (112) 447 Income (expense) from investments 1,314 (266) 1,048 (780) (33) (145) (958) Income taxes (2,859) (135) (285) (3,279) 865 84 366 1,315 Net profit 2,621 340 982 3,943 62 (3) 9 68 - Non-controlling interest 103 7 40 150 803 87 357 1,247Net profit attributable to Eni's shareholders2,518 333 942 3,793Nine months Third Quarter

2026

(€ million)Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

Operating profit 1,898 (151) 1,699 70 3,516 Finance income (expense) (191) (5) (70) (266) Income (expense) from investments 2,991 (2,384) 607 Income taxes (1,322) 45 (146) (1,423) Net profit 3,376 (106) (836) 2,434

- Non-controlling interest 57 14 30 101 Net profit attributable to Eni's shareholders 3,319 (120) (866) 2,333Q2

24 Sales from operations Q2 2026(€ million)2026 2025 % Ch. 2026 2025 % Ch.

16,579 Exploration & Production 17,639 13,329 32 47,956 38,271 25 4,058 Global Gas & LNG Portfolio and Power 6,290 3,503 80 15,723 12,537 25 6,917 Enilive 7,726 5,206 48 19,400 14,742 32 6,441 Refining, Chemicals and Sites in transformation 7,050 4,545 55 17,603 14,010 26 476 Corporate and other activities 499 487 2 1,431 1,466 (2) (12,157) Consolidation adjustments (13,559) (8,670) (56) (34,412) (26,874) (28) 22,314 25,645 18,400 39 67,701 54,152 25Q3 Nine months

Operating expenses

Q2 2026(€ million) 2026 2025 % Ch. 2026 2025 % Ch.

17,806 Purchases, services and other 20,674 15,362 35 54,603 45,416 20 51 Impairment losses (impairment reversals) of trade and other receivables, net 40 (24) .. 141 49 ..

759 Payroll and related costs 889 676 32 2,471 2,230 11 15 of which: provision for redundancy incentives and other 237 18 .. 267 52 ..

18,616 21,603 16,014 35 57,215 47,695 20Q3 Nine months

DD&A, impairments, reversals and write -off Q2 2026(€ million)2026 2025 var % 2026 2025 % Ch.

1,514 Exploration & Production 1,363 1,521 (10) 4,310 4,586 (6) 42 Global Gas & LNG Portfolio and Power 47 64 (27) 137 196 (30) 76 Enilive 74 79 (6) 223 224 -

38 Refining, Chemicals and Sites in transformation 38 39 (3) 111 114 (3) 40 Corporate and other activities 41 38 8 120 115 4 (8) Impact of unrealized intragroup profit elimination (9) (10) 10 (26) (26) -

1,702 Total depreciation, depletion and amortization 1,554 1,731 (10) 4,875 5,209 (6) 1,287Impairment losses (impairment reversals) of tangible and intangible and right of use assets, net125 181 (31) 1,599 822 95 2,989 Depreciation, depletion, amortization, impairments and reversals 1,679 1,912 (12) 6,474 6,031 7 113 Write-off of tangible and intangible assets 9 11 (18) 128 (3) ..

3,102 1,688 1,923 (12) 6,602 6,028 10Nine months Q3

Income (expense) from investments

(€ million)

Nine months 2026Exploration & ProductionGlobal Gas &

LNG Portfolio

and PowerEniliveRefining,

Chemicals and

Sites in

transformationCorporate and

other activitiesGroup

Share of profit (loss) from equity-accounted investments 1,574 23 109 283 (40) 1,949 Dividends 148 6 1 21 176 Net gains (losses) on disposals 18 18 Other income (expense), net 2,088 2 (3) 2,087 3,810 25 115 284 (4) 4,230

Analysis of Profit and Loss account items – continuing operations

25 Gearing is a measure used by management to assess the Company’s level of indebtedness. It is calculated as the ratio between net borrowings and capital employed net and measures how much capital employed net is financed recurring to third -party funding. Management periodically reviews gearing in order to assess the soundness and efficiency of the Group balance sheet in terms of optimal mix between net borrowings and net capital employed , and to carry out benchmark analysis with industry standards .

