Interim Consolidated Report as of June 30, 2026

Interim

Consolidated Report

as of

June 30, 2026

We are an energy company.

We concretely support a just energy transition, with the objective of preserving our planet and promoting an ef cient and sustainable access to energy for all.

Our work is based on passion and innovation, on our unique strengths and skills, on the equal dignity of each person, recognizing diversity as a key value for human development, on the responsibility, integrity and transparency of our actions. We believe in the value of long-term partnerships with the Countries and communities where we operate, bringing long-lasting prosperity for all.Mission Global goals for a sustainable development Development Goals (SDGs) which represent the common targets of sustainable development on the current complex social problems. These goals are an important reference for the international community and Eni in managing activities in those Countries in which it operates.

Eni Interim Consolidated Report as of June 30, 2026

Disclaimer

This report contains certain forward-looking statements in particular under the section “Outlook” regarding capital expenditures, dividends, buy-back programs, allocation of future cash flow from operations, financial structure evolution, future operating performance, targets of production and sale growth 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 that 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 timing of brin ging new oil and gas fields on stream;

management’s ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and oil and natural gas pricing; operational problems; general macroeconomic 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.

“Eni” means the parent company Eni SpA and its consolidated subsidiaries.

For the Glossary see website eni.com.

1.INTERIM CONSOLIDATED REPORT Contents

Highlights

Key operating and financial results

Operating review

Financial re view and other information

2. CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

Financial statements

Notes to the condensed consolidated interim financial statements

Management's certification

Report of Independent Auditors

3. ANNEX

List of companies owned by Eni SpA as of June 30, 202 6 Changes in the scope of consolidation for the first half 4 6 7 21 54 60 97 98 101 102

INTERIM

CONSOLIDATED REPORT

Highlights

Key operating and financial results

OPERATING REVIEW

FINANCIAL REVIEW AND OTHER INFORMATION

Financial review

Risk factors and uncertainties Outlook

Other information 4 6 7 10 13 14 21 44 51 51Exploration & Production Global Gas & LNG Portfolio and Power

Enilive

Plenitude

Refining,

Chemicals and Sites in transformation

ESG Performance

and Initiatives 17 19

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ENI INTERIM CONSOLIDATED REPORT 2026

Highlights

Strategic and financial highlights

E&P result reflects advantaged barrels and cost discipline with exploration successes and project maturation underpinning

growth outlook

• Underlying production , net of price effects, grew by a robust 11% y-o-y to 1.79 m illion 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 billion 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 b illion 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 financial results in the first half of 2026 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 € 2.40 billion of cash returns to

shareholders

In the first half of 2026 Group’s proforma adjusted EBIT was € 8.91 billion , up 40% compared to the first half of 2025 due to strong performance at E&P, GGP and the Transition satellites. Adjusted net profit was €3.6 billion, up 43% compared to the first half of 2025 .

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 5

• E&P reported € 8.13 billion of proforma adjusted EBIT (up 42% compared to the first half of 2025 ) driven by favorable volume/mix effects, cost discipline and better oil realizations, despite exchange rate trend.

• GGP and Power reported €0.83 billion of proforma adjusted EBIT, with GGP at €0.78 billio n, up 24%, due to continued asset portfolio optimization and specific benefits relating to renegotiations and settlements.

• Enilive almost doubled its proforma adjusted EBIT to €0.43 billion, driven by the biorefining business, which benefited also from an improved market scenario. Plenitude reported €0.44 billion of proforma adjusted EBIT, up 17%, 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 7 billion , reversing the year -ago loss (€0.10 billion) 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 t o ongoing restructuring measures and last year’s plant closures, with the loss cut by almost 50% to around €0. 22 billion , also on the back of temporary supply disruptions supporting commodity plastics margins.

In the first half of 20 26 organic capex was €3.7 billion, down 5% compared to the same period of 2025, 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 flows related to investing activities. Organic c apex also excluded the share of capex pertaining to sanctioned joint operators, which was funded by Eni.

In the first quarter of 2026 Group’s adjusted CFFO before working capital was € 7.4 billion, funding organic capex of € 3.7 billion . Cash returns to shareholders were € 2.4 billion , comprising the 2025 dividend (€ 1.6 billion ) and the 2026 buyback program (€0. 8 billion ). Net debt was €11.3 billion at the end of June 2026, with proforma gearing at 10%, at the low end of the 10% -15% target range.

Operati ng Performance • Hydrocarbons production averaged 1.793 million boe /d, 8% higher than the comparative period driven by projects ramp -ups in Norway, Congo, 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. Underl ying production growth was 11% adjusted for impact of portfolio transactions and price effects .

• Natural gas sales were 24.65 bcm, an increase of 1 7% from the first half of 2025 mainly thanks to higher gas volumes marketed in Italy (up 27% compared to the first half of 2025) and in the European markets, in particular in Benelux and Germany/Austria (up 10% compared to the first half of 2025 ).

• Thermoelectric production amounted to 9.23 TWh, representing a decrease of 7% compared to the first half of 2025, with a lower plant utilization rate due to planned maintenance activities .

• As a part of the transition -related satellites development, as of June 30, 2026, the Group’s installed capacity reached 6.1 GW, up 1.5 GW compared with June 30, 2025 (4.6 GW), almost entirely related to Plenitude. In the first half of 2026, bio throughputs amounted to 527 ktonnes, down 7% compared to the same period of 2025.

• Retail sales were 4 million tonnes, up 7% compared with the corresponding period, mainly driven by higher sales in Italy, particularly of gasoline and diesel .

• As of June 30, 202 6, EV charging points are 23.2 thousand (of which 93% in Italy) , up by 6% compared to 2 1.8 thousand as of June 30, 202 5 and up by approximately 2% compared to 2 2.8 thousand as of December 31, 2025.

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ENI INTERIM CONSOLIDATED REPORT 2026

KEY ECONOMIC AND FINANCIAL RESULTS 2026 2025

Proforma adjusted EBIT ⁽ᵃ⁾ (€ million) 8,911 6,362 subsidiaries 5,934 4,489 main JV/Associates ⁽ᵇ⁾ 2,977 1,873 Proforma adjusted EBIT (by segment) ⁽ᵃ⁾

E&P 8,126 5,730

Global Gas & LNG Portfolio (GGP) and Power 830 860 Transition Businesses 872 598 Refining, Chemicals and Sites in transformation (300) (527) Corporate, other activities and consolidation adjustments (617) (299) Adjusted net profit before taxes ⁽ᵃ⁾ 6,235 4,949 Adjusted net profit (loss) ⁽ᵃ⁾⁽ᶜ⁾ 3,635 2,546 Net profit (loss) ⁽ᶜ⁾ 4,390 1,715 Cash flow from operations before changes in working capital at replacement cost ⁽ᵃ⁾ 7,347 6,189 Net cash from operations 5,697 5,902 Organic capital expenditure ⁽ᵈ⁾ 3,710 3,914 Net borrowings before lease liabilities ex IFRS 16 11,271 10,198 Shareholders' equity including non-controlling interest 56,930 53,405 Proforma gearing before lease liabilities ex IFRS 16 ⁽ᵃ⁾ (%) 10 Net capital employed at period end 73,642 69,311 of which: Exploration & Production 53,535 50,883 Global Gas & LNG Portfolio and Power (1,621) (651) Enilive 2,377 1,686 Plenitude 10,231 8,065 Refining, Chemicals and Sites in transformation 7,419 7,245 Share price at period end (€) 20.6 13.8 Weighted average number of shares outstanding (million) 2,940.0 3,056.2 Market capitalization ⁽ᵉ⁾ (€ billion) 61 44

EMPLOYEES 2026 2025

Exploration & Production (number) 8,574 9,006 Global Gas & LNG Portfolio and Power 1,048 1,128 Enilive 3,235 3,123 Plenitude 3,247 2,793 Refining, Chemicals and Sites in transformation 10,152 10,198 Corporate and other activities 5,912 6,108 Total group employees 32,168 32,356 of which: women 9,236 9,001 outside Italy 9,746 10,375 Female managers (senior and middle managers) (%) 31.2 30.0First Half (c) Attributable to Eni's shareholders.

First Half (e) Number of outstanding shares by reference price at period end.(b) The main JV/associates are listed in the section "Financial statements - Non-GAAP measures".(a) Non-GAAP measures. For further information see the section "Financial statements - Non-GAAP measures".

(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.

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX

7

Operating review

EXPLORATION & PRODUCTION

2026 2025 Change % Ch.

Brent dated 92.57 71.74 21 29.0 Average EUR/USD exchange rate 1.167 1.093 0.074 6.8 Hydrocarbons production 1,793 1,658 135 8.1 Liquids 847 805 42 5.2 Natural gas 4,950 4,458 492 11.1 Average realizations 66.49 55.45 11.04 19.9 Liquids 85.08 66.85 18.23 27.3 Natural gas 8.84 8.13 0.71 8.8 ($/kcf)($/boe)First half

(kbbl/d)

(mmcf/d)(kboe/d)

($/bbl)($/bbl)

STRATEGIC DEVELOPMENTS

- In the first half of 2026, the following discoveries were made: (i) the offshore Murene South -1X gas and condensate discovery well (Eni 90%) in offshore Côte d'Ivoire confirming the exploration potential of the Calao gas complex with estimated volumes of 5 Tcf of gas and 450 mln barrels of condensates; (ii) the JV Azule Energy (Eni 50%) made a significant oil discovery with the Algaita -01 exploration well in Block 15/06, offshore Angola. Preliminary estimates indicate oil in place of around 500 mln barrels. Existing production facilities further enhance the value of this discovery;

(iii) the Bahr Essalam South 2 (BESS 2) and Bahr Essalam South 3 (BESS 3) offshore gas discoveries, in Libya as a result of an exploration campaign developed in the past months. P reliminary estimates indicate that these discoveries jointly contain more than 1 Tcf of gas in place; (iv) a significant gas and condensate discovery in Egypt with the successful drilling of the Denise W 1 exploration well in the Temsah Concession, offshore of the Eastern Mediterranean Sea.

