Eni: results for the second quarter and half year 2026

1 PRICE SENSITIVE

Eni: results for the second quarter and half year 2026 Excellent 2Q performance and enhanced guidance ;

increased shareholder returns • 2Q ’26 excellent results driven by consistent execution and delivery from a diversified portfolio of advantaged assets.

• Exceptional underlying production g rowth of 11% y-o-y, net of price effects .

• Established Searah JV with Petronas creating a major growth platform across Indonesia and Malaysia .

• FID for Phase 3 of the Baleine field off Cote d’Ivoire , the Great er PAJ project off shore Angola and the Cronos gas project in deep waters off Cyprus .

• Entered critical minerals value chain through investments in Canada and Chile on graphite and lithium .

• Gearing on a profo rma level close to 10% , a historic low.

As a result of strong execution and the market environment , Eni raises guidance on 2026 production to around 5% underlying growth and increase s its distribution policy t o €3.4 bln of share buyback.

San Donato Milanese , July 29, 2026 - Eni's Board of Directors, chaired by Giusepp ina Di Foggia , yesterday approved the consolidated results for the second quarter and first half of 2026. Eni CEO Claudio Descalzi said:

“Our focus on executing our strategy has driven excellent results in 2Q ’26 underpinned by our diversified portfolio that pro vides us a wide range of options and a perspective of profitable growth across different businesses of the energy mix. The Group’s results reflect our robust industrial and financial performance, significantly outperforming the commodity market. We are successfully scaling our E&P business for the next phas e of growth and value creation thanks to the start of the Searah JV across Indo nesia and Malaysia, which will monetize our large gas discoveries in the Kutei Basin, as well as several project advancements and expansion in new geographies. The strength of this business and our world -class E&P capabilities have driven an outstanding 11% of underlying production growth. The Transition businesses have been st eadily improving their contribution to the Group results while fueling their self -funded growth. Plenitude is on track to reach 6.5 GW of installed capacity at year -end and can already leverage a customer base of around 11 million clients to drive value. Enilive is bringing online new capacity to take advantage of rapidly raising biofuels demand and was able to capture the full upside of a strong market. As the results achieved so far in 2026 demonstrate, we are a fundamentally strong er company year after year thanks to the quality of our portfolio: it is geographically diversified, grounded in advantaged assets, with exploration compe tence and transition exposure, as well as optionality for early monetization, supporting dependable cash generation for years to co me. It will enable us to continue returning significant capital to shareholders with material upside participation in high scenarios, while retaining a robust balance sheet as highl ighted by a proforma gearing at a historic low of 10%. As a consequence of these excellent results, we are raising our distribution policy by further €600 mln, to €3.4 bln of share

buyback.”

Key operating and financial results Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

1,798 Hydrocarbon production kboe/d 1,789 1,668 7 1,793 1,658 8 5.9 Installed capacity from renewables at period end GW 6.0 4.5 33 6.0 4.5 33 3,536 Proforma adjusted EBIT ⁽ᵃ⁾ € million 5,375 2,681 100 8,911 6,362 40 2,418 subsidiaries 3,516 1,889 86 5,934 4,489 32 1,118 main JV/Associates ⁽ᵇ⁾ 1,859 792 135 2,977 1,873 59 Proforma adjusted EBIT (by segment) ⁽ᵃ⁾

3,357 E&P 4,769 2,422 97 8,126 5,730 42

327 Global Gas & LNG Portfolio (GGP) and Power 503 387 30 830 860 (3) 351 Transition Businesses 521 262 99 872 598 46 (260) Refining, Chemicals and Sites in transformation (40) (193) 79 (300) (527) 43 (239) Corporate, other activities and consolidation adjustments (378) (197) (617) (299) 2,378 Adjusted net profit before taxes ⁽ᵃ⁾ 3,857 2,200 75 6,235 4,949 26 1,302 Adjusted net profit (loss) ⁽ᵃ⁾⁽ᶜ⁾ 2,333 1,134 106 3,635 2,546 43 1,071 Net profit (loss) ⁽ᶜ⁾ 3,319 543 511 4,390 1,715 156 2,878Cash flow from operations before changes in working capital at replacement cost ⁽ᵃ⁾4,469 2,775 61 7,347 6,189 19 1,427 Net cash from operations 4,270 3,517 21 5,697 5,902 (3) 1,872 Organic capital expenditure ⁽ᵈ⁾ 1,838 2,029 (9) 3,710 3,914 (5) 10,848 Net borrowings before lease liabilities ex IFRS 16 11,271 10,198 11 11,271 10,198 11 54,291 Shareholders' equity including non-controlling interest 56,930 53,405 7 56,930 53,405 7 15 Proforma gearing before lease liabilities ex IFRS 16 ⁽ᵃ⁾ (%) 10 10 (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 18 and subsequent.

(c) Attributable to Eni's shareholders.Q2 IH (b) The main JV/associates are listed in the "Reconciliation of Group proforma adjusted EBIT" on page 22.

2

Strategic and financial highlights E&P result reflects advantaged barrels and cost discipline, with exploration and project maturation under pinning growth outlook • Underlying production , net of price effects, grew by a robust 11% y-o-y to 1.79 mln boe/d, close to flat q -o-q, driven by new project ramp -ups in West Africa, the GoA , Norway and Indonesia. FY production growth rate to around 5%.

• Established Searah JV with Petronas , a regional leader in Southeast Asia’s LNG market . Searah is immediately accretive to Eni’s 2Q cash flow and production. The JV will support the development of Eni’s material discoveries in the Kutei Basin, delivering highly attractive, and valuable, production growth into the 2030s .

• Agreed to acquire interests in upstream assets in Argentina to suppl y the floating LNG production development.

• Reached the final investment decision for Phase 3 of the core Baleine field, off Côte d’Ivoire, for the Great er PAJ block off Angola, operated by the Azule Energy JV and for the Cronos gas project off Cyprus .

• Farmed into an unexplored block in the Republic of the Gambia, marking Eni’s entry into this new geography.

Transition businesses fully on track to meet or exceed annual profitability and growth targets • Enilive and Plenitude delivered adj usted EBITDA of € 1.1 bln in the first half ’26.

• Activities are progressing for the de consolidation of Plenitude in 3Q ’26, with Eni still retaining a 65% stake, thus providing the entity with a more efficient capital structure to pursue growth plans.

• Enilive signed an agreement to acquire from Prax a network of 320 service stations branded OIL!, strengthening its presence in the mobility retail business in key European markets .

• Secured financing for the CCUS business from a pool of international lenders .

New business developments to further strengthen the portfolio • The agreement with Mercuria to establish a global trading JV will maximize value across the commodity supply chain by integrating the optimization of the physical asset portfolio with advanced trading capabilities and expertise.

• Entered the critical minerals value chain through direct investments in initiatives in Canada and Chile, supporting Eni’s ongoing plans to strengthen its transition business es.

• Established a JV with the United Kingdom Atomic Energy Authority to offer specialized services for the fuel cycle, which will be a factor in the operation of fusion power plants at industrial scale.

Managing portfolio optionality to accelerate cash generation and growth • Reached a long -term partnership agreement concerning an upstream portfolio based on infrastructure . ENI entered into a partnership agreement with AC Europe II SCSp (an entity managed by Ares Credit Management LLC), in exchange for a $2 bln capital contribution to be cashed -in the third quarter. AC Europe II SCSp obtained binding commitment letters from funds managed by Ares Alternative Credit Asset Management and from Pacific Investment Management Company LLC - PIMCO in line with market pra ctice for an aggregate amount equal to the investment to be made by it.

• Near completion of the divestment of a 10% interest in the Baleine oilfield.

• Expect ed to monetize a retained 10% equity stake in the Kutei blocks through a separate portfolio transaction in 2026.

Fast -tracking the reconversion of the main chemical hubs to transition businesses • Set up a Special Purpose Vehicle to build a biorefinery at the Priolo complex, which will be complemented by a post -

consumer chemical plastics recycling plant based on proprietary recycling technology.

• Construction work began at our Brindisi hub , on a manufacturing facility for lithium -iron-phosphate batteries for prima ry use in stationary electricity storage systems support ing renewable generation.

Excellent 2Q financial results driven by volume growth, cost management and a supportive pricing environment, with proforma gearing at the low end of our guided range of 10 -15% and €1.35 b ln of cash returns to shareholders.

2Q ‘26 Group’s proforma adj usted EBIT was € 5.38 bln, doubling y-o-y (up 52% on a sequential basis) due to strong performance at E&P, GGP and the Transition satellites. Also a djusted net profit more than doubled to €2.3 bln.

• E&P reported €4. 77 bln of proforma adj usted EBIT (up 42% and 97% respectively vs. 1Q’ 26 and y -o-y) driven by favorable volume/mix effects, cost discipline and better oil realizations, despite exchange rate trend.

• GGP and Power reported €0. 50 bln of proforma adj usted EBIT, with GGP at €0.47 bln up 4 6% y-o-y due to continued asset portfolio optimization and specific benefits relating to renegotiations and settlements .

• Enilive more than doubled its proforma adjusted EBIT to €0. 29 bln, driven by the biorefining business, which benefited also from an improved market scenario. Plenitude reported €0.2 3 bln of proforma adjusted EBIT, up 70% y-o-y, driven by volume growth in the renewables and the halting of depreciation pending the proposed deconsolidation transaction .

• The Refining business reported positive proforma adjusted EBIT of €0.0 8 bln, reversing the year -ago loss due to an improved refining margin scenario , partly capped by higher shipping cost and narrowing differentials between heavy/sour vs light/sweet crudes , which penalized margins at complex cycles. Versalis’ chemicals business began to show progress thanks to ongoing restructuring measures and last year’s plant closures, with the loss cut by 65% to around €0.0 7 bln, also on the back of temporary supply disruptions supporting commodity plastics margins .

2Q ’26 Group’s adjusted CFFO before working capital was €4. 47 bln, funding organic capex of €1. 84 bln. Cash returns to shareholders were €1.35 bln, compris ing the final tranche of the ‘25 dividend (€0.79 bln) and start of the ‘26 buyback program (€0.56 bln). Net debt was €11.3 bln at end 2Q ‘26, with proforma gearing at 10%, at the low end of the 10% -15% target range .

3 Outlook 202 6 Eni is raising guidance for business performance and cash flow generation, which translates into an increased buyback programme thus granting material upside participation for shareholders Specifically , our updated segmental guidance is providing:

• FY’26 underlying oil & gas production growth is now expected to be around 5%, compared with the previously announced 3–4% target range .

• FY’26 GGP adjusted proforma EBIT guidance is raised to over €1.4 bln, representing an increase of 40% compared with the initial level.

• Enilive and Plenitude: FY proforma adjusted EBITDA is revised upward , at current scenario, to €1.3 bln (from €1.1 bln) for Enilive and confirmed at €1.3 bln for Plenitude.

• Year-end installed renewable capacity at 6.5 GW (Plenitude @ 100%); biorefinery capacity at 2.1 MTPA plus 1.5 MTPA under construction (net Enilive).

On the financial side, we are strengthening our cash flow guidance:

• At a revised Brent scenario of 85 $/bbl and SERM refining margin at 14 $/bbl, with TTF gas price confirmed at 50 €/MWh (exchange rate EUR/USD of 1.16), adjusted CFFO is expected to amount to €1 5 bln, representing an underlying improvement of €0.7 bln vs Group’s sensitivities1.

• Gross capex confirmed at €7 bln ; net capex is guided to less than €5 bln, down vs. previous guidance .

• Proforma g earing at the lower end of the 10 -15% guided range. Reported gearing expected to converge to that level by year end.

As a result of the Company’s improved outlook, we are raising cash distributions to shareholders:

• The 2026 share repurchase plan is expanded to €3.4 bln, up 20% from last quarter already revised guidance of €2.8 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. Th e new buyback amount represents more than double the initial guidance of €1.5 bln at the budgeted cash flow.

• Considering the updated refining margin scenario at 14 $/bbl (vs 6 $/bbl of the budget), should such margin remain higher than 50% of the initial guidance (i.e. at least 9 $/bbl compared to budgeted 6 $/bbl) an extraordinary dividend is expected to be defined in October and paid in the fourth quarter, in line with the Group stated remuneration policy to return 100% of upside in CFFO due to a scenario with Brent above 90 $/bbl or with a 50% increase in gas pric es or refining margins above budgeted levels, in accordance with the Group's sensitivities (€0.08 bln per each one -dollar change in the SERM margin).