(€ million)Dec. 31, 2025 Sept. 30, 2026 Change Total debt 28,464 34,390 5,926

- Short-term debt 8,363 8,362 (1)

- Long-term debt 20,101 26,028 5,927 Cash and cash equivalents (8,100) (11,767) (3,667) Financial assets measured at fair value through profit or loss (6,991) (8,371) (1,380) Financing receivables held for non-operating purposes (3,845) (7,550) (3,705) Net borrowings before lease liabilities ex IFRS 16 9,528 6,702 (2,826) Lease Liabilities 5,700 5,614 (86) Net borrowings after lease liabilities ex IFRS 16 15,228 12,316 (2,912) Shareholders' equity including non-controlling interest 52,787 57,640 4,853 Gearing before lease liability ex IFRS 16 0.15 0.10 Gearing after lease liability ex IFRS 16 0.22 0.18

The increase in financing receivables held for non -operating purposes was mainly due to the recognition of former intercompany financing receivables owed by Plenitude to Eni for around €1.7 bln, which have been netted against the Group‘s gross finance debt in determining net borrowing s, because a reimbursement plan has been agreed and the Group is only exposed to a credit risk . Other increases were due to higher margin deposits in connection with Group commodity trading activities and other cash requirements.

Gearing and net borrowings

26

BALANCE SHEET

(€ million)

Sept. 30, 2026 Dec. 31, 2025

ASSETS

Current assets

Cash and cash equivalents 11,767 8,100 Financial assets measured at fair value through profit or loss 8,371 6,991 Other financial assets 2,710 3,710 Trade and other receivables 15,197 12,436 Inventories 8,011 5,143 Income tax assets 942 539 Other assets 5,522 3,943

52,520 40,862

Non-current assets

Property, plant and equipment 49,997 50,536 Right of use assets 5,100 5,184 Intangible assets 1,525 6,022 Inventory - compulsory stock 1,787 1,187 Equity-accounted investments 24,362 13,155 Other investments 1,429 1,329 Other financial assets 5,860 1,109 Deferred tax assets 6,875 6,716 Income tax assets 139 125 Other assets 1,490 2,839

98,564 88,202

Assets held for sale 2,994 8,005

TOTAL ASSETS 154,078 137,069

LIABILITIES AND SHAREHOLDERS' EQUITY

Current liabilities

Short-term debt 5,054 4,929 Current portion of long-term debt 3,308 3,434 Current portion of long-term lease liabilities 1,131 1,263 Trade and other payables 22,759 20,261 Income taxes payable 388 343 Other liabilities 11,954 4,039

44,594 34,269

Non-current liabilities

Long-term debt 25,922 20,139 Long-term lease liabilities 4,483 4,437 Provisions for contingencies 14,131 14,580 Provisions for employee benefits 719 596 Deferred tax liabilities 4,313 4,805 Income taxes payable 24 40 Other liabilities 1,122 3,390

50,714 47,987

Liabilities directly associated with assets held for sale 1,130 2,026

TOTAL LIABILITIES 96,438 84,282

Share capital 4,005 4,005 Retained earnings 31,995 33,209 Cumulative currency translation differences 3,616 1,936 Other reserves and equity instruments 10,274 8,964 Treasury shares (2,977) (2,782) Net profit (loss) 7,595 2,608 Total Eni shareholders' equity 54,508 47,940 Non-controlling interest 3,132 4,847