Preliminary estimates indicate about 2 trillion cubic feet (Tcf) of gas in place and 130 mmbbl of associated condensates.

The discovery is close to existing production facilities providing significant synergies for development; (v) the giant gas and condensate Geliga -1 (Eni 82%) discovery located in the Ganal block in the Kutei Basin, offshore Indonesia. Preliminary estimates indicate in -place resources of approximately 5 Tcf and 300 mmbbl of condensate allowing the possible development of a third production hub in the prolific Kutei basin. Subsequent production tests confirmed the magnitude of the discovery . Proximity to existing and planned infrastructure offers potentially significant development cost synergies and an accelerated time -to-market .

- Signed a Memorandum of Understanding (MOU) 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 recover amounts owed by PDVSA to Eni in connection with gas supplies of the Perla field.

- Eni was awarded exploration offshore Block A1 in 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 frontier ones with high potential.

- In June, following 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 k boe/d. A $6 b illion Revolving Credit Facility has been successfully secured to fund Searah’s growth plans, which include a pipeline of expected investments for over $20 b illion over the next five years.

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

- Final Investment Decisions (FIDs) were taken for: (i) the Gendalo and Gandang gas projects (South Hub) and the Geng North and Gehem fields (North Hub) in Indonesia, only 18 months after the approval of the Projects of Development Plans (PODs) in 2024. The projects will leverage on the existing infrastructure, including the Jangkrik Floating Production Unit (FPU) and the Bontang LNG facility. These assets are part of the development portfolio of the new Searah JV; (ii) Phase 3 of the Baleine project , off Côte d’Ivoire. The Phase 3 full-field development will increase oil production to 150 kbbl/d and gas production to 2000 mmcf/d , doubling the current production rate ; (iii) the Greater PAJ project, operated by Azule

ENI 8

ENI INTERIM CONSOLIDATED REPORT 202 6

Energy JV , offshore Angola. The project will develop hydrocarbon reserves 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 ;

and (iv) 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, liquefied in Damietta LNG plant for export to international markets .

- 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 million cubic meters per year as well as associated condensates.

- Signed a sale and purchase agreement with the State Company of the Argentina YPF for the acquisition of a 32% interest in three upstream blocks (Meseta Buena Esperanza, Aguada Villanueva, and Las Tacanas). The three blocks will be part of the Argentina LNG integrated development, an upstream -midstream project aimed at leveraging the Va ca Muerta gas resources , feed ing the 12 million tons per annum (MTPA) of LNG capacity (via two floating LNG units of 6 MTPA each).

The transaction is subject to approval by the relevant authorities.

- Production start -up was achieved at the Ndungu full -field, part of the Agogo Integrated West Hub Project (IWH) operated by Azule Energy, in the western area of Block 15/06, offshore Angola. The project comprises seven production wells and four injection wells, with an expected oil production peak of 60 kbbl/d.

- First gas delivery from the New Gas Consortium (NGC)’s Quiluma field operated by Azule Energy, a major milestone for Angola’s energy sector. The initial gas exports from Quiluma are set at 150 mmscf/d, with output expected to ramp up to 330 mmcf/d within 2026. Gas will be treated at the NGC gas treatment plant in Soyo, inaugurated in November 2025 and then supplied to the Angola LNG plant for export and domestic consumption.

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

MINERAL RIGHT PORTFOLIO AND EXPLORATION ACTIVITIES

As of June 30, 202 6, Eni’s mineral right portfolio consisted of 879 exclusive or shared properties for exploration and development oil and gas in 34 countries. Total acreage was 216,624 square kilometers net to Eni (205,562 square kilometers net to Eni , as of December 31, 202 5).

In the first half of 202 6, main changes derived from : (i) acquisition of new leases mainly in Algeria, Indonesia, Lebanon, Mozambique, Norway and the United Kingdom for a total acreage of approximately 16,920 square kilometers; (ii) the relinquishment of licenses mainly in Egypt, Lebanon, Norway and Oman for a total acreage of approximately 6,705 square kilometers ; (iii) net acreage increase , also due to interest changes, mainly in Australia, Mexico and Norway for a total acreage of approximately 5,810 square kilometers ; and (iv) net acreage decrease , also due to interest changes, mainly in Algeria, Egypt, Indonesia and the United Kingdom for a total acreage of 4,963 square kilometers .

In the first half of 202 6, a total of 20 exploratory wells were drilled ( 8.7 being Eni’s share), as compared to 18 exploratory wells drilled in the first half of 202 5 (7.1 being Eni’s share) .

OIL AND GAS PRODUCTION

In the first half of 202 6, oil and natural gas production averaged 1.79 mln boe/d, 8% higher than the comparative period, driven by projects ramp -ups in Norway, Congo, 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. Underlying production growth was 11% adjusted for impact of portfolio transactions and price effects .

Liquids production was 847 kbbl/d, up by 5% compared to the first half of 202 5 driven by growth in Norway, Angola, Congo and Mexico .

Natural gas production was 4,950 mmcf/d, 11% higher than the comparative period mainly due to organic growth in Norway and Congo .

Oil and gas production sold amounted to 286 mmboe. The 39 mmboe difference over production ( 325 mmboe) mainly reflected volumes consumed in operations ( 29 mmboe), changes in inventory levels and other changes.

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX

9

PRODUCTION OF OIL AND NATURAL GAS BY REGION

2026 2025

Italy (kboe/d) 59 69 Rest of Europe 311 240 North Africa 531 521 Sub-Saharan Africa 400 329 Asia 343 371 Americas 149 124 Australia and Oceania - 4 Production of oil and natural gas ⁽ᵃ⁾⁽ᵇ⁾⁽ᶜ⁾⁽ᵈ⁾ 1,793 1,658

- of which Joint Ventures and associates 546 432 Production sold ⁽ᵃ⁾ (mmboe) 286 269

PRODUCTION OF LIQUIDS BY REGION

2026 2025

Italy (kbbl/d) 25 26 Rest of Europe 194 145 North Africa 173 171 Sub-Saharan Africa 189 188 Asia 184 214 Americas 82 61 Australia and Oceania -

Production of liquids 847 805

- of which Joint Ventures and associates 289 233

PRODUCTION OF NATURAL GAS BY REGION

2026 2025

Italy (mmcf/d) 180 223 Rest of Europe 610 500 North Africa 1,871 1,828 Sub-Saharan Africa 1,107 736 Asia 832 819 Americas 350 329 Australia and Oceania 23 Production of natural gas 4,950 4,458

- of which Joint Ventures and associates 1,343 1,041 First half

First half

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

(b) Includes volumes of hydrocarbons consumed in operation (160 and 132 kboe/d in the first half of 2026 and 2025, respectively).

(c) In the first half 2026, it includes approximately 78 kboe/d 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 theUSSEC threshold forsingle country disclosures, due togrowth inother areas. Kazakhstan data have been aggregated in the geographic area “Asia”.

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ENI INTERIM CONSOLIDATED REPORT 2026

GLOBAL GAS & LNG PORTFOLIO AND POWER

2026 2025 Change % Ch.

Spot Gas price at Italian PSV (€/MWh) 44 43 1 2.6

TTF 43 41 2 3.9

Spread PSV vs. TTF 2 2 ..

Natural gas sales (bcm) Italy 13.29 10.44 2.85 27.3 Rest of Europe 9.59 9.07 0.52 5.7 of which: Importers in Italy 0.17 0.50 (0.33) (66.0) European markets 9.42 8.57 0.85 9.9 Rest of World 1.77 1.62 0.15 9.3 Worldwide gas sales ⁽ᵃ⁾ 24.65 21.13 3.52 16.7 of which: LNG sales 6.3 5.6 0.7 13

Power

Power sales in the open market (TWh) 12.28 13.21 (0.93) (7.0) Thermoelectric production 9.23 9.94 (0.71) (7.1) (a) Data include intercompany sales.First half

GLOBAL GAS & LNG PORTFOLIO

STRATEGIC DEVELOPMENTS

Signed three long -term agreements 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 LN G 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.

Signed an agreement with Mercuria to establish a global trading joint venture to fully capture value across the entire supply chain of energy commodities by integrating the optimization of the physical assets portfolio with advanced trading capabilities and expertise . 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 commo dities including oil, biofuels, gas, LNG and related logistics and infrastructure rights.

Booked regasification capacity at the Ravenna terminal equal to 2 bcm/year for a 10 -year term.

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 will increa se its contracted LNG portfolio supporting its strategic ambition to exceed 20 MTPA by 2030.

SUPPLY OF NATURAL GAS

In the first half of 202 6, Eni’s consolidated subsidiaries supplied 24.90 bcm of natural gas , with a n increase of 3.42 bcm or 15.9% from the first half of 202 5.

(bcm) 2026 2025 Change % Ch.

Italy 3.23 2.29 0.94 41.0 Algeria (including LNG) 7.16 5.88 1.28 21.8 Norway 3.77 3.45 0.32 9.3 Nigeria (LNG) 2.26 1.26 1.00 79.4 Congo (LNG) 0.90 0.34 0.56 ..