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

1 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.

4 Exploration & Production Production and price s

Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

80.61 Brent dated $/bbl 104.52 67.82 54 92.57 71.74 29 1.170 Average EUR/USD exchange rate 1.163 1.134 3 1.167 1.093 7 1,798 Hydrocarbons production ⁽ᵃ⁾ kboe/d 1,789 1,668 7 1,793 1,658 8 862 Liquids kbbl/d 832 825 1 847 805 5 4,893 Natural gas mmcf/d 5,006 4,415 14 4,950 4,458 11 55.68 Average realizations ⁽ᵇ⁾ $/boe 69.79 50.81 37 62.57 52.99 18 72.79 Liquids $/bbl 96.50 62.77 54 84.16 66.17 27 7.28 Natural gas $/kcf 8.42 7.14 18 7.85 7.36 7Q2 IH (a) In the second quarter 2026 and in the first half 2026, it includes 78 kboe/d, respectively, of production related to certain sanctioned joint‑venture partners.

(b) Prices related to consolidated subsidiaries.

• In Q2 ’26, hydrocarbons production averaged 1.79 mln boe/d, 7% higher than the comparative period ( 1.79 mln boe/d in IH ’26, up 8% from the comparative period) driven by projects ramp -ups in Norway, Congo and Mexico, new projects start -ups in Angola and higher contribution from Indonesia/Malaysia where the new JV Searah was launched, as well as operational continuity. Quarterly underlying y -o-y production growth was 11%, adjusted for impact of portfolio transactions and price effects .

• Liquids production was 832 kbbl/d in Q2 ’26, broadly in line compared to Q2 ’25 ( 847 kbbl/d in IH ’26, up 5% from the comparative period), driven by growth in Norway, Angola, Congo and Mexico.

• Natural gas production was 5,006 mmcf/d, an increase of 14% compared to Q2 ’25 ( 4,950 mmcf/d in IH ’26 , 11% higher than the comparative period) mainly due to organic growth in Norway and Congo.

Results

Q1 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

4,950 Upstream turnover 5,861 4,701 25 10,811 10,107 7 3,357 Proforma adjusted EBIT 4,769 2,422 97 8,126 5,730 42 1,074 of which: main JV/Associates 1,793 763 .. 2,867 1,841 56 1,851 Operating profit (loss) of subsidiaries 1,651 1,495 10 3,502 3,446 2 432 Exclusion of special items 1,325 164 1,757 443 2,283 Adjusted operating profit (loss) of subsidiaries 2,976 1,659 79 5,259 3,889 35 2,398 Adjusted profit (loss) before taxes 3,469 1,957 77 5,867 4,413 33 38.3 tax rate (%) 35.2 45.9 36.4 46.2 1,480 Adjusted net profit (loss) 2,249 1,059 .. 3,729 2,372 57 53 Exploration expenses: 167 42 .. 220 86 ..

53 prospecting, geological and geophysical expenses 81 42 93 134 86 56 write-off of unsuccessful wells 86 #DIV/0! 86 1,615 Capital expenditure 1,526 1,336 14 3,141 2,775 13Q2 IH

Q1 2026 Main JV/Associates 2026 2025 % Ch. 2026 2025 % Ch.

1,074 Adjusted operating profit (Eni's share) (€ million) 1,793 763 .. 2,867 1,841 56 703 of which: Vår Energi 1,217 412 .. 1,920 1,009 90 177 Azule Energy 286 218 31 463 450 3 199 Adjusted net profit 592 167 .. 791 495 60 308 Total dividends 250 330 (24) 558 596 (6) 525 Hydrocarbon production (kboe/d) 566 432 31 546 432 26Q2 IH

• In 2Q ’26, Exploration & Production reported a proforma adjusted EBIT of € 4,769 mln, increasing by 97% vs. 2Q ’25 due to favorable volume/mix effects, cost discipline , higher crude oil realized prices in USD (the Brent marker was up by 5 4%) and higher gas realizations (up by 18%), offset by the negative impact of exchange rate translation of dollar -denominated results of foreign subsidiaries ( the EUR/USD exchange rate was up by 3%). In the IH ’2 6, proforma adjusted EBIT was €8,126 mln, up 42% compared to the IH ’2 5, due to the same drivers as for the 2Q.

• In 2Q ’26, the segment reported an adjusted net profit of € 2,249 mln, more than doubling y -o-y and include d a higher contribution from JVs and associates. Adjusted net profit was € 3,729 mln in the IH ’2 6, an increase of 57% y-o-y. Business segments: operating and financial results

5 • In 2Q ’26 the tax rate was about 3 5% lower than in 2Q ’25 (46%) , 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 April, a significant gas and condensate discovery was made in Egypt, with the successful drilling of the Denise W 1 exploration well in the Temsah Concession, offshore in the Eastern Mediterranean Sea. Preliminary estimates indicate about 2 trillion cubic feet (Tcf) of gas in place and 130 Mbbl of associated condensates. The discovery is close to existing production facilities providing significant synergies for a fast-track development.

• In April, a giant gas and condensate discovery was made at the Geliga -1 (Eni 82%) well located in the Ganal block in the Kutei Basin, offshore Indonesia. Preliminary estimates indicate in -place resources of approximately 5 trillion cubic feet (Tcf) and 300 Mbbl of condensate allowing the possible development of a third production hub in the prolific Kutei Basin.

Subsequent production tests performed in May confirmed the magnitude of the discovery . Proximity to existing and planned infrastructure offers potentially significant development cost synergies and an accelerated time -to-market .

• In April, a MOU was signed with the Ministry of Hydrocarbons of Venezuela and the state oil company PDVSA to relaunch oil activities participated by Eni in the country , including the Junin -5 heavy oil field (Eni 40%) in the Orinoco Belt, as part of the initiatives to re cover amounts owed by PDVSA to Eni in connection with gas supplies at the Perla field .

• In May, a final investment decision (FID) was approved for the Phase 3 of the Baleine oil project, off Côte d'Ivoire. The Phase 3 full field development will increase oil production to 150 kbbl/d and gas production to 200 mmcf/d , doubling the current production rate .

• In June, Eni was awarded exploration Block A1 in the offshore of the Republic of the Gambia. The deal is in line with the Company’s exploration strategy focused on building a geographically diversified portfolio which includes opportunities in proven but still underexplored and emerging areas and in frontier ones with high potential.

• In June, having obtain ed all required regulatory approvals, Eni and Petronas established Searah, a new 50/50 independent joint venture which combines assets across Indonesia and Malaysia, just seven months after the signing of the Investment Agreement. Searah, with a portfolio of 19 gas -producing and development assets, 14 in Indonesia and 5 in Malaysia, is currently producing about 300 kboe/d. A $6 b ln revolving credit facility has been successfully secure d to fund Searah’s growth plans, which include a pipeline of expected investment s for over $20 b ln over the next five years.

These investments will support the development of more than 3 b ln boe of discovered resources and unlock additional exploration potential , which will ensure a sustainable long -term production plateau of 500 kboe/d .

• In June, the JV Azule Energy made a final investment decision for the operated Greater PAJ project, off Angola. The project will develop hydrocarbon re serves across five fields in two adjacent Block 31 and Block 31/21 concessions.

Production start -up is expected in the first half of 2029 by means of a new Floating Production, Storage and Offloading vessel (FPSO) with a production capacity of 95 kbbl/d of oil and 70 mmcf/d of gas .

• In June, production start - up was achieved at the Sabratha Compression Project in partnership with the Libyan National Oil Corporation (NOC), which was designed to sustain and increase gas output from the Bahr Essalam gas field. The Sabratha Compression Project will support increase d gas volumes of about 800 m ln cubic meters /year as well as associated condensates.

• In June, a sale and purchase agreement was signed with YPF for the acquisition of a 32% interest in three upstream blocks (Meseta Buena Esperanza, Aguada Villanueva, and Las Tacanas ) in Argentina. The three blocks will be part of the Argentina LNG integrated development, an upstream -midstream project aimed at leveraging the Vaca Muerta gas resources. These assets’ resources will feed the 12 m ln tons per annum (MTPA) of LNG capacity (via two floating LNG units of 6 MTPA each).

• In July, reached a final investment decision to develop the gas Cronos operated project, in Block 6 offshore Cyprus.

Production start -up is expected in 2028 with a plateau production of about 500 mmcf /d. Production will be transported and processed in existing Zohr facilities, in Egypt, then liquefied in Damietta LNG plant for export to international markets .

• The disposal of the 25% interest in the Congo L NG project announced in 1Q ’25 was not finalized , since the relevant conditions precedent were not satisfied.

6 Global Gas & LNG Portfolio and Power Sales and production Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

Global Gas & LNG Portfolio 42 Spot Gas price at Italian PSV €/MWh 47 38 22 44 43 3

40 TTF 46 35 29 43 41 4

2 Spread PSV vs. TTF 1 3 (62) 2 2 Natural gas sales bcm 7.67 Italy 5.62 4.49 25 13.29 10.44 27 5.32 Rest of Europe 4.27 3.86 11 9.59 9.07 6 0.09 Importers in Italy 0.08 0.28 (71) 0.17 0.50 (66) 5.23 European markets 4.19 3.58 17 9.42 8.57 10 0.91 Rest of World 0.86 0.66 30 1.77 1.62 9 13.90 Worldwide gas sales ⁽ᵃ⁾ 10.75 9.01 19 24.65 21.13 17 3.4 LNG sales 2.9 2.8 4 6.3 5.6 13

Power

5.32 Thermoelectric production TWh 3.91 4.53 (14) 9.23 9.94 (7)Q2 IH (a) Data include intercompany sales.

• In 2Q ’26, natural gas sales were 10.75 bcm, an increase of 19% from the comparative period. Sales in Italy increased by 25% vs. 2Q ’25, whilst sales in the European market s amounted to 4.19 bcm, an increase of 17% vs. 2Q ’25, reflecting higher sales to hub s in Benelux, France and Germany /Austria. LNG sales in 2Q ‘26 increased by 4% compared to the same period of 2025, largely due to more supply from Congo and Nigeria . In IH ’26, natural gas sales amounted to 24.65 bcm, up 17% vs the IH ‘25, mainly thanks to high er gas volumes marketed in Italy (up 27% vs. IH ’25) and in the European markets, in particular in Benelux and Germany /Austria (up 10% vs. IH ’25).

• Thermoelectric production amounted to 3.91 TWh in 2Q ’26, down by 14% vs. 2Q ’25 with a lower plant utilization rate due to planned maintenance activities (9.23 TWh in IH ‘2 6, representing a decrease of 7% compared to the same period in 202 5, due to the same drivers as of the quarter).

Results

Q1 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

5,375 Sales from operations 4,058 3,444 18 9,433 9,034 4 327 Proforma adjusted EBIT 503 387 30 830 860 (3)

315 GGP 468 321 46 783 631 24

9 of which: main JV/Associates 8 9 (11) 17 19 (11) 12 Power 35 66 (47) 47 229 (79) (142) Operating profit (loss) of subsidiaries 523 585 (11) 381 1,358 (72) 460 Exclusion of special items (28) (207) 432 (517) 318 Adjusted operating profit (loss) of subsidiaries 495 378 31 813 841 (3) 324 Adjusted profit (loss) before taxes 497 382 30 821 852 (4) 204 Adjusted net profit (loss) 311 235 32 515 542 (5) 8 Capital expenditure 14 25 (44) 22 37 (41)Q2 IH

• In 2Q ’26, the Global Gas & LNG Portfolio business achieved a proforma adjusted EBIT of € 468 mln, increasing by 46% vs. the comparative period benefitting from the continued asset portfolio optimizations and specific benefits relating to renegotiations and settlements . In IH ’2 6, proforma adjusted EBIT amounted to € 783 mln, up by 24% compared to IH ’2 5.