TOTAL SHAREHOLDERS' EQUITY 57,640 52,787

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 154,078 137,069

Consolidated financial statements

27 GROUP PROFIT AND LOSS ACCOUNT

Q2 2026 (€ million) 2026 2025 2026 2025

CONTINUING OPERATIONS

22,314 Sales from operations 25,645 18,400 67,701 54,152 354 Other income and revenues 390 284 1,063 933 22,668 Total revenues 26,035 18,684 68,764 55,085 (17,806) Purchases, services and other (20,674) (15,362) (54,603) (45,416) (51) Impairment reversals (impairment losses) of trade and other receivables, net (40) 24 (141) (49) (759) Payroll and related costs (889) (676) (2,471) (2,230) 227 Other operating (expense) income (882) 85 (1,203) 521 (1,702) Depreciation, Depletion and Amortization (1,554) (1,731) (4,875) (5,209) (1,287) Impairment reversals (impairment losses) of tangible, intangible and right of use assets, net (125) (181) (1,599) (822) (113) Write-off of tangible and intangible assets (9) (11) (128) 3

1,177 OPERATING PROFIT (LOSS) 1,862 832 3,744 1,883

1,735 Finance income 1,482 836 4,699 6,195 (2,066) Finance expense (1,778) (1,135) (5,485) (6,864) 82 Net finance income (expense) from financial assets measured at fair value through profit or loss 2 71 97 182 61 Derivative financial instruments 9 (18) 18 (88)

(188) FINANCE INCOME (EXPENSE) (285) (246) (671) (575)

889 Share of profit (loss) of equity-accounted investments 777 359 1,949 1,028 2,106 Other gain (loss) from investments 135 195 2,281 301

2,995 INCOME (EXPENSE) FROM INVESTMENTS 912 554 4,230 1,329

3,984 PROFIT (LOSS) BEFORE INCOME TAXES 2,489 1,140 7,303 2,637

(1,312) Income taxes (869) (773) (2,986) (2,829) 2,672 Net profit (loss) - continuing operations 1,620 367 4,317 (192)

DISCONTINUED OPERATIONS

704 Net profit (loss) - discontinued operations 1,872 498 3,830 2,813

TOTAL GROUP

3,376 Net profit (loss) 3,492 865 8,147 2,621

attributable to:

3,319 - Eni's shareholders 3,205 803 7,595 2,518 2,827 - continuing operations 1,448 355 4,471 (51) 492 - discontinued operations 1,757 448 3,124 2,569 57 - Non-controlling interest 287 62 552 103 (155) - continuing operations 172 12 (154) (141) 212 - discontinued operations 115 50 706 244 Net profit (loss) per share attributable to Eni's shareholders (€ per share) 1.11 - basic 1.09 0.25 2.53 0.77 1.09 - diluted 1.07 0.24 2.48 0.76 Net profit (loss) per share - continuing operations attributable to Eni's shareholders (€ per share) 0.94 - basic 0.48 0.10 1.46 (0.07) 0.92 - diluted 0.47 0.10 1.44 (0.07) Weighted average number of shares outstanding (million) 2,934.6 - basic 2,886.5 3,011.2 2,922.0 3,041.0 3,000.2 - diluted 2,952.2 3,073.8 2,987.6 3,103.6 Q3 Nine months

28 COMPREHENSIVE INCOME (LOSS)

(€ million) 2026 2025 2026 2025 Net profit (loss) 3,492 865 8,147 2,621 Items that are not reclassified to profit or loss in later periods (12) (2) 5 Remeasurements of defined benefit plans 1 1 Share of other comprehensive income on equity accounted entities 1 Change in the fair value of interests with effects on other comprehensive income (13) (4) 5

Taxation

Items that may be reclassified to profit in later periods (1,027) 38 186 (5,481) Currency translation differences 158 (90) 1,758 (6,153) Change in the fair value of cash flow hedging derivatives (1,730) 132 (2,212) 864 Share of other comprehensive income on equity-accounted entities (1) 31 (57) 55 Taxation 546 (35) 697 (247) Total other items of comprehensive income (loss) (1,039) 38 184 (5,476) Total comprehensive income (loss) 2,453 903 8,331 (2,855)

attributable to:

- Eni's shareholders 2,147 845 7,675 (2,704)

- continuing operations 368 403 4,472 (5,197)