United Kingdom 0.89 0.86 0.03 3.5 Netherlands 0.54 0.53 0.01 1.9 Indonesia (LNG) 0.39 1.08 (0.69) (63.9) Libya 0.19 0.52 (0.33) (63.5) Qatar (LNG) 0.00 1.15 (1.15) ..

Other supplies of natural gas 2.80 2.29 0.51 22.3 Other supplies of LNG 2.77 1.83 0.94 51.4 Outside Italy 21.67 19.19 2.48 12.9

TOTAL SUPPLIES OF ENI'S CONSOLIDATED SUBSIDIARIES 24.90 21.48 3.42 15.9

Offtake from (input to) storage (0.25) (0.35) 0.10 28.6

TOTAL AVAILABLE FOR SALE 24.65 21.13 3.52 16.7First half

Gas volumes supplied outside Italy from consolidated subsidiaries ( 21.67 bcm), imported in Italy or sold outside Italy,

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 11

represented approximately 87% of total supplies, with a n increase of 2.48 bcm or up by 12.9% from the first half of 202 5 mainly reflecting higher volumes purchased in Algeria (+1.28 b cm), Nigeria (+1 b cm), Congo (+0.56 b cm) and Norway (+0.32 bcm), partially offset by lower volumes supplied from Qatar ( -1.15 b cm), due to the impact of operational disruptions, and Indonesia ( -0.69 b cm).

Supplies in Italy ( 3.23 bcm) reported a n incre ase of 41% from the comparative period.

SALES

In the first half of 202 6, natural gas sales were 24.65 bcm, up by 3.52 bcm from the first half of 202 5, mainly due to higher volumes marketed in Italy and in the European markets .

Sales in Italy were 13.29 bcm up by 2.85 bcm or 27.3% from the first half 202 5 (10.44 bcm), due to higher sales marketed mainly to wholesale rs and to hub .

Sales in European markets (9.42 bcm) increased by 9.9% as result of higher sales to hubs mainly in Benelux, and German y/Austria, partly offset by lower sales in Iberi an Peninsula and France.

(bcm) 2026 2025 Change %Ch.

Italy 13.29 10.44 2.85 27.3 Wholesalers 6.02 4.19 1.83 43.7 Italian gas exchange and spot markets 3.45 2.25 1.20 53.3 Industries 1.07 1.02 0.05 4.9 Power generation 0.27 0.29 (0.02) (6.9) Own consumption 2.48 2.69 (0.21) (7.8) International sales 11.36 10.69 0.67 6.3 Rest of Europe 9.59 9.07 0.52 5.7 Importers in Italy 0.17 0.50 (0.33) (66.0) European markets: 9.42 8.57 0.85 9.9 Iberian Peninsula 1.32 1.74 (0.42) (24.1) Germany/Austria 2.21 1.65 0.56 33.9 Benelux 3.00 2.31 0.69 29.9 United Kingdom 0.90 0.86 0.04 4.7 Turkey 0.29 0.00 0.29 ..

France 1.70 2.01 (0.31) (15.4) Extra European markets 1.77 1.62 0.15 9.3

NATURAL GAS SALES 24.65 21.13 3.52 16.7First half

LNG SALES

(bcm) 2026 2025 Change %Ch.

Europe 4.5 4.0 0.5 12.5 Outside Europe 1.8 1.6 0.2 12.5 TOTAL LNG SALES 6.3 5.6 0.7 12.5First half

LNG sales (included in worldwide gas sales) amounted to 6.3 bcm , representing a n increase from the comparative period (up by 0.7 bcm). In the first half of 202 6, the main sources of LNG supply were the USA, Nigeria and Congo .

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ENI INTERIM CONSOLIDATED REPORT 2026

POWER

2026 2025 Change % Ch.

Purchases of natural gas (mmcm) 1,891 2,035 (144) (7.1) Purchases of other fuels (ktoe) 18 34 (16) (47.1) Power generation (TWh) 9.23 9.94 (0.71) (7.1) Steam (ktonnes) 2,870 3,186 (316) (9.9) Availability of electricity (TWh) 2026 2025 Change % Ch.

Power generation 9.23 9.94 (0.71) (7.1) Trading of electricity ⁽ᵃ⁾ 3.05 3.27 (0.22) (6.7) Availability 12.28 13.21 (0.93) (7.0) Power sales in the open market ⁽ᵇ⁾ 12.28 13.21 (0.93) (7.0) of which: sales to third parties 8.53 9.36 (0.83) (8.9) (a) Include positive and negative imbalances (difference between the electricity effectively fed-in and as scheduled).

(b) Include sales to Group's companies.First half

First half

Eni’s power generation sites are located in Brindisi, Ferrera Erbognone, Ravenna, Mantua, Ferrara and Bolgiano. As of June 30, 202 6, the installed operational capacity of EniPower’s power plants was approximately 5 GW.

In the first half of 202 6, thermoelectric power generation was 9.23 TWh, decreasing from the first half of 202 5 (down by 7.1%), due to the lower plant utilization following planned maintenance shutdowns. Electricity trading ( 3.05 TWh) reported a decrease of 6.7% from the comparative period, continuing the optimization of power inflows and outflows.

In the first half of 202 6, power sales in the open market were 12.28 TWh, representing a decrease of 7%, following the lower volumes sold to the open market, in particular to wholesalers .

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 13

TRANSITION BUSINESSES

ENILIVE

2026 2025 Change % Ch.

Enilive

Spread EU HVO UCO-based vs UCO (CIF) $/tonnes 1,623 777 846.06 108.9 Spread US RD ⁽ᵃ⁾ UCO-based vs UCO 936 463 473 102.2 Bio throughputs (ktonnes) 527 566 (39) (6.9) Average bio refineries utilization rate (%) 69 77 Total Enilive sales mmtonnes 9.93 10.66 (0.73) (6.8) Retail sales 4.00 3.75 0.25 6.7 of which: Italy 2.96 2.65 0.31 11.7 Wholesales sales 4.86 5.71 (0.85) (14.9) of which: Italy 3.38 4.36 (0.98) (22.5) Other sales 1.07 1.20 (0.13) (10.8)First half (a) Renewable Diesel.

BUSINESS DEVELOPMENTS

Final Investment Decision (FID) was taken for a project to convert specific facilities of the Sannazzaro de' Burgondi refiner y (Pavia, Lombardy) into a biorefinery . The project is expected to be completed by 2028, achieving a high degree of flexibility to produce both HVO -diesel and SAF -biojet. In April, the European Investment Bank (EIB) granted a 15 -year loan of €500 million to finance the project.

Final Investment Decision (FID) was taken to build a biorefinery as part of the conversion plan of the Priolo hub, in partnership with Q8.

Extended the collaboration with Itabus, whose entire vehicle fleet runs on HVOlution diesel. The collaboration between Eniliv e and Itabus began in 2021 with the testing and initial deployment of HVOlution diesel on the first vehicles.

Eni and MSC Cruises completed test activities of Enilive’s HVO diesel, confirming its immediate applicability for use in mari ne engines with performance in line with traditional marine fossil fuels and also reducing emissions.

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 320 service stations, strengthening its presence in key strategic markets.

Signed an agreement with carmaker BMW Group to power its vehicles of corporate fleets in Italy with HVO Diesel manufactured by Enilive .

THROUGHPUTS AND SALES

Bio throughputs were 527 ktonnes, down by 6.9% from the same period of 202 5. The lower volumes processed reflected maintenance shutdowns at the Venice biorefiner y.

(mmtonnes) 2026 2025 Change %Ch.

Retail 2.96 2.65 0.31 11.7 Wholesale 3.39 4.36 (0.97) (22.2) Other sales 1.07 1.20 (0.13) (10.8) Sales in Italy 7.42 8.21 (0.79) (9.6) Retail 1.04 1.10 (0.06) (5.5) Wholesale 1.47 1.35 0.12 8.9 Sales outside Italy 2.51 2.45 0.06 2.4

TOTAL SALES OF REFINED PRODUCTS 9.93 10.66 (0.73) (6.9)First half

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ENI INTERIM CONSOLIDATED REPORT 2026

In the first half of 202 6, sales of refined products (9.93 mmt onnes) decreased by 0.73 mmtonnes compared to the corresponding period of 202 5 (down by 6.9%).

Retail sales in Italy were 2.96 mmton nes, showing a n increase (11.7 %) due to higher volumes of gasoline and gasoil.

As of June 30, 202 6, Eni’s retail network in Italy consisted of 4,008 service stations, recording a n increase from June 30, 2025 (3,975 service stations), mainly resulting from the posi tive balance of acquisitions/releases of lease concessions ( +33 units) .

Wholesale sales in Italy were 3.39 mmtons , down by 22.2 % from the first half of 202 5, mainly due to the optimization of the clients portfolio in Italy . Other sales in Italy ( 1.07 mmtonnes) decreased compared to the first half of 202 5 (down by 10.8 %).

Retail and wholesale sales outside Italy of 2.51 mmtonnes increased by 0.06 mmtonnes from the first half of 202 5 (+2.4 %), mainly reflect ing lower volumes marketed in Europe.

PLENITUDE

2026 2025 Change % Ch.