• In 2Q ’26, the Power generation business reported a proforma adjusted EBIT of € 35 mln down by 47% compared to the comparative period . The y -o-y comparison is affected by the circumstance that the 2025 results were impacted by a one-

off item. In IH ‘2 6, proforma adjusted EBIT was € 47 mln, down by € 182 mln compared to IH ’25 due to the same driver as for the quarter .

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

Strategic developments

• In May, three long -term agreements were signed for the purchase of liquefied natural gas in Indonesia with the South Hub and North Hub gas projects, both projects operated by Searah, the new 50/50 joint venture between Eni and Petronas. These long -term agreements relate to LNG volumes that will be supplied through the existing Bontang plant and cover volumes of approximately 2 MTPA. These additional LNG volumes will further diversify and strengthen Eni’s global integrated portfolio.

7 • In June, Eni booked regasification capacity at the Ravenna terminal equal to 2 bcm/year for a 10 -year term.

• In July, an agreement was signed with Mercuria to establish a global trading joint venture to fully capture value across the entire supply chain of energy commodities . The new venture, equally owned, will operate on an independent and unconsolidated basis through a holding structure with international trading hubs, ensuring a global operational presence.

The activities include the commercialization and trading of commodities including oil, biofuels, gas, LNG and related logistics and infrastructure rights.

• In July, reached the Final Investment Decision (FID) to develop Cronos project, in deep waters offshore Cyprus, with the target to bring the first Cypriot gas to market in 2028. Through the marketing of 50% of the LNG volumes, equivalent to 1.4 MTPA, Eni w ill increase its contracted LNG portfolio supporting its strategic ambition to exceed 20 MTPA by 2030.

Transition Businesses

Enilive

Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

Enilive

1,515 Spread EU HVO UCO-based vs UCO (CIF) $/tonnes 1,732 852 103 1,623 777 109 750 Spread US RD ⁽ᵃ⁾ UCO-based vs UCO 1,122 444 153 936 463 102 252 Bio throughputs ktonnes 275 274 527 566 (7) 64 Average bio refineries utilization rate % 74 74 69 77 4.69 Total Enilive sales mmtonnes 5.24 5.38 (3) 9.93 10.66 (7) 1.89 Retail sales 2.11 1.97 7 4.00 3.75 7 1.39 of which: Italy 1.04 1.40 (26) 2.96 2.65 12 2.39 Wholesale sales 2.47 2.83 (13) 4.86 5.71 (15) 1.65 of which: Italy 1.74 2.09 (17) 3.39 4.36 (22) 0.41 Other sales 0.66 0.58 14 1.07 1.20 (11)Q2 IH (a) Renewable Diesel.

• In 2Q ’26, bio throughputs were 0.28 mmtonnes, substantially in line vs. the comparative period , driven by higher volumes processed at Gela and Chalmette biorefiner ies which offset lower volumes at Venice biorefinery following a planned shutdown in order to enhance biorefinery configuration . In IH ‘2 6, bio throughputs decreased by 7% compared to the same period of 202 5, reflecting the shutdown at Venice biorefinery .

• In 2Q ’26, retail sales were 2.11 mmtonnes, a 7% increase vs 2Q ’25, supported by a positive performance in Italy. In IH ‘26, retail sales amounted to 4 mmtonnes, up by 7% vs. IH ’25, following the same driver s of the quarter.

• In 2Q ’26, wholesale sales were 2.47 mmtonnes, a reduction of 13% y-o-y due to portfolio optimization in a competitive market in Italy. In IH ‘26, wholesales sales amounted to 4.86 mmtonnes, a reduction of 15% vs. IH ‘25, following the same drivers of the quarter.

Q1 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

4,757 Sales from operations 6,917 4,779 45 11,674 9,536 22 217 Proforma adjusted EBITDA 375 209 79 592 381 55 138 Proforma adjusted EBIT 295 129 129 433 224 93 2 of which: main JV/Associates 28 (9) .. 30 (24) 225 183 Operating profit (loss) of subsidiaries 192 53 262 375 174 116 (105) Exclusion of inventory holding (gains) losses 70 61 (35) 42 58 Exclusion of special items 5 24 63 32 136 Adjusted operating profit (loss) of subsidiaries 267 138 93 403 248 63 127 Adjusted profit (loss) before taxes 287 126 128 414 213 94 93 Adjusted net profit (loss) 208 76 174 301 141 113 165 Cash flow from operations before changes in working capital at replacement cost 293 176 66 458 325 41 (1,004) Net borrowings (438) (1,264) 65 (438) (1,264) 65 63 Capital expenditure 56 68 (18) 119 101 18Q2 IH

• In 2Q ’26 Enilive reported a proforma adjusted EBIT of € 295 mln, more than double compared to 2Q ’25 (€433 mln in IH ’26, compared to € 224 mln in IH ’2 5, up by 93%) mainly thanks to the biorefining business which benefited from an improved market scenario , despite the Venice plant shutdown .

• Proforma adjusted EBITDA amounted to € 375 mln, increasing by 79% compared to the 2Q ’25 (€ 209 mln). In IH ’2 6 Enilive reported a proforma adjusted EBITDA of € 592 mln, compared to a profit of € 381 mln in IH ’2 5 (up by 55%).

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

8

Strategic developments

• In May, Eni and MSC Cruises completed test activities of Enilive’s HVO diesel , confirm ing its immediate applicab ility for use in marine engines with performance in line with traditional marine fossil fuels and also reducing emissions.

• In July, Enilive, through its subsidiary Enilive Deutschland, signed a binding agreement with Prax to acquire 100% of OIL!

Tankstellen , a company operating in the mobility sector in Germany, Denmark, Austria and Switzerland. Completion of the transaction is subject to the approval of the relevant regulatory authorities. The acquisition will enable Enilive to expand its European network b y approximately 320 service stations, strengthening its presence in key strategic markets.

• In July, an agreement was signed with carmaker BMW Group to power its vehicles of corporate fleets in Italy with HVO Diesel manufactured by Enilive .

Plenitude

Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

Plenitude

130 Italian PUN Index GME €/MWh 124 102 22 127 120 6 9.8 Retail and business customers at period end mln pod 10.8 10.0 8 10.8 10.0 8 2.27 Retail and business gas sales to end customers bcm 0.65 0.68 (5) 2.92 3.07 (5) 5.19 Retail and business power sales to end customers TWh 5.14 4.09 26 10.33 8.99 15 5.9 Installed capacity from renewables at period end GW 6.0 4.5 33 6.0 4.5 33 1.8 Energy production from renewable sources TWh 2.2 1.5 47 4.0 2.7 48 22.9 EV charging points at period end thousand 23.2 21.8 6 23.2 21.8 6Q2 IH

• As of June 30 , 202 6, retail and business customers were 10.8 mln (gas and electricity), an increase of 0.8 mln compared to June 30, 2025 mainly benefitting from the acquisition of the Acea Energia customer portfolio.

• Retail and business gas sales to end customers amounted to 0.65 bcm in 2Q ’26, decreasing by 5% compared to 2Q ’25.

In IH ‘26, gas sales amounted to 2.92 bcm, decreasing by 5% vs. the comparative period, mainly abroad due to lower average consumptions.

• Retail and business power sales to end customers were 5.14 TWh in 2Q ’26, reflecting an increase of 26% compared to 2Q ’25, thanks to higher sales in Italy. In IH ’26 power sales amounted to 10.33 TWh (+15%), benefitting from increasing customer portfolio in the domestic business segment following the ab ove mentioned Acea Energia acquisition and increasing power average consumption.

• As of June 30 , 202 6, the installed capacity from renewables was 6 GW, with an increase of 1.5 GW compared to June 30, 2025, reflecting the organic development in Spain, the UK, Greece, Italy and Kazakhstan, as well as the acquisitions in France and in the USA.

• Energy production from renewable sources was 2.2 TWh in 2Q ’26, up by 47% y -o-y, mainly thanks to the increased capacity in France and the development of organic projects in Spain (4 TWh in IH ’26, +48% vs. the comparative period).

• As of June 30 , 202 6, EV charging points amounted to 23.2 thousand, up by 6% compared to 21.8 thousand as of June 30, 2025, thanks to network development, mainly in Italy, France and Germany.

Q1 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

3,230 Sales from operations 2,075 1,885 10 5,305 5,603 (5) 308 Proforma adjusted EBITDA 233 256 (9) 541 614 (12) 213 Proforma adjusted EBIT 226 133 70 439 374 17 774 Operating profit (loss) of subsidiaries 52 30 .. 826 64 ..

(574) Exclusion of special items 147 94 (427) 302 200 Adjusted operating profit (loss) of subsidiaries 199 124 60 399 366 9 204 Adjusted profit (loss) before taxes 189 107 77 393 336 17 134 Adjusted net profit (loss) 130 68 91 264 223 18 248 Cash flow from operations before changes in working capital at replacement cost 154 217 (29) 402 580 (31) 2,810 Net borrowings ⁽ᵃ⁾ 3,274 2,061 59 3,274 2,061 59 101 Capital expenditure 118 196 (40) 219 340 (36)Q2 IH (a) Of which €3.0 bln due to Eni's Group as of June 30, 2026.

9 • In 2Q ’26 Plenitude reported a proforma adjusted EBIT of € 226 mln, up by 70% vs 2Q ’25 , benefiting from volume growth in the renewables business and the halting of depreciation pending the proposed deconsolidation transaction . In IH ’26 Plenitude reported a proforma adjusted EBIT of €439 mln , an increase of 17% compared to a proforma adjusted EBIT of €374 mln in IH ’25.

• In 2Q ’26, proforma adjusted EBITDA amounted to € 233 mln, down by 9% vs 2Q ’25 . In IH ’2 6 reported a proforma adjusted EBITDA of € 541 mln, down by 12% compared to IH ’2 5 (€614 mln).

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

Strategic developments

• In April , Plenitude complet ed the acquisition of 100% of the share capital of Acea Energia S.p.A. and 50% of the share capital of Umbria Energy S.p.A.

• In May, Plenitude, through its subsidiary Plenitude On The Road, progressed the development plan of its charging network with the installation of new infrastructures at ALDI retail locations across Italy. The plan foresees installation of charging points supported by different technologies, with the target of reaching an overall presence in more than 100 ALDI stores.

• In June, as part of the development of the Renopool photovoltaic project in Spain, the largest solar park built by the Company worldwide, with a total installed capacity of 330 MW, Plenitude started production at the second 200 MW plant.

• In June, Plenitude signed a 15 -year Power Purchase Agreement with STAT, a company specializing in the design and production of components for the automotive sector. Plenitude will build a new 890 kWp photovoltaic plant to supply electricity to the company’s production facilities .

• In June, Plenitude started production at the Villarino photovoltaic plant (Spain) ; with an installed capacity of 220 MW, it is expected to reach an estimated annual production of over 400 GWh .

• In July, Plenitude achieved the First Industrial Electricity in Kazakhstan from the 120 MW gas -fired power plant. This milestone marks a major step in the development of Kazakhstan’s first large -scale hybrid power plant, which will integrate solar, gas -fired and wind generation in the future.

Refining , Chemical s and Sites in transformation Production and sales Q1 2026 2026 2025 % Ch. 2026 2025 % Ch.

Refining

10.1 Standard Eni Refining Margin (SERM) ⁽ᵃ⁾ $/bbl 8.3 4.8 74 9.1 4.3 ..

2.78 Throughputs in Italy on own account mmtonnes 3.37 3.73 (10) 6.14 7.07 (13) 2.23 Throughputs in the rest of World on own account 1.73 2.67 (35) 3.96 5.17 (23) 5.01 Total throughputs on own account 5.10 6.40 (20) 10.10 12.24 (17) 66 Average refineries utilization rate % 74 84 70 79

Chemicals

0.65 Sales of chemical products mmtonnes 0.61 0.72 (15) 1.26 1.52 (17) 58 Average plant utilization rate % 57 47 21 58 51 14Q2 IH (a) Given volatility and market dislocations, the benchmark SERM refining margin has been calculated to factor such conditions. The margin for Q1 ’26 has been revised accordingly.

Refining

• In 2Q ’26, the Standard Eni Refining Margin averaged 8.3 $/barrel vs. 4.8 $/barrel in 2Q ’25 mainly due to more favorable middle distillate crack spreads reflecting product tightness in connection with disrupted flows from the Middle East and plant outages against a backdrop of refinery closures in the Atlantic Basin (9.1 $/barrel in the IH ‘2 6, representing a n increase vs. 4.3 $/barrel reported in IH ’2 5).