- discontinued operations 1,779 442 3,203 2,493

- Non-controlling interest 306 58 656 (151)

- continuing operations 182 7 (84) (388)

- discontinued operations 124 51 740 237Nine months Q3

29 CHANGES IN SHAREHOLDERS’ EQUITY

(€ million)

Shareholders' equity at January 1, 2025 55,648 Total comprehensive income (loss) (2,855) Dividends paid to Eni's shareholders (2,307) Dividends distributed by consolidated subsidiaries (63) Net purchase of treasury shares (1,217) Issue of hybrid bonds 1,500 Repurchase of perpetual hybrid bonds (1,251) Coupon of perpetual subordinated bonds (105) Taxes on disposal of Enilive and Plenitude (26) Taxes on hybrid bond coupon and costs 9 Plenitude transaction - disposal to EIP 209 Put option on Plenitude (139) Enilive transaction - disposal to KKR 3,569 Other changes (6) Total changes (2,682) Shareholders' equity at September 30, 2025 52,966

attributable to:

- Eni's shareholders 49,243

- Non-controlling interest 3,723 Shareholders' equity at January 1, 2026 52,787 Total comprehensive income (loss) 8,331 Dividends paid to Eni's shareholders (2,333) Dividends distributed by consolidated subsidiaries (156) Net purchase of treasury shares (1,995) Issue of hybrid bonds 1,000 Coupon of perpetual subordinated bonds and Enimarine (214) Taxes on hybrid bond coupon and costs 55 Upstream infrastructure transaction 1,753 Plenitude deconsolidation (2,101) Put option liability elimination 541 Other changes (28) Total changes 4,853 Shareholders' equity at September 30, 2026 57,640

attributable to:

- Eni's shareholders 54,508

- Non-controlling interest 3,132

30 GROUP CASH FLOW STATEMENT

Q2 2026(€ million)2026 2025 2026 2025 2,672 Net profit (loss) - continuing operations 1,620 367 4,317 (192) 704 Net profit (loss) - discontinued operations 1,872 498 3,830 2,813 3,376 Net profit (loss) 3,492 865 8,147 2,621 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

1,702 Depreciation, depletion and amortization 1,554 1,842 4,952 5,538 1,287 Impairment losses (impairment reversals) of tangible, intangible and right of use, net 125 181 1,599 822 114 Write-off of tangible and intangible assets 9 11 129 (2) (882) Share of (profit) loss of equity-accounted investments (775) (359) (1,933) (1,008) Gains on disposal of assets, net (45) (32) (50) (38) (17) Dividend income (116) (87) (176) (187) (121) Interest income (135) (121) (358) (323) 355 Interest expense 412 319 1,041 926 1,322 Income taxes 1,113 780 3,467 2,859 (2,064) Other changes (1,383) (107) (3,460) (232) 269 Cash flow from changes in working capital 178 435 (1,338) 627 (1,200) - inventories (1,734) (405) (3,463) (4) 2,660 - trade receivables (2,079) 1,166 (3,312) 3,821 (1,442) - trade payables 2,955 (609) 4,749 (3,046) (70) - provisions for contingencies 36 (109) (387) (548) 321 - other assets and liabilities 1,000 392 1,075 404 (17) Net change in the provisions for employee benefits 118 (63) 137 (55) 578 Dividends received 1,112 417 1,980 1,296 49 Interest received 51 51 138 168 (485) Interest paid (203) (242) (1,020) (990) (1,196) Income taxes paid, net of tax receivables received (1,148) (812) (3,199) (3,042) 4,270 Net cash provided by operating activities 4,359 3,078 10,056 8,980 (2,981) Cash flow from investing activities (1,819) (2,494) (6,893) (7,029) (2,114) - tangible assets (1,645) (2,061) (6,123) (5,768) (94) - intangible assets (116) (117) (279) (375) (499) - consolidated subsidiaries and businesses net of cash and cash equivalent acquired (499) (236) - investments (134) (229) (435) (580) (8) - securities and financing receivables held for operating purposes (25) (8) (58) (43) (30) - change in payables in relation to investing activities 101 (79) 501 (263) 164 Cash flow from disposals 241 1,430 491 1,750 2 - tangible assets 380 1,351 392 1,417