Plenitude

Italian PUN Index GME €/MWh 127 120 8 6.4 Retail and business customers at period end (mln pod) 10.8 10.0 0.8 7.8 Retail and business gas sales to end customers (bcm) 2.92 3.07 (0.15) (4.9) Retail and business power sales to end customers (TWh) 10.33 8.99 1.34 14.9 Renewable installed capacity at period end (GW) 6.0 4.5 1.5 33.3 Energy production from renewable sources (TWh) 4.0 2.7 1.3 48.1 EV charging points at period end (thousand) 23.2 21.8 1.4 6.2First half

BUSINESS DEVELOPMENTS

Eni commenced a reorganization of the shareholding structure of its subsidiary Plenitude, involving non -controlling shareholders Ares Alternative Credit (affiliates of Ares Management Corporation) and Energy Infrastructure Partners, with the aim to establi sh a new governance framework based on joint control between Eni and Ares, which upon completion will result in the derecognition of Plenitude from Eni's consolidated financial statements. The transaction involves a non -

proportional capital increase to be subscribed to by the shareholders amounting to approximately €1.5 b illion , of which at least €1 b illion is expected to be provided by Ares, based on a 100% pre -money equity valuation of Plenitude of €10.75 b illion (and an implied enterprise value of €13.1 b illion ). The transaction is subject to the approval of the competent authorities.

From 1Q ‘26, Plenitude was accounted for as discontinued operation ex IFRS 5 in the Group consolidated statutory accounts.

Completed the acquisition of the entire share capital of Acea Energia S.p.A. and the 50% share capital of Umbria Energy S.p.A.

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, started production at the second 200 MW plant.

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 .

Plenitude signed with Methagora , a biomethane solutions developer and gas supplier, an agreement covering the sourcing in France of 50 GWh of biomethane per year over a 15 -year period. Under the agreement, Methagora will sell Plenitude biomethane sourced from a range of agricultural are as in France.

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.

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 15

Plenitude signed an agreement with Autopistas del Atlántico to install and operate 42 ultrafast charging points with power up to 300 kW, located in service areas along the AP -9 motorway in the Galicia region, with completion expected by the end of 2026.

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 .

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.

RETAIL AND BUSINESS GAS SALES

(bcm) 2026 2025 Change % Ch.

Italy 2.06 2.10 (0.04) (1.9) Retail 1.51 1.57 (0.06) (3.8) Business 0.55 0.53 0.02 3.8 International sales 0.86 0.97 (0.11) (11.3)

European markets:

France 0.64 0.72 (0.08) (11.1) Greece 0.16 0.18 (0.02) (11.1) Other 0.06 0.07 (0.01) (14.3)

RETAIL AND BUSINESS GAS SALES TO END CUSTOMERS 2.92 3.07 (0.15) (4.9)First half

In the first half of 202 6, retail and business gas sales in Italy and the rest of Europe amounted to 2.92 bcm, down by 0.15 bcm or 4.9% from the first half of 202 5, mainly outside Italy, due to lower consumptions following lower average consumptions.

RETAIL AND BUSINESS POWER SALES

In the first half of 202 6, retail and business power sales to end customers , managed by Plenitude and its subsidiaries in Italy and abroad (France, Iberian Peninsula and Greece ) amounted to 10.33 TWh, with an increase of 15% compared to the first half of 202 5, benefitting from the larger portfolio of customers due to the acquisition of Acea Energia , as well as higher average consumptions of electricity .

RENEWABLES

(TWh) 2026 2025 Change % Ch.

Energy production from renewable sources 4.0 2.7 1.3 48.1 of which: photovoltaic 2.4 1.5 0.9 60.0 wind 1.6 1.2 0.4 33.3 of which: Italy 0.9 0.8 0.1 12.5 outside Italy 3.1 1.9 1.2 63.2First half

Energy production from renewable sources amounted to 4 TWh (of which 2.4 TWh photovoltaic , 1.6 TWh wind ) up by 1.3 TWh compared to the first half of 202 5, mainly benefitt ing from the higher capacity in France and the development of organic project s in Spain .

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ENI INTERIM CONSOLIDATED REPORT 2026

Installed capacity

Follows breakdown of the installed capacity from renewables by technology:

(GW) 2026 2025 Change % Ch.

Installed capacity from renewables at period end 6.0 4.5 1.5 33.3 of which: photovoltaic (including installed storage capacity) 74% 72% wind 26% 28%First half

Breakdown by Country:

2026 2025 Change % Ch.

ITALY 1.1 1.1 0.0 0.0

OUTSIDE ITALY 4.9 3.4 1.5 44.1

United States 1.7 1.7 0.0 0.0 Spain 1.8 1.2 0.6 ..

Other (Australia, France, Germany, Greece, Kazakhstan, UK) 1.4 0.5 0.9 180.0 Total installed capacity from renewables at period end (including installed storage power) ⁽ᵃ⁾ 6.0 4.5 1.5 33.3First half

(GW)

(a) Installed storage capacity amounted to 272 MW and 221 MW in the first half 2026 and the first half 2025, respectively.

As of June 30, 202 6, the total renewable installed capacity was 6 GW. Compared to June 30, 202 5, the capacity increased by 1.5 GW, mainly thanks to the organic development in Spain, the UK, Greece, Italy and Kazakhstan as well as the acquisition in France and in the USA .

E-MOBILITY

As of June 30, 2026, the installed charging points for electric vehicles amounted to 23.2 thousand (of which 93% in Italy) , up 6.4% from June 30, 202 5 (21.8 thousand units) and up 1.8% from the end of 202 5 (22.8 thousand units as of December 31, 2025).

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 17

REFINING , CHEMICALS AND SITES I N TRANSFORMATION

2026 2025 Change % Ch.

Refining

Standard Eni Refining Margin (SERM) ⁽ᵃ⁾ ($/bbl) 9.1 4.3 4.8 112.2 Throughputs in Italy on own account (mmtonnes) 6.14 7.07 (0.93) (13.2) Throughputs in the rest of World on own account 3.96 5.17 (1.21) (23.4) Total throughputs on own account 10.10 12.24 (2.14) (17.5) Average refineries utilization rate (%) 70 79

Chemicals

Sales of chemical products (mmtonnes) 1.26 1.52 (0.26) (17.1) Average plant utilization rate (%) 58 51First half (a) In $/bbl. Source: Eni calculations. Given volatility and market dislocations , the benchmark SERM refining margin has been calculated to factor such conditions.

REFINING

PORTFOLIO DEVELOPMENTS

As of January 1, 2026, the business branch of Eni SpA’s Refining Evolution & Transformation unit has been contributed to the new subsidiary Eni Industrial Evolution (EIE) SpA , engaged in the efficient use of traditional assets and in the industrial transformation, also with a view to the circular economy.

REFINING THROUGHPUTS

In the first half of 202 6, Eni’s Standard Refining Margin – SERM – amounted to 9.1 $/barrel , increasing compared to the same period of 202 5 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 .

Eni refining throughputs on own account were 10.10 mmtonnes, decreasing compared to the first half of 202 5. In Italy, the reduced throughputs (6.14 mmtonnes) reflected lower volumes processed at the Milazzo and Sannazzaro refiner ies due to planned maintenance downtime, partly offset by higher volumes at the Taranto refinery following higher plant availability .

Throughputs in the rest o f world decreased compared to 202 5 (-23.4%), due to lower volumes processed due to the product unavailability connected to the closure of Strait of Hormuz. Decreased by 9 percentage points the average plant utilization rate ( 70%) compared to the first half 202 5.

CHEMICALS

PORTFOLIO DEVELOPMENTS

Progress is being made in the restructuring plan of the Versalis hub in Priolo, where FID was made to build a biorefinery and evaluation and authorization activities are ongoing to build a plant for the chemical recycling of post -consumer plastics.

ENI 18

ENI INTERIM CONSOLIDATED REPORT 2026

SALES

(ktonnes) 2026 2025 Change %Ch.

Intermediates 863 1,701 (838) (49.3) Polymers 545 701 (156) (22.3) Biochem 107 118 (11) (9.0) Moulding & Compounding 40 40 0 0.2 Total productions 1,555 2,559 (1,004) (39.2) Consumption and losses (785) (1,467) 682 46.5 Purchases and change in inventories 485 426 60 14.0 Total availability 1,256 1,518 (262) (17.3) Intermediates 745 799 (54) (6.8) Polymers 400 609 (209) (34.3) Oilfield chemicals 14 13 1 11.2 Biochem 60 59 2 2.8 Moulding & Compounding 37 39 (2) (6.4) Total sales 1,256 1,518 (262) (17.3)First half

Chemicals production of 1,555 ktonnes decreased by 1,004 ktonnes (down by 39.2%) mainly due to the definitive shutdown of the cracking at the Brindisi site (from April 2025) and at the Priolo site (from July 2025).

Chemicals sales of 1,256 ktonnes decreased by 262 ktonnes ( down by 17.3%), due to the polymers market being affected by significant geopolitical tensions and higher feedstock costs, which resulted in lower demand for plastic materials from industrial customers.

Moulding & Compounding sales of 37 ktonnes were related to semi -finished and products of the Finproject Group, particularly the last generation compound based on expandable polyolefins under the Levirex® brand and the ultra -light plastic material under the XL Extralight® brand.

Margins recorded a significant improvement, supported by transformation initiatives and by a polyethylene market characterized by supply shortages resulting from geopolitical tensions associated with the closure of the Strait of Hormuz.

Biochem margins were advers ely affected by the introduction in Europe of tariffs on imports of feedstocks from Asia.

SITES IN TRANSFORMATION

PORTFOLIO DEVELOPMENTS

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 integr ated indust rial 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 .