• In 2Q ’26, throughputs on own accounts at Eni’s refineries in Italy amounted to 3.37 mmtonnes, down 10% y-o-y, mainly affected by lower volumes processed at the Sannazzaro and Milazzo refiner ies due to planned maintenance downtime, partly offset by higher volumes at the Taranto refinery due to higher plant availability . In IH ’26 throughputs amounted to 6.14 mmtonnes, down by 13% vs. the comparative period. Throughputs outside Italy decreased by 35% vs. 2Q ’25, due to lower volumes processed due to the product unavailability connected to the closure of Strait of Hormuz . In IH ’2 6, throughputs decreased by 23% vs IH ’25, following the same drivers of the quarter .

10 Chemicals

• Sales of chemical products were 0.61 mmtonnes in 2Q ’26, a 15% decrease y -o-y due to lower production in particular polymers , following the closing of the Brindisi and Priolo sites, but now under transformation, and weaker demand. In IH ‘26, sales amounted to 1.26 mmtonnes, representing a decrease of 17% from the comparative period.

• 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. The only exception was an improvement in the polyethylene spread driven by product tightness amidst supply disruptions from the M iddle East.

Results

Q1 2026 (€ million) 2026 2025 % Ch. 2026 2025 % Ch.

4,112 Sales from operations 6,441 4,533 42 10,553 9,465 11 (260) Proforma adjusted EBIT (40) (193) 79 (300) (527) 43 (14) Refining ⁽ᵃ⁾ 80 (9) .. 66 (100) ..

20 of which: main JV/Associates 3 20 (85) 23 29 (21) (158) Chemicals (65) (184) 65 (223) (427) 48 (88) Sites in transformation (55) 0 (143) 0 (173) Operating profit (loss) of subsidiaries (129) (843) 85 (302) (1,302) 77 (404) Exclusion of inventory holding (gains) losses (151) 396 (555) 427 297 Exclusion of special items 237 234 534 319 (280) Adjusted operating profit (loss) of subsidiaries (43) (213) 80 (323) (556) 42 (259) Adjusted profit (loss) before taxes (63) (207) 70 (322) (550) 41 (229) Adjusted net profit (loss) (87) (197) 56 (316) (507) 38 158 Capital expenditure 282 175 61 440 288 53Q2 IH (a)Due totheshutdown ofthegasoline production unit inthefirst half 2026, theLivorno hub, currenty being upgraded toabiorefinery, has been reclassified tothesegment “Sites intransformation” effective 1 January 2026 with the adjustment of the Q1 result.

• In 2Q ’26, the Refining business, including the contribution from the ADNOC R&GT associate, reported a proforma adjusted profit of €80 mln, a better performance compared to the loss of € 9 mln reported in 2Q ’25. Despite the upside of a constructive refining margin scenario the result was capped by higher shipping expenses, narrowing differentials between heavy/sour vs light/sweet crudes which penalized margins at complex cycles and lower throughputs . In IH ’2 6 the business reported a proforma adjusted profit of €66 mln, reversing the proforma adjusted loss of €100 mln reported in IH ’2 5.

• The Chemical business, managed by Versalis, reported a proforma adjusted loss of € 65 mln in 2Q ’26, a significantly improved performance compared to the loss in 2Q ’25 (€184 mln), reflecting ongoing restructuring efforts and last year’s plant closures , as well as a temporary improvement in the market scenario due to supply disruptions in connection with the ME crisis in certain segments like polyethylene . The overall picture of the chemical sector remains depressed , because of rapidly escalating costs of oil -based feedstock and plant utilities expenses which were not reflected in commodity plastics final prices due to macro headwinds impacting commodity demands and competitive pressures from players with advantaged cost structures . Polyethylene spreads have returned to unprofitable territory in July. In IH ’26, proforma adjusted loss amounted to € 223 mln, almost 50% better than the €427 mln loss recorded in IH ’2 5.

• The Sites in transformation business, which is currently managing restructuring, decommissioning and environmental remediation operations at petrochemical hubs shut down in prior period, including the Brindisi and Priolo hubs, to prepare the sites for the next investment transformation phase, reported a proforma adjusted loss of € 55 mln due to ongoing expenses for plant restructuring . In IH ’2 6, proforma adjusted loss amounted to € 143 mln.

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

Strategic developments

• In May, Eni Industrial Evolution and FIB (Seri Industrial Group) signed an agreement for the joint development of an integrated industrial supply chain in the lithium iron phosphate “LFP” battery sector. The initiative is aimed at establishing an integrated industrial platform including the production of cells and modules, the assembly of systems for stationary energy storage and electric mobility, and, in the longer term, recycling activities and the production of cathode active materials. As part of the transaction, Eni Industrial Evolution acquired a 30% stake in a new company set -up by FIB (70% FIB’s stake), which will be engaged in project's commercial development and procurement and engineering activities. In July 2026, construction works started at the Brindisi hub to build a manufacturing facility of LFP batteries to be primarily used for stationary electricity storage systems to support renewable generation .

11 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 May, Eni finalized the acquisition of an 11.6% stake in Nouveau Monde Graphite ("NMG"), a Canadian company active in the natural graphite and advanced battery materials sector. The transaction allows Eni to enter the value chain of critical minerals, in line with its strategy of diversifying supply sources and strengthening in the battery materials sector and to support the development of the Gigafactory project for stationary lithium batteries in Brindisi.

• In May, Eni Rovuma Basin, on behalf of its Area 4 partners, signed two Memorandums of Understanding with the Ministry of Health of Mozambique for the improvement of hospital facilities in the provinces of Cabo Delgado and Maputo, contributing to the streng thening of the national health system and the promotion of more equitable access to quality healthcare services.

• In May, Eni CCUS Holding secured a financing facility of more than £500 mln from a pool of 13 international lenders to strengthen its Carbon Capture & Storage (CCS) project platform.

• In June, Eni and Hera inaugurated the Environmental Hub in Ravenna in the Ca’ Ponticelle reclaimed area. The project will help reduce the structural shortage of plants for managing special waste in Italy, maximizing material recovery and reducing reliance on landfills.

• In June, Eni signed a Letter of Intent with the Agenzia Italiana per la Cooperazione allo Sviluppo with the aim of identifying and evaluating initiatives in cooperation areas of common interest to support Ghana development .

• During the first half of 2026, as part of the Clean Cooking Program, Eni significantly expanded access to more efficient cooking solutions in Africa, reaching 1 mln people in Mozambique through the distribution of more than 200,000 improved cookstoves and inaugurating a new production center in Luanda (Angola). The program helps to reduce fuel consumption, pressure on natural resources and improve health. In addition, in Angola, Eni announced the launch of a sustainable agriculture and restoration proj ect for degraded ecosystems in the province of Moxico, in order to promote practices and interventions to rebuild forest ecosystems.

• In June, Eni signed a strategic agreement with Fincantieri for the development and dissemination of its proprietary Clean Sea technology, an advanced underwater robotic system for monitoring marine ecosystems and inspecting offshore infrastructure, aimed a t ensuring asset integrity. This technology provides applications in offshore projects and in Carbon Capture and Storage (CCS) in the marine environment.

• In June, Eni launched its new supercomputing system, HPC7 (High Performance Computing – HPC), which, with a capacity of over 861 PFlops/s, ranks 6th overall in the new TOP500 global ranking, second supercomputer in Europe and confirming its position as the world’s most powerful High -Performance Computer for industrial use.

• In June, Eni's stock was confirmed for the twentieth consecutive year in the FTSE4Good Developed index.

• In July, Eni and UKAEA (the United Kingdom Atomic Energy Authority) formed RH3OVA, a joint venture which combines the technical and industrial expertise of both partners to deliver specialist consultancy and operational services to the growing global fusio n industry.

• In July, Eni signed an agreement to acquire a 25% stake in EnergyX's Chilean subsidiary company Black Giant SpA, owing a lithium project located in the N orthern Chile , characterized by the application of an innovative technology with a lower environmental impact than traditional extraction techniques .

Sustainability and other developments

12 Q1

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

22,962 Sales from operations 24,375 18,767 30 47,337 41,332 15 2,173 Operating profit (loss) 1,898 1,162 63 4,071 3,490 17 (434) Exclusion of inventory holding (gains) losses (151) 372 .. (585) 358 ..

679 Exclusion of special items ⁽ᵃ⁾ 1,769 355 .. 2,448 641 ..

2,418 Adjusted operating profit (loss) 3,516 1,889 86 5,934 4,489 32 1,118 main JV/Associates adjusted EBIT 1,859 792 135 2,977 1,873 59 3,536 Proforma adjusted EBIT 5,375 2,681 100 8,911 6,362 40

3,357 E&P 4,769 2,422 97 8,126 5,730 42

327 Global Gas & LNG Portfolio (GGP) and Power 503 387 30 830 860 (3) 351 Transition Businesses 521 262 99 872 598 46 (260) Refining, Chemicals and Sites in transformation (40) (193) 79 (300) (527) 43 (239) Corporate, other activities and consolidation adjustments (378) (197) (617) (299) 2,378 Adjusted profit (loss) before taxes 3,857 2,200 75 6,235 4,949 26 1,375 Adjusted net profit (loss) 2,434 1,175 107 3,809 2,628 45 1,279 Net profit (loss) 3,376 561 .. 4,655 1,756 ..

1,071 Net profit (loss) attributable to Eni's shareholders 3,319 543 .. 4,390 1,715 ..

(278) Exclusion of inventory holding (gains) losses (120) 256 .. (398) 246 ..

509 Exclusion of special items ⁽ᵃ⁾ (866) 335 .. (357) 585 ..

1,302 Adjusted net profit (loss) attributable to Eni's shareholders 2,333 1,134 106 3,635 2,546 43Q2 IH (a) For further information see table "Breakdown of special items".

• In 2Q ’26, the Group proforma adjusted EBIT of €5, 38 bln doubled y-o-y due to strong performance at E&P, GGP and the Transition satellites . The factors which drove the Group’s 2Q ’26 performance were better realizations on equity production, higher biofuels margins, better volume/mix effects and the positive outcome of restructuring the chemicals sector and other cost efficiencies.

• In 2Q ’26 adjusted profit before taxes was € 3.86 bln, 75% higher than 2Q ’25, reflecting the trend in the Group adjusted EBIT and higher profits reported at equity -accounted entities , partly offset by increas ed finance expenses. In IH ‘2 6, the Group reported an adjusted profit before taxes of € 6.24 bln, up 26% compared to IH ’2 5.

• In 2Q ’26 adjusted net profit attributable to Eni’s shareholders of €2.33 bln more than doubled compared to 2Q ’25, factoring in a lower adjusted tax rate down to 37% from 47%, due to a better geographical mix of profits before taxes in E&P reflecting higher contribution from jurisdictions with lower -than -average tax rates . In IH ‘2 6, the Group reported an adjusted net profit attributable to Eni’s shareholders of € 3.64 mln, up 43% compared to IH ’2 5.