- intangible assets 1 3 1 3 38 - consolidated subsidiaries and businesses net of cash and cash equivalent disposed of (201) (163) 27 - investments 42 52 69 70 42 - securities and financing receivables held for operating purposes 12 7 55 23 55 - change in receivables in relation to disposals 7 17 137 237 9 Net change in receivables and securities not held for operating purposes (1,895) (459) (2,725) (649) (2,808) Net cash used in investing activities (3,473) (1,523) (9,127) (5,928)Nine months Q3

31 GROUP CASH FLOW STATEMENT (continued)

Q2 2026(€ million) 2026 2025 2026 2025 2,821 Increase in long-term debt 3,000 1,514 8,116 5,235 (1,177) Payment of long-term debt (250) (2,908) (3,156) (7,711) (327) Payment of lease liabilities (272) (303) (941) (978) (1,540) Increase (decrease) in short-term financial debt (1,081) 1,297 (831) 1,055 (786) Dividends paid to Eni's shareholders (781) (781) (2,333) (2,305) (106) Dividends paid to non-controlling interests (24) (30) (150) (63) Net capital issuance from non-controlling interest 1,080 1,080 709 Disposal (acquisition) of additional interests in consolidated subsidiaries 3,069 (560) Net purchase of treasury shares (1,115) (560) (1,964) (1,226) Issue (repayment) of perpetual hybrid bonds (1) 988 230 Other contributions 1,747 1,747 9 (156) Interest payment of perpetual hybrid bond (30) (214) (105) (1,831) Net cash used in financing activities 2,274 (1,772) 2,342 (2,081) 8 Effect of exchange rate changes on cash and cash equivalents and other changes 57 2 80 (202) (361) Net increase (decrease) in cash and cash equivalents 3,217 (215) 3,351 769 8,916 Cash and cash equivalents - beginning of the period 8,555 9,167 8,421 8,183 8,555 Cash and cash equivalents - end of the period 11,772 8,952 11,772 8,952Nine months Q3

Capital expenditure

Q2 2026 (€ million) 2026 2025 var % 2026 2025 % Ch.

1,526 Exploration & Production 1,091 1,535 (29) 4,232 4,310 (2) 97 of which: - exploration 31 63 (51) 296 229 29 1,418 - oil & gas development 1,046 1,345 (22) 3,906 3,931 (1) 14 Global Gas & LNG Portfolio and Power 7 14 (50) 29 51 (43) 2 - Global Gas & LNG Portfolio 1 2 (50) 3 11 (73) 12 - Power 6 12 (50) 26 40 (35) 174 Transition Businesses 245 288 (15) 583 729 (20) 56 - Enilive 103 98 5 222 199 12 118 - Plenitude 142 190 (25) 361 530 (32) 282 Refining, Chemicals and Sites in transformation 39 142 (73) 479 430 11 247 - Refining 9 97 (91) 393 303 30 27 - Chemicals 22 45 (51) 66 127 (48) 8 - Sites in transformation 8 20 44 Corporate and other activities 34 51 (33) 112 304 (63) 1 Impact of unrealized intragroup profit elimination (1) (13) (12) (34) 2,041 Capital expenditure ⁽ᵃ⁾ 1,415 2,017 (30) 5,423 5,790 (6)Q3 Nine months (a)Expenditures topurchase plant and equipment from suppliers whose payment terms matched classification asfinancing payables, have been recognized among other changes ofthereclassified cash flow statements and arenotreported inthetable above (€436 mln and €270 mln inthethird quarter 2026 and 2025, respectively, €997 mln and €1,023 mln inthenine months 2026 and thenine months 2025, respectively and €289 mln inthe second quarter 2026).