CONDENSED CONSOLIDAT ED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 19

ESG PERFORMANCE AND INITIATIVES

HEALTH, SAFETY AND ENVIRONMENT ⁽ᵃ⁾ 2026 2025

Total Recordable Injury Rate (TRIR) (total recordable injuries/worked hours) x 1,000,000 0.53 0.48 employees 0.42 0.60 contractors 0.59 0.40 Direct GHG emissions (Scope 1) (mmtonnes CO ₂eq) 8.0 9.5 of which: E&P 1.7 2.5 GGP and Power 4.4 4.6 Enilive 0.1 0.3 Plenitude 0.001 0.001 Refining, Chemicals and Sites in transformation 1.7 2.1 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 Re-injected production water (%) 59 55 Volume of oil spills due to sabotage (including theft) (>1 barrel) (barrels) 75 0 Operational oil spills volumes (>1 barrel) 931 11 (a) KPIs refer to 100% of the operated assets, consolidated and unconsolidated.First Half

• 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 d ecreased. 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 management actions), refining (maintenance shutdowns) and ch emicals (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 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).

• Upstream r e-injected production water increased compared with IH ‘25 (59% vs. 55%), driven by higher volumes re -

injected particularly in Mexico and the Netherlands.

• In the first half 202 6, R&D costs amounted to € 89 million, down by 5% compared to the first half 202 5 (€94 million).

• Eni ranked first in the Corporate Human Rights Benchmark (CHRB) published by the World Benchmarking Alliance (WBA), which evaluates performance across specific measurement areas of over 100 main companies globally operating in five high -risk sectors.

• The Global Framework Agreement on International Industrial Relations, Corporate Social Responsibility and for a Just Transition (GFA) was renewed with IndustriALL Global Union and the trade unions Filctem Cgil, Femca Cisl, Uiltec Uil.

• In Egypt, Eni, through its subsidiary IEOC, and Eni Foundation signed a Memorandum of Intent (MoI ) with the Ministry of Health and Population, the Health Insurance Organization and the Ministry of Petroleum and Mineral Resources to engage in joint cooperation for the development and implementation of a community health project aimed at enhancing healt hcare services and improving the well -being of the people in Cairo Governorate with a focus on vulnerable groups.

• 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 wi th 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.

ENI 20

ENI INTERIM CONSOLIDATED REPORT 2026

• 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 strengthening of the national health system and the promotion of more equitable access to quality healthcare services.

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

• 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 landfi lls.

• 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 m illion 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 additio n, in Angola, Eni announced the launch of a sustainable agriculture and restoration project for degraded ecosystems in the province of Moxico, in order to promote practices and interventions to rebuild forest ecosystems.

• 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 at ensurin g asset integrity. This technology provides applications in offshore projects and in Carbon Capture and Storage (CCS) in the marine environment.

• 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.

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

• 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 fusion industr y.

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

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 21

Financial review

As a result of Eni’s Board of Directors decision to reorganize the shareholding structure of Eni’s subsidiary Plenitude and to establish a new governance framework based on joint control with the minority shareholder Ares Management Alternative Credit funds (“Ares”) , from the first quarter of 2026, the Plenitude group has been accounted for as discontinued operation ex IFRS 5 in the Group consolidated statutory accounts because it represents a major business line held for sale . This means that Plenitude results after elimination of intercompany transactions are condensed in a single item of the Group statutory consolidated profit and loss account and reported separately from the results of continuing operations.

Results of continued and discontinued did 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 supplyin g Plenit ude 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 segment. The first half of 2025 has 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 interim report relating to Plenitude represent the entity on a standalone basis in line with prior periods segment information.

CONTINUING OPERATIONS RESULTS

PROFIT AND LOSS ACCOUNT

(€ million) 2026 2025 Change % Ch.

Sales from operations 42,056 35,752 6,304 17.6 Other income and revenues 673 649 24 3.7 Operating expenses (35,612) (31,681) (3,931) (12.4) Other operating income (expense) (321) 436 (757) ..

Depreciation, depletion, amortization (3,321) (3,478) 157 4.5 (1,474) (641) (833) ..

Write-off of tangible and intangible assets (119) 14 (133) ..

Operating profit (loss) 1,882 1,051 831 79.1 Finance income (expense) (386) (329) (57) (17.3) Income (expense) from investments 3,318 775 2,543 ..

Profit (loss) before income taxes 4,814 1,497 3,317 ..

Income taxes (2,117) (2,056) (61) (3.0) Tax rate (%) 44.0 137.3 Net profit (loss) - continuing operations 2,697 (559) 3,256 ..

Net profit (loss) - discontinued operations 1,958 2,315 (357) (15.4) Net profit (loss) 4,655 1,756 2,899 ..

attributable to:

- Eni's shareholders 4,390 1,715 2,675 ..

- continuing operations 3,023 (406)

- discontinued operations 1,367 2,121

- non-controlling interest 265 41 224 ..

- continuing operations (326) (153) (173) ..

- discontinued operations 591 194 397First Half Net impairment reversals (losses) of tangible and intangible and right-of-use assets

In the first half of 202 6, market environment favorably affected the Group’s economic and financial performance, mainly due to the positive trend of energy commodities partly offset by the appreciation of the EUR/USD. The volatility of o il price reached record levels during the first half of 2026, with the Brent benchmark averaging approximately 93 $/bbl, up by 29% compared to the first half of 2025. In the first half of 2026 the natural gas prices at the main European hubs (PSV and TTF) recorded a positive trend (up by 3 -4% compared with the corresponding period of the previous year) whit limited volatility due to the start -up of significant liquefaction capacity in the USA and the growth of renewables.

The Standard Eni Refining Margin (SERM) reported a significant increase i n the first half of 2026 (up by approximately 1 12%

ENI 22

ENI INTERIM CONSOLIDATED REPORT 202 6

compared with the same period of 2025) due to a reduction in the availability of refined products in international markets driven by geopolitical factors (disrupted flows from the Middle East and Russia) and lower export volumes from China in connection with p olicy measures aimed at supporting domestic demand. The appreciation of the EUR/USD exchange rate (up by 7% compared to the first half of 2025) negatively impacted on the translation of the financial statements of subsidiaries with USD functional currency.

Group net profit reflected the positive trend in the operating performance as well as net gain relating to the business combination with Petronas to launch the new JV Searah (€2.1 billion) partly offset by impairment losses at E&P assets of approximately €1. 2 billion.

The following table shows the main scenario indicators reported in the first half of 202 6:

2026 2025 % Ch.

Average price of Brent dated crude oil in U.S. dollars ⁽ᵃ⁾ 92.57 71.74 29.0 Average EUR/USD exchange rate ⁽ᵇ⁾ 1.167 1.093 6.8 Average price of Brent dated crude oil in euro 79.32 65.64 20.8 Standard Eni Refining Margin (SERM) ⁽ᶜ⁾ 9.1 4.3 112

PSV ⁽ᵈ⁾ 44 43 2.6

TTF ⁽ᵈ⁾ 43 41 3.9

Spread EU HVO UCO-based vs UCO (CIF) 1,623 777 ..

Spread US RD ⁽ᵉ⁾ UCO-based vs UCO 936 463 ..

Italian PUN Index GME 127 120 6.4 (a) Price per barrel. Source: S&P Global Energy.

(b) Source: ECB.

(d) €/MWh.

(e) Renewable Diesel.(c) In $/bbl. Source: Eni calculations. Given volatility and market dislocations , the benchmark SERM refining margin has been calculated to factor such conditions.First Half

Analysis of profit and loss account items

REVENUES

(€ million) 2026 2025 Change % Ch.

Exploration & Production 30,317 24,942 5,375 21.5

- of which upstream 10,811 10,107 704 7.0 Global Gas & LNG Portfolio and Power 9,433 9,034 399 4.4

- Global Gas & LNG Portfolio 7,555 6,961 594 8.5

- Power 1,878 2,073 (195) (9.4) Enilive 11,674 9,536 2,138 22.4 Refining, Chemicals and Sites in transformation 10,553 9,465 1,088 11.5

- Refining 8,702 7,545 1,157 15.3

- Chemicals 1,661 2,017 (356) (17.6)

- Sites in transformation 298 298 Corporate and other activities 932 979 (47) (4.8) Consolidation adjustments (20,853) (18,204) (2,649) Sales from operations 42,056 35,752 6,304 17.6 Other income and revenues 673 649 24 3.7 Total revenues 42,729 36,401 6,328 17.4First Half

Total revenues amounted to € 42,729 million, up by 17% from the first half of 202 5.

Eni’s sales from operations were € 42,056 million in the first half of 2026 , reflecting the positive trend in energy commodities partly offset by appreciation of the euro which negatively affected all business segments: the Brent price increased by 29% in the first half of 2026 vs the first half of 2025 ; as well as the higher price of refining products favorably affected by tighter global supply in international markets driven by geopolitical factors (disrupted flows from the Middle East and Russia), part ly offset by lower processed volumes. The increase reported in the Enilive segment was mainly related to an improved market scenario in the biorefining business.

Other income and revenues amounting to € 673 million, increased by 4% from the first half of 2025 and include the share of lease repayments debited to joint operators in Eni -led upstream projects, as well as revenues from patents, licenses and royalties.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 23

OPERATING EXPENSES

(€ million) 2026 2025 Change % Ch.

Purchases, services and other 33,929 30,054 3,875 12.9 Impairment losses (impairment reversals) of trade and other receivables, net 101 73 28 38.4 Payroll and related costs 1,582 1,554 28 1.8 of which: provision for redundancy incentives and other 30 34 (4) (11.8) 35,612 31,681 3,931 12.4First Half

Operating expenses in the first half of 202 6 (€35,612 million) increased by € 3,931 million from the first half of 202 5 (up by 12%) .

Purchases, services and other (€33,929 million) increased by € 3,875 million from the same period of 202 5, mainly reflecting higher hydrocarbon supply costs (gas from long -term contracts and refinery and chemical feedstocks) due to the trend in the energy market scenario.

Payroll and related costs (€1,582 million) were substantially unchanged from the first half of 202 5.