Group results

13 Net borrowings and cash flow from operations Q1 2026 (€ million) 2026 2025 Change 2026 2025 Change 1,279 Net profit (loss) 3,376 561 2,815 4,655 1,756 2,899 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

1,636 - depreciation, depletion and amortization and other non monetary items 140 1,716 (1,576) 1,776 3,558 (1,782) (5) - net gains on disposal of assets (6) 6 (5) (6) 1 1,161 - dividends, interests and taxes 1,539 950 589 2,700 2,384 316 (1,785) Changes in working capital related to operations 269 1,176 (907) (1,516) 192 (1,708) 290 Dividends received by equity investments 578 512 66 868 879 (11) (855) Taxes paid (1,196) (1,058) (138) (2,051) (2,230) 179 (294) Interests (paid) received (436) (334) (102) (730) (631) (99) 1,427 Net cash provided by operating activities 4,270 3,517 753 5,697 5,902 (205) (1,967) Capital expenditure (2,041) (1,954) (87) (4,008) (3,773) (235) (65) Investments and acquisitions (735) (100) (635) (800) (351) (449) 10 Disposal of consolidated subsidiaries, businesses, tangible and intangible assets and investments (281) 83 (364) (271) 84 (355) 15 Other cash flow related to investing activities 240 (275) 515 255 (175) 430 (580) Free cash flow 1,453 1,271 182 873 1,687 (814) (839) Net cash inflow (outflow) related to financial activities 9 10 (1) (830) (190) (640) 2,356 Changes in short and long-term financial debt 104 (317) 421 2,460 (1,324) 3,784 (342) Repayment of lease liabilities (327) (300) (27) (669) (675) 6 (1,075) Dividends paid, share repurchases, changes in non-controlling interests and reserves (1,452) (458) (994) (2,527) 1,564 (4,091) 960 Issue of perpetual hybrid bond and interest payment (156) (65) (91) 804 126 678 15 Effect of changes in consolidation and exchange differences of cash and cash equivalent 8 (121) 129 23 (204) 227

495 NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENT (361) 20 (381) 134 984 (850)

2,878 Adjusted net cash before changes in working capital at replacement cost 4,469 2,775 1,694 7,347 6,189 1,158 Q1 2026 (€ million) 2026 2025 Change 2026 2025 Change (580) Free cash flow 1,453 1,271 182 873 1,687 (814) (342) Repayment of lease liabilities (327) (300) (27) (669) (675) 6 Net borrowings of acquired companies (9) (9) (9) (9) Net borrowings of divested companies (238) (238) (238) (238) (284) Exchange differences on net borrowings and other changes 307 (312) 619 23 (725) 748 (1,075) Dividends paid and changes in non-controlling interest and reserves (1,452) (458) (994) (2,527) 1,564 (4,091) 960 Issue of perpetual hybrid bond and interest payment (156) (65) (91) 804 126 678

(1,321) CHANGE IN NET BORROWINGS BEFORE LEASE LIABILITIES (422) 136 (558) (1,743) 1,977 (3,720)

342 Repayment of lease liabilities 327 300 27 669 675 (6) (269) Inception of new leases and other changes (141) 193 (334) (410) 70 (480)

(1,248) CHANGE IN NET BORROWINGS AFTER LEASE LIABILITIES (236) 629 (865) (1,484) 2,722 (4,206)Q2

Q2 IH

IH

In IH ’26, net cash provided by operating activities was €5,6 97 mln and included €868 mln of dividends received by Eni’s equity -accounted investments. The amount of trade receivables discounted as part of non -recourse arrangements with financing institutions was ca. €0.2 bln higher than in the Q 4 ‘25 as part of the Group initiatives to optimize working capital requirements.

Adjusted net cash before changes in working capital at replacement cost was € 7,347 mln in IH ’26 (€4,469 mln in the Q2 ’2 6) 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 ;

• accrued post -merger balancing proceeds and other minor items.

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

Q1 2026 (€ million) 2026 2025 Change 2026 2025 Change 1,427 Net cash provided by operating activities 4,270 3,517 753 5,697 5,902 (205) 1,785 Changes in working capital related to operations (269) (1,176) 907 1,516 (192) 1,708 195 Exclusion of commodity derivatives (123) (28) (95) 72 (279) 351 (434) Exclusion of inventory holding (gains) losses (151) 372 (523) (585) 358 (943) 2,973 Net cash before changes in working capital at replacement cost 3,727 2,685 1,042 6,700 5,789 911 (95) Extraordinary (gains) charges and other items 742 90 652 647 400 247 2,878 Adjusted net cash before changes in working capital at replacement cost 4,469 2,775 1,694 7,347 6,189 1,158Q2 IH

In IH ’26 organic capex was € 3.7 bln (down 5% 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 have 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 increased by around €1 .74 bln in the first half of 2026 . The main inflows comprised the adjusted operating cash flow (€7 .35 bln) and the issuance of a hybrid bond (€0.99 bln) which were utilized to fund cash outflows related to organic capex (€3 .71 bln), working capital needs (€1 .52 bln), dividend payments to Eni’s shareholders and share repurchases of €2 .53 bln (dividend payments of €1 .6 bln and share repurchases of €0 .9 bln), acquisition of consolidated subsidiaries and other portfolio activities (€1 bln) and repayment of lease liabilities and hybrid bond interest (€0.85 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. As of Ju ly 17, 2026, around 39 mln shares have been purchased, for a cash outlay of € 860 mln.

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

Fixed assets

Property, plant and equipment 50,536 49,165 (1,371) Right of use 5,184 4,948 (236) Intangible assets 6,022 1,532 (4,490) Inventories - Compulsory stock 1,187 1,655 468 Equity-accounted investments and other investments 14,484 19,170 4,686 Receivables financing and securities held for operating purposes 974 997 23 Net payables related to capital expenditure (1,337) (1,372) (35) 77,050 76,095 (955) Net working capital Inventories 5,143 6,407 1,264 Trade receivables 8,986 9,044 58 Trade payables (13,901) (14,863) (962) Net tax assets (liabilities) 1,506 757 (749) Provisions (14,580) (13,887) 693 Other current assets and liabilities (1,572) (1,183) 389 (14,418) (13,725) 693 Provisions for employee benefits (596) (559) 37 Discontinued operations and assets held for sale including related liabilities 5,979 11,831 5,852

CAPITAL EMPLOYED, NET 68,015 73,642 5,627

Eni's shareholders equity 47,940 52,001 4,061 Non-controlling interest 4,847 4,929 82 Shareholders' equity 52,787 56,930 4,143 Net borrowings before lease liabilities ex IFRS 16 9,528 11,271 1,743 Lease liabilities 5,700 5,441 (259) Net borrowings after lease liabilities ex IFRS 16 15,228 16,712 1,484

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 68,015 73,642 5,627

Gearing before lease liabilities ex IFRS 16 0.15 0.17 Gearing after lease liabilities ex IFRS 16 0.22 0.23

As of June 30 , 202 6, fixed assets (€76.1 bln) decreased by approximately €1 bln from December 31, 202 5, mainly due to the reclassification of Plenitude as discontinued operations in connection with the proposed new shareholding setup which will trigger the demerger . This movement was partly offset by the net effect of the initial recognition of the investment in the new JV Searah, exceeding the book values of the assets contributed to the venture in exchange of a 50% participating interest .

Capital expenditure for the period was offset by DD&A . Positive exchange rate translation differences (the period -end exchange rate of EUR vs. USD was 1.139 down by 3 % compared to 1.176 as of December 31, 202 5) increased the euro reported amounts of dollar -denominated assets for € 1.7 bln.

Net working capital amount was €13.7 bln. Higher inventory book value because of the weighted average cost of supplies in an environment of rising commodity prices and provisions payment were only partially offset by higher trading payables .

Discontinued operations /asset held for sale included Plenitude (€9. 6 bln) and other held -for-sale E&P properties (€2. 2 bln).

Due to termination of the planned disposal process, the 25% interest in Congo LNG project previously stated as held -for-sale, has been reclassified among continuing operations. In doing so, the asset has been restated at its current net book value, thus recognizing a net revaluation gain of ca. € 0.29 bln.

Eni’s s hareholders equity (€52 bln) increased by € 4.1 bln from December 31, 202 5, mainly due to net profit for the period (€4.4 bln) and positive foreign currency translation differences (€ 1.5 bln), partly offset by shareholders remuneration of approximately € 2.4 bln ( dividend s and share buyback).

Non-controlling interests of €4.9 bln included: i) a minority participating interest acquired by the private equity fund KKR in the share capital of Enilive (€ 0.8 bln) as well as the EIP and Ares fund’s interest in Plenitude of € 1.9 bln; ii) a perpetual subordinated hybrid bond (€ 1.7 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.

Net borrowings2 before lease liabilities as of June 30 , 202 6 of €11.3 bln were up by approximately €1.7 bln from December

2 Details on net borrowings are furnished on page 2 4.

16 31, 202 5. Gearing3 - the ratio of net borrowings to net capital employed before lease liabilities - was 17% on June 30 , 202 6.

Considering the portfolio transactions underway, the Group proforma gearing stands at 10%.

Special items

The breakdown of pre-tax special items recorded in operating profit by segment (net charges of €2,4 48 mln and €1,7 69 mln in IH ’26 and Q2 ’26, respectively) is as follows:

• E&P: net charges of €1,757 mln were incurred in IH ’26 (€1,325 mln in Q2 ‘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 consistent with strategy , as well as downward reserves revision s (€1,203 mln and €1,104 mln in IH ’26 and Q2 ’26, respectively); credit loss provisions (€92 mln) and environmental charges (€15 mln and €16 mln in IH ’26 and Q2 ’26, respectively);

• GGP and Power: net charges of €432 mln in IH ’26 (net gains of €28 mln in Q2 ‘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 €314 mln and gain of €95 mln in IH ‘26 and Q2 ’26, respectively). The reclassification of the positive balance of €152 mln (€65 mln in Q2 ‘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 €364 mln (net charges of €152 mln in Q2 ‘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 €409 mln and charge of €1 36 mln in IH ‘26 and Q2 ‘26, respectively);

• Refining, Chemicals and Sites in t ransformation: net charges of €5 34 mln (€2 37 mln in Q2 ’26) mainly related to the write -down of capital expenditures made for compliance and stay -in-business at certain CGU with expected negative cash flows in Refining business (€162 mln and € 94 mln in IH ‘26 and Q2 ’26, respectively) and to the fair values of commodity derivatives lacking the formal criteria to be classified as hedges under IFRS (€178 mln and €15 mln in IH ‘26 and Q2 ’26, respectively) as well as environmental charges of €90 mln (€66 mln in Q2 ’26).

3 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 18 and subsequent.

17 Other information, basis of presentation and disclaimer This press release on Eni’s unaudited results for the second quarter and the first half of 202 6 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 disc losure of results and business trends on a quarterly basis is consi stent 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 first and second quarter of 202 6, the first half of 202 6 and for the second quarter and the first half of 2025. Information on the Company’s financial position relates to end of the periods as of June 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 .

The interim consolidated financial report as at June 30, 202 6 prepared in accordance with Italian listing standards, subject to a limited review by the external auditors is due to be published in the first week of August.

Following Eni’s Board of Directors decision to reorganize the shareholding structure of Eni’s subsidiary Plenitude with a view to derecogniz ing the subsidiary and its controlled entities, from 1Q 2026, Plenitude has been accounted for as discontinued operation ex IFRS 5 in the Group consolidated statutory accounts because it represents a major business line. This means that Plenitude results afte r elimination of intercompany transactions are condensed in a single item of the Group statutory consolidated profit and loss account and reported separately from the resul ts of continuing operations. Since intercompany eliminations continue to work due to the fact that Plenitude remains fully consolidated as of June 30 , 2026, results of both continuing and discontinued operations are not necessarily representative of results as standalone entities. Same con siderations apply to the preparation of the Group statement of cash flows. Comparative periods have been represented accordingly . In the statement of financial position, the accounting of Plenitude does not differ from that of held -for-sale assets. The discontinued results of Plenitude and its controlled entities are assuming that DD&A charges no longer accrue from the month of March 2026 onwards.

Non-GAAP financial measures throughout this press release relating to Plenitude represent the entity on a standalone basis in line with prior periods segment information . For a representation of Plenitude as a discontinued operation see the “Profit and loss account” on page 2 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/201 5/1415), published on October 5, 2015. For further information, see the section “Alternative performance measures (Non ‐GAAP measures)” of this press release.

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 field s 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 areas 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 hydrocarbons and refined products, Eni ’s results from operations and changes in net borrowings 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 second quarter and first half of 202 6 results (not subject to audit) is also available on Eni’s website eni.com.