In the nine months ’26, capital expenditure amounted to € 5,423 mln (€ 5,790 mln in the nine months ’25) decreasing by 6% y-

o-y, in particular:

• in the Exploration & Production, capital expenditure (€ 4,232 mln) was mainly related to oil&gas development activities in particular in Libya, Egypt, Congo, Italy, the United Arab Emirates, Indonesia, Algeria , Kazakhstan, Nigeria, Mexico and Iraq ;

• in the Transition Businesses segment, Plenitude’s capital expenditure (€ 361 mln) related to development activities in the renewable business, acquisition of new customers, as well as development of electric vehicles network infrastructure, while Enilive capital expenditure (€ 222 mln) mainly related to biorefining projects (EcofiningTM and Steam Reformer in Venice and Gela catalysts) and marketing activity in Italy and in the rest of Europe;

• in the Refining, Chemicals and Sites in transformation segment mainly related to refining in Italy (€ 393 mln) specifically to the reconversion of Livorno in biorefinery, maintenance and stay -in-business, as well as to the chemical business (€ 66 mln) and regarded the circular economy and asset integrity;

• in the Corporate and other activities mainly related to the CCUS and agri -business projects (€ 21 mln).

32 Exploration & Productio n

PRODUCTION OF OIL AND NATURAL GAS BY REGION

Q2 2026 2026 2025 2026 2025

57 Italy (kboe/d) 57 62 58 66 300 Rest of Europe 293 287 305 256 529 North Africa 536 529 532 524 404 Sub-Saharan Africa 403 340 401 333 342 Asia 390 389 359 377 157 Americas 150 143 150 130

- Australia and Oceania - 6 - 5 1,789 Production of oil and natural gas ⁽ᵃ⁾⁽ᵇ⁾⁽ᶜ⁾⁽ᵈ⁾ 1,829 1,756 1,805 1,691 566 - of which Joint Ventures and associates 648 493 580 452 145 Production sold ⁽ᵃ⁾ (mmboe) 146 143 432 413

PRODUCTION OF LIQUIDS BY REGION

Q2 2026 2026 2025 2026 2025

23 Italy (kbbl/d) 24 25 24 26 185 Rest of Europe 181 193 190 161 176 North Africa 178 175 175 173 185 Sub-Saharan Africa 202 193 193 190 174 Asia 177 197 182 208 89 Americas 83 77 82 66

- Australia and Oceania - - - -

832 Production of liquids 845 860 846 824 282 - of which Joint Ventures and associates 279 283 286 250

PRODUCTION OF NATURAL GAS BY REGION

Q2 2026 2026 2025 2026 2025

175 Italy (mmcf/d) 174 190 178 212 603 Rest of Europe 583 491 601 497 1,848 North Africa 1,869 1,851 1,870 1,836 1,145 Sub-Saharan Africa 1,053 769 1,089 747 878 Asia 1,115 1,008 927 882 357 Americas 354 346 352 335

- Australia and Oceania - 32 - 26 5,006 Production of natural gas 5,148 4,687 5,017 4,535 1,487 - of which Joint Ventures and associates 1,930 1,096 1,541 1,060 Q3 Nine months Q3 Nine months Q3 Nine months (a) Includes Eni ’s share of production of equity -accounted entities .

(b)Includes volumes ofhydrocarbons consumed inoperation (157 and 129 kboe/d inthethird quarter of2026 and 2025, respectively, 159 and 131 kboe/d inthenine months of2026 and 2025, respectively, and 150 kboe/d in the second quarter of 2026).

(c) In the third quarter 2026 and in the nine months 2026 , it includes 81 and 79 kboe /d, respectively , of production related to certain sanctioned joint‑venture partners .

(d)From 2026, Enihas discontinued reporting data onproduction/reserves forKazakhstan because this Country has represented less than 15% ofEni’stotal proved reserves forthree years inarow, with 15% being the US SEC threshold for single country disclosures , due to growth in other areas . Kazakhstan data have been aggregated in the geographic area “Asia ”.