DEPRECIATION, DEPLETION, AMORTIZATION, IMPAIRMENT LOSSES (IMPAIRMENT

REVERSALS) NET AND WRITE -OFF

(€ million) 2026 2025 Change % Ch.

Exploration & Production 2,947 3,065 (118) (3.8) Global Gas & LNG Portfolio and Power 90 132 (42) (31.8) Enilive 149 145 4 2.8 Refining, Chemicals and Sites in transformation 73 75 (2) (2.7) Corporate and other activities 79 77 2 2.6 Impact of unrealized intragroup profit elimination (17) (16) (1) Total depreciation, depletion and amortization 3,321 3,478 (157) (4.5) Impairment losses (impairment reversals) of tangible and intangible and right of use assets, net1,474 641 833 ..

Depreciation, depletion, amortization, impairments and reversals 4,795 4,119 676 16.4 Write-off of tangible and intangible assets 119 (14) 133 ..

4,914 4,105 809 19.7First Half

Depreciation, depletion and amortization (€3,321 million) decreased by €157 million from the first half of 202 5 (down by 4.5%) following the appreciation of the EUR vs. USD and in the Exploration & Production segment due to portfolio activity partly offset by start -ups and ramp -up of new projects. Impairment losses (impairment reversals) of tangible and intangible and right of use assets, net (€1.474 million) are disclosed in the section “Non-Gaap results ”.

Write -off of tangible and intangible assets amounted to €119 million and mainly related to the E&P segment as capitalized costs of suspended exploratory wells were expensed through profit due to the negative assessment of recoverable reserves or economic feasibility of exploration projects in Oman and Libya, as well as, exploration mineral rights, mainly due to the abandonment of certain underlying initiatives.

ENI 24

ENI INTERIM CONSOLIDATED REPORT 202 6

FINANCE INCOME (EXPENSE)

(€ million) 2026 2025 Change Finance income (expense) related to net borrowings (380) (368) (12)

- Interest expense on corporate bonds (346) (367) 21

- Net income from financial activities held for trading 94 120 (26)

- Net income from financial assets measured at fair value through profit or loss 1 (9) 10

- Interest expense for banks and other financing istitutions (164) (129) (35)

- Interest expense for lease liabilities (162) (180) 18

- Interest from banks 68 103 (35)

- Interest and other income from receivables and securities for non-financing operating activities 129 94 35 Income (expense) on derivative financial instruments 9 (70) 79

- Derivatives on exchange rate 53 (52) 105

- Derivatives on interest rate (44) (18) (26) Exchange differences, net 93 182 (89) Other finance income (expense) (143) (143)

- Interest and other income from receivables and securities for financing operating activities 18 18

- Finance expense due to the passage of time (accretion discount) (142) (162) 20

- Other finance income (expense) (19) 1 (20) (421) (399) (22) Finance income (expense) capitalized 35 70 (35) (386) (329) (57)First Half

Net finance expense (€386 million) reported a slight increase (€ 57 million from the first half of 202 5) mainly due to : (i) expense related to net borrowings increasing by € 12 million ; (ii) higher financial expenses related to the negative change in the fair value of interest rate derivatives (down by €26 million), whose changes are recognized in the profit and loss as the y do not meet the formal criteria to be classified as hedges; an d (iii) lower financial expenses related to the negative change in the fair value of currency derivatives (up by €105 million), whose changes are recognized in the profit and loss as they do n ot meet the formal criteria to be classified as hedges under IFRS 9, par tially offset by the negative change in exchange rate differences ( down by €89 million).

NET INCOME (EXPENSE) FROM INVESTMENTS

(€ million) 2026 2025 Change Share of gains (losses) from equity-accounted investments 1,172 669 503 Dividends 60 100 (40) Other income (expense), net 2,086 6 2,080 Income (expense) from investments 3,318 775 2,543First Half

Net income from investments amounted to € 3,318 million, increasing compared to the same period of 202 5 (up by €2,543 million) and referred to:

- gains from equity -accounted investments (€ 1,172 million) mainly relating to the share profit of Vår Energi, Azule Energy, Ithaca Energy , Searah and ADNOC R&GT as well as Eni’s share of the Saipem joint venture results;

- dividends of € 60 million related to dividends paid by minor investments in certain entities which were designated at fair value , and which mainly comprised Nigeria LNG (€ 31 million) and Everen Ltd (€ 20 million) ;

- other net income (€2,0 86 million) mainly related to the effects of the business combination to launch the Searah JV.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 25

SUMMARIZED GROUP BALANCE SHEET1

(€ 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 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 liabilities5,979 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 post 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 liability ex IFRS 16 0.15 0.17 Gearing after lease liability ex IFRS 16 0.22 0.23

As of June 30, 2026, fixed assets (€76, 095 million) decreased by € 955 million from December 31, 2025, 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 ini tial 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 translati on differences (the period -end exchange rate of EUR vs. USD was 1.139 down by 3% compared to 1.176 as of December 31, 2025) increased the euro reported amounts of dollar -denominated assets for €1,653 million .

Net working capital amount was €13,725 million. 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 billion) and other held -for-sale E&P properties (€2. 2 billion). 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 revaluation gain of ca. €0.2 9 billion .

1 For a reconciliation to the statutory statement of cash flow see the paragraph “Reconciliation of Summarized Group Balance Sh eet and Statement of Cash Flows to Statutory Schemes”.

ENI 26

ENI INTERIM CONSOLIDATED REPORT 202 6

Eni’s shareholders equity (€52,0 01 million) increased by €4, 061 million from December 31, 2025, due to net profit for the period (€4, 390 million) and positive foreign currency translation differences (€1,5 34 million), partly offset by shareholders remuneration of approximately €2,438 million (dividends and share buyback).

Non -controlling interests of €4,929 million included: i) a minority participating interest acquired by the private equity fund KKR in the share capital of Enilive (€839 million) as well as the EIP and Ares fund’s interest in Plenitude of €1,911 million ; ii) a perpetual subordinate d hybrid bond (€1,755 million) 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 borrowings before lease liabilities as of June 30, 2026 , of €11 ,271 million was up by €1 ,743 million from December 31, 2025.

Gearing – the ratio of net borrowings to net capital employed before lease liabilities – was 17% on June 30, 2026. Considering the portfolio transactions underway, the Group proforma gearing stands at 10%.

GEARING AND NET BORROWINGS

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. Ma nagement 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 June 30, 2026 Change Total finance 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 post 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

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 27

COMPREHENSIVE INCOME

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

Taxation

Items that may be reclassified to profit or loss in later periods 1,213 (5,519) Currency translation differences 1,600 (6,063) Change in the fair value of cash flow hedging derivatives(482) 732 Share of other comprehensive income on equity-accounted entities (56) 24 Taxation 151 (212) Total other items of comprehensive income (loss) 1,223 (5,514) Total comprehensive income (loss) 5,878 (3,758)

attributable to:

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

- continuing operations 4,104 (5,600)

- discontinued operations 1,424 2,051

- Non-controlling interest 350 (209)

- continuing operations (266) (395)

- discontinued operations 616 186First Half

CHANGES IN SHAREHOLDERS’ EQUITY

(€ 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 perpetual hybrid bonds 1,500 Repurchase of perpetual hybrid bonds (1,251) Coupon of perpetual subordinated bonds (105) Taxes on Enilive and Plenitude disposals (26) Taxes on hybrid bond coupon and costs 10 Plenitude operation- disposal to EIP 209 Put option on Plenitude (139) Enilive operation - 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 perpetual hybrid bonds 1,000 Coupon of perpetual subordinated bonds (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

ENI 28

ENI INTERIM CONSOLIDATED REPORT 202 6

SUMMARIZED GROUP CASH FLOW STATEMENT2

(€ million) 2026 2025 Change Net profit (loss) - continuing operations 2,697 (559) 3,256 Net profit (loss) - discontinued operations 1,958 2,315 (357) Net profit (loss) 4,655 1,756 2,899 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

- depreciation, depletion and amortization and other non monetary items 1,776 3,558 (1,782)

- net gains on disposal of assets (5) (6) 1

- dividends, interests, taxes and other changes 2,700 2,384 316 Changes in working capital related to operations (1,516) 192 (1,708) Dividends received by equity investments 868 879 (11) Taxes paid (2,051) (2,230) 179 Interests (paid) received (730) (631) (99) Net cash provided by operating activities 5,697 5,902 (205) Capital expenditure (4,008) (3,773) (235) Investments and purchase of consolidated subsidiaries and businesses (800) (351) (449) Disposal of consolidated subsidiaries, businesses, tangible and intangible assets and investments (271) 84 (355) Other cash flow related to investing activities and disinvestments 255 (175) 430 Free cash flow 873 1,687 (814) Net cash inflow (outflow) related to financial activities (830) (190) (640) Changes in short and long-term financial debt 2,460 (1,324) 3,784 Repayment of lease liabilities (669) (675) 6 Dividends paid and changes in non-controlling interests and reserves (2,527) 1,564 (4,091) Net issue (repayment) of perpetual hybrid bond 804 126 678 Effect of changes in consolidation and exchange differences of cash and cash equivalent 23 (204) 227

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENT 134 984 (850)

Change in net borrowings (€ million) 2026 2025 Change Free cash flow 873 1,687 (814) Repayment of lease liabilities (669) (675) 6 Net borrowings of acquired companies (9) (9) Net borrowings of divested companies (238) (238) Exchange differences on net borrowings and other changes 23 (725) 748 Dividends paid and changes in non-controlling interest and reserves (2,527) 1,564 (4,091) Net issue (repayment) of perpetual hybrid bond 804 126 678

CHANGE IN NET BORROWINGS BEFORE LEASE LIABILITIES (1,743) 1,977 (3,720)

Repayment of lease liabilities 669 675 (6) Inception of new leases and other changes (410) 70 (480) Change in lease liabilities 259 745 (486)

CHANGE IN NET BORROWINGS AFTER LEASE LIABILITIES (1,484) 2,722 (4,206)First Half

First Half

Net cash provided by operating activities in the first half of 202 6 was € 5,697 million and included € 868 million 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 billion higher than in the fourth quarter of 2025 as part of the Group initiatives to optimize working capital requirements.