18 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, which impact industrial margins and translation of commercial payables and receivables. Accordingly, also currency translation effects recorded through profi t 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 based 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 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 through 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)

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

(€ 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 43.4 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) 1,878Impact 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)

Second Quarter 2025

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 1,495 585 53 30 (843) (261) 103 1,162 (30) (652) (682) 480 Exclusion of inventory holding (gains) losses 61 396 (85) 372 372 Exclusion of special items:

environmental charges (expense recovered from third-parties) 6 102 55 163 163 impairment losses (impairment reversals), net 214 6 99 4 323 323 net gains on disposal of assets (3) (3) (6) (6) risk provisions 16 1 17 17 provision for redundancy incentives 4 4 5 13 13 commodity derivatives (27) (99) 1 84 13 (28) (84) 83 (1) (29) exchange rate differences and derivatives (9) (196) 6 1 (198) (198) other (15) 88 11 10 (3) (20) 71 (10) (10) 61 Special items of operating profit (loss) 164 (207) 24 94 234 46 355 (94) 83 (11) 344 Adjusted operating profit (loss) of subsidiaries (a) 1,659 378 138 124 (213) (215) 18 1,889 (124) (569) (693) 1,196 main JV/Associates adjusted EBIT (b) 763 9 (9) 9 20 792 (9) (9) 783 Proforma adjusted EBIT (c)=(a)+(b) 2,422 387 129 133 (193) (215) 18 2,681 (133) (569) (702) 1,979 Finance expenses and dividends of subsidiaries (d) 131 (4) (2) (10) (5) 32 142 10 47 57 199 Finance expenses and dividends of main JV/associates (e) (192) 2 (1) (15) (21) (227) 15 15 (212) Income taxes of main JV/associates (f) (404) (3) (1) 12 (396) 1 1 (395) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 167 8 (10) (7) 11 169 7 7 176 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 1,957 382 126 107 (207) (183) 18 2,200 (107) (522) (629) 1,571 Income taxes (i) (898) (147) (50) (39) 10 103 (4) (1,025) 39 (2) 37 (988) Tax rate (%) 46.6 Adjusted net profit (loss) (j)=(h)+(i) 1,059 235 76 68 (197) (80) 14 1,175 (68) (524) (592) 583

of which:

- Adjusted net profit (loss) of non-controlling interest 41 (60) (19)

- Adjusted net profit (loss) attributable to Eni's shareholders 1,134 (532) 602 Reported net profit (loss) attributable to Eni's shareholders 543 (545) (2) Exclusion of inventory holding (gains) losses 256 256 Exclusion of special items 335 13 348 Adjusted net profit (loss) attributable to Eni's shareholders 1,134 (532) 602Impact 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

20

(€ million)

First Half 2026

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 3,502 381 375 826 (302) (615) (96) 4,071 (826) (1,363) (2,189) 1,882 Exclusion of inventory holding (gains) losses (35) (555) 5 (585) (585) Exclusion of special items:

environmental charges 15 48 90 (10) 143 143 impairment losses (impairment reversals), net 1,203 11 187 73 1,474 1,474 net gains on disposal of assets (5) (5) (5) risk provisions 11 1 1 6 19 19 provision for redundancy incentives 9 1 1 2 12 7 32 (2) (2) 30 commodity derivatives (11) 314 14 (423) 178 72 423 (425) (2) 70 exchange rate differences and derivatives 27 152 (2) 16 193 193 other 508 (35) (10) (6) 50 13 520 6 6 526 Special items of operating profit (loss) 1,757 432 63 (427) 534 89 2,448 427 (425) 22,450 Adjusted operating profit (loss) of subsidiaries (a) 5,259 813 403 399 (323) (526) (91) 5,934 (399) (1,788) (2,187) 3,747 main JV/Associates adjusted EBIT (b) 2,867 17 30 40 23 2,977 (40) (40) 2,937 Proforma adjusted EBIT (c)=(a)+(b) 8,126 830 433 439 (300) (526) (91) 8,911 (439) (1,788) (2,227) 6,684 Finance expenses and dividends of subsidiaries (d) (183) (9) (14) (2) 5 (321) (524) 2 (12) (10) (534) Finance expenses and dividends of main JV/associates (e) (449) 6 (5) (39) (31) (518) 39 39 (479) Income taxes of main JV/associates (f) (1,627) (6) (5) 4 (1,634) 5 5(1,629) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 791 17 25 (4) (4) 825 4 4 829 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 5,867 821 414 393 (322) (847) (91) 6,235 (393) (1,800) (2,193) 4,042 Income taxes (i) (2,138) (306) (113) (129) 6 224 30 (2,426) 129 (11) 118 (2,308) Tax rate (%) 38.9 57.1 Adjusted net profit (loss) (j)=(h)+(i) 3,729 515 301 264 (316) (623) (61) 3,809 (264) (1,811) (2,075) 1,734

of which:

- Adjusted net profit (loss) of non-controlling interest 174 (626) (452)

- Adjusted net profit (loss) attributable to Eni's shareholders 3,635 (1,449) 2,186 Reported net profit (loss) attributable to Eni's shareholders 4,390 (1,367) 3,023 Exclusion of inventory holding (gains) losses (398) (398) Exclusion of special items (357) (82) (439) Adjusted net profit (loss) attributable to Eni's shareholders 3,635 (1,449) 2,186Exploration &

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)

First Half 2025

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 3,446 1,358 174 64 (1,302) (539) 289 3,490 (64) (2,375) (2,439) 1,051 Exclusion of inventory holding (gains) losses 42 427 (111) 358 358 Exclusion of special items:

environmental charges (expense recovered from third-parties) (2) 22 117 55 192 192 impairment losses (impairment reversals), net 469 5 159 8 641 641 net gains on disposal of assets (3) (3) (6) (6) risk provisions 16 1 17 17 provision for redundancy incentives 9 1 7 17 34 34 commodity derivatives (19) (342) 1 292 15 (53) (292) 290 (2) (55) exchange rate differences and derivatives 15 (297) (1) 3 1 (279) (279) other (26) 122 4 10 5 (20) 95 (10) (10) 85 Special items of operating profit (loss) 443 (517) 32 302 319 62 641 (302) 290 (12) 629 Adjusted operating profit (loss) of subsidiaries (a) 3,889 841 248 366 (556) (477) 178 4,489 (366) (2,085) (2,451) 2,038 main JV/Associates adjusted EBIT (b) 1,841 19 (24) 8 29 1,873 (8) (8) 1,865 Proforma adjusted EBIT (c)=(a)+(b) 5,730 860 224 374 (527) (477) 178 6,362 (374) (2,085) (2,459) 3,903 Finance expenses and dividends of subsidiaries (d) 29 (9) (8) (13) (5) (16) (22) 13 71 84 62 Finance expenses and dividends of main JV/associates (e) (322) 5 (3) (24) (41) (385) 24 24 (361) Income taxes of main JV/associates (f) (1,024) (4) (1) 23 (1,006) 1 1(1,005) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 495 20 (27) (17) 11 482 17 17 499 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 4,413 852 213 336 (550) (493) 178 4,949 (336) (2,014) (2,350) 2,599 Income taxes (i) (2,041) (310) (72) (113) 43 222 (50) (2,321) 113 (7) 106 (2,215) Tax rate (%) 46.9 Adjusted net profit (loss) (j)=(h)+(i) 2,372 542 141 223 (507) (271) 128 2,628 (223) (2,021) (2,244) 384

of which:

- Adjusted net profit (loss) of non-controlling interest 82 (187) (105)

- Adjusted net profit (loss) attributable to Eni's shareholders 2,546 (2,057) 489 Reported net profit (loss) attributable to Eni's shareholders 1,715 (2,121) (406) Exclusion of inventory holding (gains) losses 246 246 Exclusion of special items 585 64 649 Adjusted net profit (loss) attributable to Eni's shareholders 2,546 (2,057) 489Exploration &

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

21

(€ million)

First Quarter 2026

Plenitude

Infragroup

elimination

TOTAL

Reported operating profit (loss) 1,851 (142) 183 774 (173) (302) (18) 2,173 (774) (694) (1,468) 705 Exclusion of inventory holding (gains) losses (105) (404) 75 (434) (434) Exclusion of special items:

environmental charges (1) 17 24 40 40 impairment losses (impairment reversals), net 99 5 79 4 187 187 net gains on disposal of assets (5) (5) (5)

risk provisions

provision for redundancy incentives 3 1 1 1 6 4 16 (1) (1) 15 commodity derivatives 168 409 37 (582) 163 195 582 (581) 1 196 exchange rate differences and derivatives 31 87 5 123 123 other 137 (37) (2) 7 20 (2) 123 (7) (7) 116 Special items of operating profit (loss) 432 460 58 (574) 297 6 679 574 (581) (7) 672 Adjusted operating profit (loss) of subsidiaries (a) 2,283 318 136 200 (280) (296) 57 2,418 (200) (1,275) (1,475) 943 main JV/Associates adjusted EBIT (b) 1,074 9 2 13 20 1,118 (13) (13) 1,105 Proforma adjusted EBIT (c)=(a)+(b) 3,357 327 138 213 (260) (296) 57 3,536 (213) (1,275) (1,488) 2,048 Finance expenses and dividends of subsidiaries (d) (84) (4) (8) 9 3 (177) (261) (9) (9) (18) (279) Finance expenses and dividends of main JV/associates (e) (214) 4 (3) (19) (17) (249) 19 19 (230) Income taxes of main JV/associates (f) (661) (3) 1 15 (648) (1) (1) (649) Adjusted net profit (loss) of main JV/associates (g)=(b)+(e)+(f) 199 10 (1) (5) 18 221 5 5 226 Adjusted profit (loss) before taxes (h)=(a)+(d)+(g) 2,398 324 127 204 (259) (473) 57 2,378 (204) (1,284) (1,488) 890 Income taxes (i) (918) (120) (34) (70) 30 123 (14) (1,003) 70 (6) 64 (939) Tax rate (%) 42.2 Adjusted net profit (loss) (j)=(h)+(i) 1,480 204 93 134 (229) (350) 43 1,375 (134) (1,290) (1,424) (49)

of which:

- Adjusted net profit (loss) of non-controlling interest 73 (430) (357)

- Adjusted net profit (loss) attributable to Eni's shareholders 1,302 (994) 308 Reported net profit (loss) attributable to Eni's shareholders 1,071 (875) 196 Exclusion of inventory holding (gains) losses (278) (278) Exclusion of special items 509 (119) 390 Adjusted net profit (loss) attributable to Eni's shareholders 1,302 (994) 308Exploration &

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

Breakdown of special items Q1 2026 (€ million) 2026 2025 2026 2025 40 Environmental charges 103 163 143 192 187 Impairment losses (impairment reversals), net 1,287 323 1,474 641 (5) Net gains on disposal of assets (6) (5) (6) Risk provisions 19 17 19 17 16 Provisions for redundancy incentives 16 13 32 34 195 Commodity derivatives (123) (28) 72 (53) 123 Exchange rate differences and derivatives 70 (198) 193 (279) 123 Other 397 71 520 95 679 Special items of operating profit (loss) 1,769 355 2,448 641 (126) Net finance (income) expense (75) 190 (201) 269

of which:

(123) - exchange rate differences and derivatives reclassified to operating profit (loss) (70) 198 (193) 279 (52) Net income (expense) from investments (2,384) (122) (2,436) (154)

of which:

- net gain on business combination (2,088) (2,088) (105) Income taxes (146) (75) (251) (140) 396 Total special items of net profit (loss) (836) 348 (440) 616

attributable to:

509 - Eni's shareholders (866) 335 (357) 585 (113) - Non-controlling interest 30 13 (83) 31Q2 IH

22 Reconciliation of Group proforma adjusted EBIT Q1 2026(€ million)2026 2025 % Ch. 2026 2025 % Ch.

2,283 E&P adjusted Ebit of consolidated subsidiaries 2,976 1,659 79 5,259 3,889 35 1,074 main JV/Associates adjusted Ebit 1,793 763 .. 2,867 1,841 56 3,357 E&P proforma adjusted Ebit 4,769 2,422 97 8,126 5,730 42 318 GGP and Power adjusted Ebit of consolidated subsidiaries 495 378 31 813 841 (3) 9 main JV/Associates adjusted Ebit 8 9 (11) 17 19 (11) 327 GGP and Power proforma adjusted Ebit 503 387 30 830 860 (3) 336 Transition Businesses adjusted Ebit of consolidated subsidiaries 466 262 78 802 614 31 15 main JV/Associates adjusted Ebit 55 .. 70 (16) ..