2 For a reconciliation to the statutory statement of cash flow see the paragraph “Reconciliation of Summarized Group Balance Sh eet and Statement of Cash Flows to Statutory Schemes”.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 29

CAPITAL EXPENDITURE

(€ million)2026 2025 Change % Ch.

Exploration & Production 3,141 2,775 366 13.2 of which: - exploration 265 166 99 59.6

- oil and gas development 2,860 2,586 274 10.6

- other 16 23 (7) (30.4) Global Gas & LNG Portfolio 22 37 (15) (40.5)

- Global Gas & LNG Portfolio 2 9 (7) (77.8)

- Power 20 28 (8) (28.6) Enilive 119 101 18 17.8 Plenitude 219 340 (121) (35.6) Refining, Chemicals and Sites in transformation 440 288 152 52.8

- Refining 384 206 178 86.4

- Chemicals 44 82 (38) (46.3)

- Sites in transformation 12 Corporate and other activities 78 253 (175) (69.2) Impact of unrealized intragroup profit elimination (11) (21) 10 Capital expenditure ⁽ᵃ⁾ 4,008 3,773 235 6.2First Half (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 (€561 million and €753 million in the first half 2026 and the first half 2025, respectively).

Capital expenditure of €4,008 million, increasing by 6% y -o-y, (€3,773 million in the first half of 202 5) mainly concerned :

- in the Exploration & Production, capital expenditure (€3,141 million ) 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 Enilive segment (€11 9 million ) mainly related to biorefining projects (Venice EcofiningTM and Gela catalysts) and marketing activity in Italy and in the rest of Europe;

- in the Plenitude segment (€219 mln) mainly related to development activities in the renewable business, acquisition of new customers, as well as development of electric vehicles network infrastructure ;

- in the Refining, Chemicals and Sites in transformation segment mainly related to refining in Italy (€ 384 million ) specifically to the reconversion of Livorno in biorefinery, maintenance and stay -in-business, as well as to the chemical business (€4 4 million ) and regarded the circular economy and asset integrity;

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

ENI 30

ENI INTERIM CONSOLIDATED REPORT 202 6

RECONCILIATION OF SUMMARIZED GROUP BALANCE SHEET AND

SUMMARIZED GROUP CASH FLOW STATEMENT TO STATUTORY SCHEMES

SUMMARIZED GROUP BALANCE SHEET

Items of Summarized Group Balance Sheet (where not expressly indicated, the item derives directly from the statutory scheme)

(€ million)

Fixed assets

Property, plant and equipment 49,165 50,536 Right of use 4,948 5,184 Intangible assets 1,532 6,022 Inventories - Compulsory stock 1,655 1,187 Equity‐accounted investments and other investments 19,170 14,484 Receivables and securities held for operating activities (see note 14) 997 974 Net payables related to capital expenditure, made up of: (1,372) (1,337) -liabilities for current investment assets (see note 8) (49)

- liabilities for no current investment assets (see note 8)

- receivables related to disposals (see note 6) 74 209

- receivables related to disposals non‐current (see note 8) 171 169

- payables for purchase of non-current assets (see note 15) (1,617) (1,666) Total fixed assets 76,095 77,050 Net working capital Inventories 6,407 5,143 Trade receivables (see note 6) 9,044 8,986 Trade payables (see note 15) (14,863) (13,901) Net tax assets (liabilities), made up of: 757 1,506

- current income tax payables (420) (343)

- non-current income tax payables (25) (40)

- other current tax liabilities (see note 8) (2,277) (1,589)

- deferred tax liabilities (4,222) (4,805)

- other non-current tax liabilities (see note 8) (35) (47)

- current income tax receivables 820 539

- non-current income tax receivables 125 125

- other current tax assets (see note 8) 692 919

- deferred tax assets 6,084 6,716

- other non-current tax assets (see note 8) 7 24

- receivables for Italian consolidated accounts (see note 6) 10 9

- payables for Italian consolidated accounts (see note 15) (2) (2) Provisions (13,887) (14,580) Other current assets and liabilities, made up of: (1,183) (1,572)

- short-term financial receivables for operating purposes (see note 14)

- receivables vs. partners for exploration and production activities and other (see note 6) 3,279 3,232

- other current assets (see note 8) 2,721 3,024

- other receivables and other assets non-current (see note 8) 1,293 2,608

- advances, other payables, payables vs. partners for exploration and production activities and other(see note 15) (3,497) (4,692)

- other current liabilities (see note 8) (3,521) (2,401)

- other payables and other liabilities non-current (see note 8) (1,458) (3,343) Total net working capital (13,725) (14,418) Provisions for employee benefits (559) (596) Assets held for sale including related liabilities 11,831 5,979 made up of:

- assets held for sale 18,533 8,005

- liabilities directly associated with held for sale (6,702) (2,026)

CAPITAL EMPLOYED, NET 73,642 68,015

Shareholders' equity including non‐controlling interest 56,930 52,787

Net borrowings

Total debt, made up of: 31,522 28,464 ‐ long‐term debt 23,827 20,139 ‐ current portion of long‐term debt 2,388 3,434 ‐ short‐term debt 5,334 4,929

- other non-current assets (see note 8) (27) (38)

less:

Cash and cash equivalents (8,365) (8,100) Financial assets measured at fair value through profit or loss (6,723) (6,991) Financing receivables for non‐operating purposes (see note 14) (5,163) (3,845) Net borrowings before lease liabilities ex IFRS 16 11,271 9,528 Lease liabilities, made up of: 5,441 5,700

- long‐term lease liabilities 4,358 4,437

- current portion of long‐term lease liabilities 1,083 1,263 Total net borrowings post lease libilities ex IFRS 16 ⁽ᵃ⁾

16,712 15,228

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 73,642 68,015June 30, 2026 December 31, 2025

(a) For details on net borrowings see also note 17 to the condensed consolidated interim financial statements.Notes to the

Consolidated

Financial

StatementPartial

amounts from

statutory

schemeAmounts of the

summarized

Group schemePartial

amounts from

statutory

schemeAmounts of

the

summarized

Group scheme

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 31

SUMMARIZED GROUP CASH FLOW STATEMENT

Items of Summarized Cash Flow Statement and confluence/reclassification of items in the statutory scheme

(€ million)

Net profit (loss) - continuing operations 2,697 (559) Net profit (loss) - discontinued operations 1,958 2,315 Net profit (loss) 4,655 1,756 Adjustments to reconcile net profit (loss) to net cash provided by operating

activities:

Depreciation, depletion and amortization and other non monetary items 1,776 3,558

- depreciation, depletion and amortization 3,398 3,696

- impairment losses (impairment reversals) of tangible, intangible and right of use, net1,474 641

- write-off of tangible and intangible assets 120 (13)

- share of profit (loss) of equity-accounted investments (1,158) (649)

- other changes (2,077) (125)

- net change in the provisions for employee benefits 19 8 Gains on disposal of assets, net (5) (6) Dividends, interests, income taxes and other changes 2,700 2,384

- dividend income (60) (100)

- interest income (223) (202)

- interest expense 629 607

- income taxes 2,354 2,079 Cash flow from changes in working capital (1,516) 192

- inventories (1,729) 401

- trade receivables (1,233) 2,655

- trade payables 1,794 (2,437)

- provisions for contingencies (423) (439)

- other assets and liabilities 75 12 Dividends received 868 879 Income taxes paid, net of tax receivables received (2,051) (2,230) Interests (paid) received (730) (631)

- interest received 87 117

- interest paid (817) (748) Net cash provided by operating activities 5,697 5,902 Investing activities (4,008) (3,773)

- tangible assets (4,478) (3,707)

- intangible assets (163) (258)

- other changes 633 192 Investments and purchase of consolidated subsidiaries and businesses (800) (351) ‐ investments (301) (351) ‐ consolidated subsidiaries and businesses net of cash and cash

equivalent acquired(499)

Disposals (271) 84

- tangible assets 12 66

- intangible assets

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

- tax disposals

- investments 27 18

- other changes (348) Other cash flow related to capital expenditure, investments and disposals 255 (175) ‐ investment of securities and financing receivables held for operating purposes (33) (35) ‐ change in payables in relation to investing activities 400 (184) ‐ disposal of securities and financing receivables held for operating purposes 43 16 ‐ change in receivables in relation to disposals 130 220

- other changes (285) (192) Free cash flow 873 1,687First Half 2026 First Half 2025

Partial amounts

from statutory

schemeAmounts of

the

summarized

Group schemePartial amounts

from statutory

schemeAmounts of the

summarized

Group scheme

ENI 32

ENI INTERIM CONSOLIDATED REPORT 202 6

SUMMARIZED GROUP CASH FLOW STATEMENT (CONTINUED)

Items of Summarized Cash Flow Statement and confluence/reclassification of items in the statutory scheme (€ million)Partial amounts

from statutory

schemeAmounts of

the

summarized

Group schemePartial amounts

from statutory

schemeAmounts of

the

summarized

Group scheme

Free cash flow 873 1,687 Borrowings (repayment) of debt related to financing activities (830) (190) ‐ net change of securities and financing receivables (830) (190) Changes in short and long‐term finance debt 2,460 (1,324)