351 Transition Businesses proforma adjusted Ebit 521 262 99 872 598 46 (280) Refining, Chemicals and Sites in transformation adjusted Ebit of consolidated subsidiaries (43) (213) 80 (323) (556) 42 20 main JV/Associates adjusted Ebit 3 20 (85) 23 29 (21) (260) Refining, Chemicals and Sites in transformation proforma adjusted Ebit (40) (193) 79 (300) (527) 43 (296) Other segments adjusted Ebit (230) (215) (7) (526) (477) (10) 57 Impact of unrealized intragroup profit elimination (148) 18 .. (91) 178 ..

3,536 Group proforma adjusted Ebit ⁽ᵃ⁾ 5,375 2,681 .. 8,911 6,362 40Q2 IH (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

1,898 (151) 1,699 70 3,516 Operating profit 4,071 (585) 2,255 193 5,934 (191) (5) (70) (266) Finance income (expense) (379) (8) (193) (580) 2,991 (2,384) 607 Income (expense) from investments 3,317 (2,436) 881 (1,322) 45 (146) (1,423) Income taxes (2,354) 179 (251) (2,426) 3,376 (106) (836) 2,434 Net profit 4,655 (406) (440) 3,809 57 14 30 101 - Non-controlling interest 265 (8) (83) 174 3,319 (120) (866) 2,333 Net profit attributable to Eni's shareholders 4,390 (398) (357) 3,635IH Second 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

1,162 372 553 (198) 1,889 Operating profit 3,490 358 920 (279) 4,489 (161) (8) 198 29 Finance income (expense) (410) (10) 279 (141) 404 (122) 282 Income (expense) from investments 755 (154) 601 (844) (106) (75) (1,025) Income taxes (2,079) (102) (140) (2,321) 561 266 348 1,175 Net profit 1,756 256 616 2,628 18 10 13 41 - Non-controlling interest 41 10 31 82 543 256 335 1,134Net profit attributable to Eni's shareholders1,715 246 585 2,546IH Second Quarter

23

2026

(€ million)Reported

results

Profit on

stock

Special

items

Finance

expense

reclassifiedAdjusted

results

Operating profit 2,173 (434) 556 123 2,418 Finance income (expense) (188) (3) (123) (314) Income (expense) from investments 326 (52) 274 Income taxes (1,032) 134 (105) (1,003) Net profit 1,279 (300) 396 1,375

- Non-controlling interest 208 (22) (113) 73 Net profit attributable to Eni's shareholders 1,071 (278) 509 1,302Q1

Sales from operations Q1 2026(€ million)2026 2025 % Ch. 2026 2025 % Ch.

13,738 Exploration & Production 16,579 11,881 40 30,317 24,942 22 5,375 Global Gas & LNG Portfolio and Power 4,058 3,444 18 9,433 9,034 4 4,757 Enilive 6,917 4,779 45 11,674 9,536 22 4,112 Refining, Chemicals and Sites in transformation 6,441 4,533 42 10,553 9,465 11 456 Corporate and other activities 476 510 (7) 932 979 (5) (8,696) Consolidation adjustments (12,157) (8,253) (47) (20,853) (18,204) (15)

19,742 22,314 16,894 32 42,056 35,752 18Q2 IH

Operating expenses

Q1 2026(€ million) 2026 2025 % Ch. 2026 2025 % Ch.

16,123 Purchases, services and other 17,806 14,086 26 33,929 30,054 13 50 Impairment losses (impairment reversals) of trade and other receivables, net 51 36 42 101 73 38 823 Payroll and related costs 759 753 1 1,582 1,554 2 15 of which: provision for redundancy incentives and other 15 13 15 30 34 (12)

16,996 18,616 14,875 25 35,612 31,681 12Q2 IH

DD&A, impairments, reversals and write -off Q1 2026(€ million)2026 2025 var % 2026 2025 % Ch.

1,433 Exploration & Production 1,514 1,501 1 2,947 3,065 (4) 48 Global Gas & LNG Portfolio and Power 42 66 (36) 90 132 (32) 73 Enilive 76 75 1 149 145 3 35 Refining, Chemicals and Sites in transformation 38 37 3 73 75 (3) 39 Corporate and other activities 40 39 3 79 77 3 (9) Impact of unrealized intragroup profit elimination (8) (8) - (17) (16) (6) 1,619 Total depreciation, depletion and amortization 1,702 1,710 - 3,321 3,478 (5) 187Impairment losses (impairment reversals) of tangible and intangible and right of use assets, net1,287 323 .. 1,474 641 ..

1,806 Depreciation, depletion, amortization, impairments and reversals 2,989 2,033 47 4,795 4,119 16 6 Write-off of tangible and intangible assets 113 (11) .. 119 (14) ..

1,812 3,102 2,022 53 4,914 4,105 20IH Q2

Income (expense) from investments Analysis of Profit and Loss account items – continuing operations

24

(€ million)

First Half 2026Exploration & ProductionGlobal Gas &

LNG Portfolio

and PowerEniliveRefining,

Chemicals and

Sites in

transformationCorporate and

other activitiesGroup

Share of profit (loss) from equity-accounted investments 1,060 16 47 88 (39) 1,172 Dividends 36 3 1 20 60 Other income (expense), net 2,088 1 (3) 2,086 3,184 17 50 89 (22) 3,318

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 Jun. 30, 2026 Change Total debt 28,464 31,522 3,058

- Short-term debt 8,363 7,722 (641)

- Long-term debt 20,101 23,800 3,699 Cash and cash equivalents (8,100) (8,365) (265) Financial assets measured at fair value through profit or loss (6,991) (6,723) 268 Financing receivables held for non-operating purposes (3,845) (5,163) (1,318) Net borrowings before lease liabilities ex IFRS 16 9,528 11,271 1,743 Lease Liabilities 5,700 5,441 (259) Net borrowings after lease liabilities ex IFRS 16 15,228 16,712 1,484 Shareholders' equity including non-controlling interest 52,787 56,930 4,143 Gearing before lease liability ex IFRS 16 0.15 0.17 Gearing after lease liability ex IFRS 16 0.22 0.23

Gearing and net borrowings

25

BALANCE SHEET Consolidated financial statements

26

(€ million)

Jun. 30, 2026 Dec. 31, 2025

ASSETS

Current assets

Cash and cash equivalents 8,365 8,100 Financial assets measured at fair value through profit or loss 6,723 6,991 Other financial assets 5,034 3,710 Trade and other receivables 12,407 12,436 Inventories 6,407 5,143 Income tax assets 820 539 Other assets 3,413 3,943

43,169 40,862

Non-current assets

Property, plant and equipment 49,165 50,536 Right of use assets 4,948 5,184 Intangible assets 1,532 6,022 Inventory - compulsory stock 1,655 1,187 Equity-accounted investments 17,743 13,155 Other investments 1,427 1,329 Other financial assets 1,126 1,109 Deferred tax assets 6,084 6,716 Income tax assets 125 125 Other assets 1,498 2,839

85,303 88,202

Assets held for sale 18,533 8,005

TOTAL ASSETS 147,005 137,069

LIABILITIES AND SHAREHOLDERS' EQUITY

Current liabilities

Short-term debt 5,334 4,929 Current portion of long-term debt 2,388 3,434 Current portion of long-term lease liabilities 1,083 1,263 Trade and other payables 19,979 20,261 Income taxes payable 420 343 Other liabilities 5,798 4,039

35,002 34,269

Non-current liabilities

Long-term debt 23,827 20,139 Long-term lease liabilities 4,358 4,437 Provisions for contingencies 13,887 14,580 Provisions for employee benefits 559 596 Deferred tax liabilities 4,222 4,805 Income taxes payable 25 40 Other liabilities 1,493 3,390

48,371 47,987

Liabilities directly associated with assets held for sale 6,702 2,026

TOTAL LIABILITIES 90,075 84,282

Share capital 4,005 4,005 Retained earnings 33,364 33,209 Cumulative currency translation differences 3,470 1,936 Other reserves and equity instruments 8,634 8,964 Treasury shares (1,862) (2,782) Net profit (loss) 4,390 2,608 Total Eni shareholders' equity 52,001 47,940 Non-controlling interest 4,929 4,847

TOTAL SHAREHOLDERS' EQUITY 56,930 52,787

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 147,005 137,069

GROUP PROFIT AND LOSS ACCOUNT

27 Q1

2026 (€ million) 2026 2025 2026 2025

CONTINUING OPERATIONS

19,742 Sales from operations 22,314 16,894 42,056 35,752 319 Other income and revenues 354 321 673 649 20,061 Total revenues 22,668 17,215 42,729 36,401 (16,123) Purchases, services and other (17,806) (14,086) (33,929) (30,054) (50) Impairment reversals (impairment losses) of trade and other receivables, net (51) (36) (101) (73) (823) Payroll and related costs (759) (753) (1,582) (1,554) (548) Other operating (expense) income 227 162 (321) 436 (1,619) Depreciation, Depletion and Amortization (1,702) (1,710) (3,321) (3,478) (187) Impairment reversals (impairment losses) of tangible, intangible and right of use assets, net (1,287) (323) (1,474) (641) (6) Write-off of tangible and intangible assets (113) 11 (119) 14

705 OPERATING PROFIT (LOSS) 1,177 480 1,882 1,051

1,482 Finance income 1,735 3,111 3,217 5,359 (1,641) Finance expense (2,066) (3,267) (3,707) (5,729) 13 Net finance income (expense) from financial assets measured at fair value through profit or loss 82 54 95 111 (52) Derivative financial instruments 61 (3) 9 (70)

(198) FINANCE INCOME (EXPENSE) (188) (105) (386) (329)

283 Share of profit (loss) of equity-accounted investments 889 311 1,172 669 40 Other gain (loss) from investments 2,106 101 2,146 106

323 INCOME (EXPENSE) FROM INVESTMENTS 2,995 412 3,318 775

830 PROFIT (LOSS) BEFORE INCOME TAXES 3,984 787 4,814 1,497

(805) Income taxes (1,312) (832) (2,117) (2,056) 25 Net profit (loss) - continuing operations 2,672 (45) 2,697 (559)

DISCONTINUED OPERATIONS

1,254 Net profit (loss) - discontinued operations 704 606 1,958 2,315

TOTAL GROUP

1,279 Net profit (loss) 3,376 561 4,655 1,756

attributable to:

1,071 - Eni's shareholders 3,319 543 4,390 1,715 196 - continuing operations 2,827 (2) 3,023 (406) 875 - discontinued operations 492 545 1,367 2,121 208 - Non-controlling interest 57 18 265 41 (171) - continuing operations (155) (43) (326) (153) 379 - discontinued operations 212 61 591 194 Net profit (loss) per share attributable to Eni's shareholders (€ per share) 0.34 - basic 1.11 0.16 1.45 0.52 0.34 - diluted 1.09 0.16 1.42 0.52 Net profit (loss) per share - continuing operations attributable to Eni's shareholders (€ per share) 0.04 - basic 0.94 (0.02) 0.98 (0.17) 0.04 - diluted 0.92 (0.02) 0.97 (0.17) Weighted average number of shares outstanding (million) 2,945.5 - basic 2,934.6 3,049.7 2,940.0 3,056.2 3,008.8 - diluted 3,000.2 3,112.3 3,005.6 3,118.8 Q2 IH Discontinued operations related to Plenitude and its subsidiaries. Results of continued and discontinued d id not reflect entities’ standalone results , because intercompany eliminations were still applied since Plenitude is fully consolidated as of June 30, 2026. Particularly, the continuing operations are supplying Plenitude with significant volumes of gas and this intercompany transaction was eliminated thus reducing results of the selling segment and correspondingly increasing the one of the buying segme nt.

COMPREHENSIVE INCOME (LOSS)

28 (€ million) 2026 2025 2026 2025 Net profit (loss) 3,376 561 4,655 1,756 Items that are not reclassified to profit or loss in later periods 9 3 10 5 Share of other comprehensive income on equity accounted entities 1 Change in the fair value of interests with effects on other comprehensive income 9 3 9 5

Taxation

Items that may be reclassified to profit in later periods 883 (3,833) 1,213 (5,519) Currency translation differences 448 (3,974) 1,600 (6,063) Change in the fair value of cash flow hedging derivatives 485 151 (482) 732 Share of other comprehensive income on equity-accounted entities 96 35 (56) 24 Taxation (146) (45) 151 (212) Total other items of comprehensive income (loss) 892 (3,830) 1,223 (5,514) Total comprehensive income (loss) 4,268 (3,269) 5,878 (3,758)

attributable to:

- Eni's shareholders 4,182 (3,123) 5,528 (3,549)

- continuing operations 3,665 (3,624) 4,104 (5,600)

- discontinued operations 517 501 1,424 2,051

- Non-controlling interest 86 (146) 350 (209)

- continuing operations (138) (201) (266) (395)

- discontinued operations 224 55 616 186IH Q2

CHANGES IN SHAREHOLDERS’ EQUITY

29

(€ million)

Shareholders' equity at January 1, 2025 55,648 Total comprehensive income (loss) (3,758) Dividends paid to Eni's shareholders (1,528) Dividends distributed by consolidated subsidiaries (63) Net purchase of treasury shares (660) 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 10 Plenitude transaction - disposal to EIP 209 Put option on Plenitude (139) Enilive transaction - disposal to KKR 3,569 Other changes (1) Total changes (2,243) Shareholders' equity at June 30, 2025 53,405

attributable to:

- Eni's shareholders 49,738

- Non-controlling interest 3,667 Shareholders' equity at January 1, 2026 52,787 Total comprehensive income (loss) 5,878 Dividends paid to Eni's shareholders (1,558) Dividends distributed by consolidated subsidiaries (153) Net purchase of treasury shares (880) Issue of hybrid bonds 1,000 Coupon of perpetual subordinated bonds and Enimarine (184) Taxes on hybrid bond coupon and costs 37 Other changes 3 Total changes 4,143 Shareholders' equity at June 30, 2026 56,930

attributable to:

- Eni's shareholders 52,001

- Non-controlling interest 4,929

GROUP CASH FLOW STATEMENT

30 Q1

2026(€ million)2026 2025 2026 2025 25 Net profit (loss) - continuing operations 2,672 (45) 2,697 (559) 1,254 Net profit (loss) - discontinued operations 704 606 1,958 2,315 1,279 Net profit (loss) 3,376 561 4,655 1,756 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

1,696 Depreciation, depletion and amortization 1,702 1,823 3,398 3,696 187 Impairment losses (impairment reversals) of tangible, intangible and right of use, net 1,287 323 1,474 641 6 Write-off of tangible and intangible assets 114 (10) 120 (13) (276) Share of (profit) loss of equity-accounted investments (882) (303) (1,158) (649) (5) Gains on disposal of assets, net (6) (5) (6) (43) Dividend income (17) (100) (60) (100) (102) Interest income (121) (94) (223) (202) 274 Interest expense 355 300 629 607 1,032 Income taxes 1,322 844 2,354 2,079 (13) Other changes (2,064) (103) (2,077) (125) (1,785) Cash flow from changes in working capital 269 1,176 (1,516) 192 (529) - inventories (1,200) (38) (1,729) 401 (3,893) - trade receivables 2,660 2,868 (1,233) 2,655 3,236 - trade payables (1,442) (1,545) 1,794 (2,437) (353) - provisions for contingencies (70) (276) (423) (439) (246) - other assets and liabilities 321 167 75 12 36 Net change in the provisions for employee benefits (17) (14) 19 8 290 Dividends received 578 512 868 879 38 Interest received 49 52 87 117 (332) Interest paid (485) (386) (817) (748) (855) Income taxes paid, net of tax receivables received (1,196) (1,058) (2,051) (2,230) 1,427 Net cash provided by operating activities 4,270 3,517 5,697 5,902 (2,093) Cash flow from investing activities (2,981) (2,433) (5,074) (4,535) (2,364) - tangible assets (2,114) (2,021) (4,478) (3,707) (69) - intangible assets (94) (125) (163) (258)

- consolidated subsidiaries and businesses net of cash and cash equivalent acquired (499) (499) (65) - investments (236) (100) (301) (351) (25) - securities and financing receivables held for operating purposes (8) (23) (33) (35) 430 - change in payables in relation to investing activities (30) (164) 400 (184) 86 Cash flow from disposals 164 187 250 320 10 - tangible assets 2 65 12 66

- consolidated subsidiaries and businesses net of cash and cash equivalent disposed of 38 38

- investments 27 18 27 18 1 - securities and financing receivables held for operating purposes 42 4 43 16 75 - change in receivables in relation to disposals 55 100 130 220 (839) Net change in receivables and securities not held for operating purposes 9 10 (830) (190) (2,846) Net cash used in investing activities (2,808) (2,236) (5,654) (4,405)IH Q2

GROUP CASH FLOW STATEMENT (continued)

31 Q1

2026(€ million) 2026 2025 2026 2025 2,295 Increase in long-term debt 2,821 2,223 5,116 3,721 (1,729) Payment of long-term debt (1,177) (1,985) (2,906) (4,803) (342) Payment of lease liabilities (327) (300) (669) (675) 1,790 Increase (decrease) in short-term financial debt (1,540) (555) 250 (242) (766) Dividends paid to Eni's shareholders (786) (759) (1,552) (1,524) (20) Dividends paid to non-controlling interests (106) (20) (126) (33) Net capital issuance from non-controlling interest 709 Disposal (acquisition) of additional interests in consolidated subsidiaries 601 3,069 (289) Net purchase of treasury shares (560) (280) (849) (666) 988 Issue (repayment) of perpetual hybrid bonds 988 231 Other contributions 9 (28) Interest payment of perpetual hybrid bond (156) (65) (184) (105) 1,899 Net cash used in financing activities (1,831) (1,140) 68 (309) 15 Effect of exchange rate changes on cash and cash equivalents and other changes 8 (121) 23 (204) 495 Net increase (decrease) in cash and cash equivalents (361) 20 134 984 8,421 Cash and cash equivalents - beginning of the period 8,916 9,147 8,421 8,183 8,916 Cash and cash equivalents - end of the period 8,555 9,167 8,555 9,167IH Q2

Capital expenditure

Q1 2026 (€ million) 2026 2025 var % 2026 2025 % Ch.

1,615 Exploration & Production 1,526 1,336 14 3,141 2,775 13 168 of which: - exploration 97 79 23 265 166 60 1,442 - oil & gas development 1,418 1,241 14 2,860 2,586 11 8 Global Gas & LNG Portfolio and Power 14 25 (44) 22 37 (41)

- Global Gas & LNG Portfolio 2 9 2 9 (78) 8 - Power 12 16 (25) 20 28 (29) 164 Transition Businesses 174 264 (34) 338 441 63 - Enilive 56 68 (18) 119 101 18 101 - Plenitude 118 196 (40) 219 340 158 Refining, Chemicals and Sites in transformation 282 175 61 440 288 53 137 - Refining 247 132 87 384 206 86 17 - Chemicals 27 43 (37) 44 82 (46) 4 - Sites in transformation 8 12 34 Corporate and other activities 44 153 (71) 78 253 (69) (12) Impact of unrealized intragroup profit elimination 1 1 (11) (21) 48 1,967 Capital expenditure ⁽ᵃ⁾ 2,041 1,954 4 4,008 3,773 6Q2 IH (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 are not reported in the table above (€289 mln and €327 mln in the second quarter 2026 and 2025, respectively, €561 mln and €753 mln in the first half 2026 and the first half 2025, respectively and €272 mln in the first quarter 2026).

In the IH ’26, capital expenditure amounted to €4,008 mln (€3,773 mln in the IH ’25) increasing by 6% y -o-y, in particular:

• in the Exploration & Production, capital expenditure (€ 3,141 mln) was mainly related to oil&gas development activities in particular in Libya, Congo, Egypt, Indonesia, Italy, the United Arab Emirates, Algeria and Iraq ;

• in the Transition Businesses segment, Plenitude’s capital expenditure (€ 219 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 (€ 119 mln) mainly related to biorefining projects (Venice EcofiningTM 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 (€ 384 mln) specifically to the reconversion of Livorno in biorefinery, maintenance and stay -in-business, as well as to the chemical business (€ 44 mln) and regarded the circular economy and asset integrity;

• in the Corporate and other activities mainly related to the CCUS and agri -business projects (€ 13 mln).

Exploration & Productio n

32

PRODUCTION OF OIL AND NATURAL GAS BY REGION

Q1 2026 2026 2025 2026 2025

62 Italy (kboe/d) 57 65 59 69 321 Rest of Europe 300 243 311 240 534 North Africa 529 515 531 521 396 Sub-Saharan Africa 404 336 400 329 344 Asia 342 369 343 371 141 Americas 157 132 149 124

- Australia and Oceania - 8 - 4 1,798 Production of oil and natural gas ⁽ᵃ⁾⁽ᵇ⁾⁽ᶜ⁾⁽ᵈ⁾ 1,789 1,668 1,793 1,658 525 - of which Joint Ventures and associates 566 432 546 432 141 Production sold ⁽ᵃ⁾ (mmboe) 145 136 286 269

PRODUCTION OF LIQUIDS BY REGION

Q1 2026 2026 2025 2026 2025

26 Italy (kbbl/d) 23 26 25 26 203 Rest of Europe 185 150 194 145 171 North Africa 176 173 173 171 192 Sub-Saharan Africa 185 194 189 188 194 Asia 174 214 184 214 76 Americas 89 68 82 61

- Australia and Oceania - - - -

862 Production of liquids 832 825 847 805 296 - of which Joint Ventures and associates 282 238 289 233

PRODUCTION OF NATURAL GAS BY REGION

Q1 2026 2026 2025 2026 2025

186 Italy (mmcf/d) 175 208 180 223 617 Rest of Europe 603 487 610 500 1,894 North Africa 1,848 1,786 1,871 1,828 1,068 Sub-Saharan Africa 1,145 745 1,107 736 784 Asia 878 811 832 819 344 Americas 357 338 350 329

- Australia and Oceania - 40 - 23 4,893 Production of natural gas 5,006 4,415 4,950 4,458 1,198 - of which Joint Ventures and associates 1,487 1,019 1,343 1,041 Q2 IH

Q2 IH

Q2 IH

(a) Includes Eni’s share of production of equity-accounted entities.

(b)Includes volumes ofhydrocarbons consumed inoperation (150 and 133 kboe/d inthesecond quarter of2026 and 2025, respectively, 160 and 132 kboe/d inthefirst half of2026 and 2025, respectively, and 170 kboe/d in the first quarter of 2026).

(c) In the second quarter 2026 and in the first half 2026, it includes 78 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’s total 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”.

33

Sustainability performance

First Half First Half

2026 2025

Total Recordable Injury Rate (TRIR) (total recordable injuries/worked hours) x 1,000,0000.53 0.48 Direct GHG emissions (Scope 1) (mmtonnes CO ₂ eq.)8.0 9.5 Direct methane emissions (Scope 1) (ktonnes CH ₄) 5.8 8.3 Volumes of hydrocarbon sent to routine flaring (billion Sm³) 0.0 0.0 Volume of oil spills due to sabotage (>1 barrel) (bbl) 75 0 Volume of operational oil spills (>1 barrel)931 11 Re-injected production water (%) 59 55 KPIs refer to 100% of the operated assets, consolidated and unconsolidated.

• Total recordable injury rate (TRIR) of the workforce amounted to 0.53, the increase compared to IH ’25 was due to a higher number of incidents involving contractors . Conversely, among employees, both the related rate and number of incidents significantly decreased . No fatal incidents or incidents resulting in disability were recorded during the period.

• Direct GHG emissions (Scope 1): decreasing compared to IH ‘25, in line with Eni’s decarbonization commitments. Main reductions were attributable to E&P (flaring reduction activities and portfolio trans actions), refining (maintenance shutdowns) and chemicals (the Versalis transformation plan and new operating configuration at the Brindisi and Priolo sites).

• Direct methane emissions (Scope 1): lower than IH ‘25 in the E&P, mainly due to the reduction of non -routine flaring and portfolio trans actions .

• Volumes of hydrocarbon sent to routine flaring: in IH ’26 confirmed the zero routine flaring for operated assets.

• Volume of oil spills : operational oil spills increased vs. IH ‘25, despite a reduction in the number of incidents. During the period, one oil spill incident related to acts of sabotage was recorded in Italy (no incidents were recorded in the IH ‘25).

• Re-injected production water increased compared with IH ‘25 (59% vs. 55%), driven by higher volumes re-injected particularly in Mexico and the Netherlands.