- increase in long-term debt 5,116 3,721

- repayments of long-term debt (2,906) (4,803)

- increase (decrease) in short-term debt 250 (242) Repayment of lease liabilities (669) (675) Dividends paid and changes in non‐controlling interest and reserves (2,527) 1,564

- net reimbursement (capital contribution) to (by) non-controlling interest 709

- net purchase of treasury shares (849) (666)

- disposal (acquisition) of additional interests in consolidated subsidiaries 3,069 ‐ dividends paid to Eni's shareholders (1,552) (1,524) ‐ dividends paid to non‐controlling interest (126) (33)

- other contributions 9 Net issue (repayment) of perpetual hybrid bond 804 126

- issue of perpetual subordinated bonds 988 231

- payments on perpetual subordinated bonds (184) (105) Effect of changes in consolidation, exchange differences and cash and cash equivalent 23 (204)

- effect of exchange rate changes on cash and cash equivalents and other changes 23 (204)

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENT 134 984First Half 2026 First Half 2025

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 33

DISCONTINUED OPERATIONS

PLENITUDE – RESULTS OF OPERATIONS AND LIQUIDITY FROM THIRD -PARTY TRANSACTIONS

(€ million) 2026 2025 Change Total Revenues 5,407 5,685 (278) Operating expenses, depreciation, depletion, amortization and impairments (3,218) (3,246) 28 Operating profit (loss) 2,189 2,439 (250) Finance income (expense) 7 (81) 88 Profit (loss) before gains on disposal of assets 2,195 2,338 (143) Income taxes (237) (23) (214) Net profit (loss) 1,958 2,315 (357)

of which:

- Eni's shareholders 1,367 2,121 (754)

- Non-controlling interest 591 194 397 Net borrowings 250 122 128 Net cash provided by operating activities 1,930 2,791 (861) Capital expenditure 219 340 (121)First Half

PLENITUDE – RESULTS OF OPERATIONS AND LIQUIDITY FROM THIRD -PARTY AND

INTERCOMPANY TRANSACTIONS

(€ million) 2026 2025 Change Total Revenues 5,431 5,708 (277) Operating expenses, depreciation, depletion, amortization and impairments (4,605) (5,644) 1,039 Operating profit (loss) 826 64 762 Finance income (expense) (52) (41) (11) Profit (loss) before income taxes 773 3 770 Income taxes (237) (23) (214) Net profit (loss) 536 (20) 556

of which:

- Eni's shareholders 374 (19) 393

- Non-controlling interest 162 (1) 163 Net borrowings 3,274 2,061 1,213 Net cash provided by operating activities 95 542 (447) Capital expenditure 219 340 (121)First Half

ENI 34

ENI INTERIM CONSOLIDATED REPORT 202 6

NON -GAAP RESULTS3

(€ million) 2026 2025 Change % Ch.

Operating profit (loss) 4,071 3,490 581 16.6 Exclusion of inventory holding (gains) losses (585) 358 Exclusion of special items 2,448 641 Adjusted operating profit (loss) 5,934 4,489 1,445 32.2 main JV/Associates adjusted EBIT 2,977 1,873 1,104 58.9 Proforma adjusted EBIT 8,911 6,362 2,549 40.1 Breakdown by segment:

Exploration & Production 8,126 5,730 2,396 41.8 Global Gas & LNG Portfolio and Power 830 860 (30) (3.5) Enilive 433 224 209 93.3 Plenitude 439 374 65 17.4 Refining, Chemicals and Sites in transformation (300) (527) 227 43.1 Corporate and other activities (526) (477) (49) (10.3) Impact of unrealized intragroup profit elimination and other consolidation adjustments (91) 178 (269) Adjusted profit (loss) before taxes 6,235 4,949 1,286 26.0 Adjusted net profit (loss) 3,635 2,546 1,089 42.8 Net profit (loss) 4,655 1,756 2,899 ..

Net profit (loss) attributable to Eni's shareholders 4,390 1,715 2,675 ..

Exclusion of inventory holding (gains) losses (398) 246 Exclusion of special items (357) 585 Adjusted net profit (loss) attributable to Eni's shareholders 3,635 2,546 1,089 42.8First Half

In the first half of 2026, the Group proforma adjusted EBIT of €8,9 11 million increased by 40% compared to the same period of 2025 due to strong performance at E&P, GGP and the Transition satellites. The factors which drove the Group’s performance were better realizations on equity production, higher biofuels margins , better volume/mix effects , the positive outcome of restructuring the chemicals sector and other cost efficiencies.

In the first half of 2026 adjusted profit before taxes was €6, 235 million, 2 6% higher than the first half of 2025, reflecting the trend in the Group adjusted EBIT and higher profits reported at equity -accounted entities, partly offset by increased finance expenses.

In the first half of 2026 adjusted net profit attributable to Eni’s shareholders of €3, 635 million increased by 4 3% compared to the first half of previous year, factoring in a lower tax rate down to 39% 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.

3 Explanatory notes and tables detail certain other alternative performance indicators in line with guidance provided by ESMA g uidelines on Alternative performance measures (ESMA/2015/1415), published on October 5, 2015. For a detailed explanation, see secti on “Alternative performance measures” in the following pages of this interim report. The results of the business segments reflect their contribution to Eni’s consolidated results.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 35

SPECIAL ITEMS

(€ million) 2026 2025 Special items of operating profit (loss) 2,448 641

- environmental charges (expense recovered from third-parties) 143 192

- impairment losses (impairment reversals), net 1,474 641

- net gains on disposal of assets (5) (6)

- risk provisions 19 17

- provisions for redundancy incentives 32 34

- commodity derivatives 72 (53)

- exchange rate differences and derivatives 193 (279)

- other 520 95 Net finance (income) expense (201) 269

of which:

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

of which:

- net gain on business combination (2,088) Income taxes (251) (140) Total special items of net profit (loss) (440) 616

attributable to:

- Eni's shareholders (357) 585

- Non-controlling interest (83) 31First Half

The pre -tax special items recorded in operating profit (net charges of €2,448 million in the first half of 2026) are mainly related to the following segments:

• E&P: net charges of €1,757 million 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 revisions (€1,203 million ); credit loss provisions (€92 million ) and environmental charges (€15 million );

• GGP and Power: net charges of €432 million mainly relat ing 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 million ). The reclassification of the positive balance of €152 million 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 million 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 million );

• Refining, Chemicals and Sites in transformation: net charges of €534 million 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 million ) and to the fair values of commodity derivatives lacking the formal criteria to be classified as hedges under IFRS (€178 million ) as well as environmental charges of €90 million .

ENI 36

ENI INTERIM CONSOLIDATED REPORT 202 6

RESULTS BY SEGMENT

EXPLORATION & PRODUCTION

(€ million) 2026 2025 Change % Ch.

Upstream turnover 10,811 10,107 704 7.0 Proforma adjusted EBIT 8,126 5,730 2,396 41.8 of which: main JV/Associates 2,867 1,841 1,026 55.7 Operating profit (loss) of subsidiaries 3,502 3,446 56 1.6 Exclusion of special items 1,757 443 Adjusted operating profit (loss) of subsidiaries 5,259 3,889 1,370 35.2 Adjusted profit (loss) before taxes 5,867 4,413 1,454 32.9 tax rate (%) 36.4 46.2 (9.8) Adjusted net profit (loss) 3,729 2,372 1,357 57.2 Results also include:

Exploration expenses: 220 86 134 ..

- prospecting, geological and geophysical expenses 134 86 48 55.8

- write-off of unsuccessful wells 86 0 86 ..First Half

In the first half of 2026, Exploration & Production reported a proforma adjusted EBIT of €8,1 26 million, increasing by 42% compared to the first half of 2025 due to favorable volume/mix effects, cost discipline, higher crude oil realized prices in USD (the Brent marker was up by 29%) and higher gas realizations (up by 9%), offset by the negative impact of exchange rate translation of dollar -denominated results of foreign subsidiaries (the EUR/USD exchange rate was up by 7%).

The segment reported an adjusted net profit of €3,729 million, a n increase of 57% compared to the first half of 2025 and included a higher contribution from JVs and associates.

The tax rate was 36%, lower than the first half of 2025, due to a more favorable geographical mix of pretax profit.

Main JV/Associates (€ million) 2026 2025 Change % Ch.

Adjusted operating profit (Eni's share) 2,867 1,841 1,026 55.7 of which: Vår Energi 1,920 1,009 911 90.3 Azule Energy 463 450 13 2.9 Adjusted net profit 791 495 296 59.8 Total dividends 558 596 (38) (6.4) Hydrocarbon production (kboe/d) 546 432 114 26.4First Half

GLOBAL GAS & LNG PORTFOLIO AND POWER

(€ million) 2026 2025 Change % Ch.

Sales from operations 9,433 9,034 399 4.4 Proforma adjusted EBIT 830 860 (30) (3.5)

GGP 783 631 152 24.1

of which: main JV/Associates 17 19 (2) (10.5) Power 47 229 (182) ..

Operating profit (loss) of subsidiaries 381 1,358 (977) ..

Exclusion of special items 432 (517) Adjusted operating profit (loss) of subsidiaries 813 841 (28) (3.3) Adjusted profit (loss) before taxes 821 852 (31) (3.6) Adjusted net profit (loss) 515 542 (27) (5.0)First Half

In the first half of 2026, the Global Gas & LNG Portfolio business achieved a proforma adjusted Ebit of € 783 million, increasing by 24% compared to the first half of 2025 benefitting from the continued asset portfolio optimizations and specific benefits relating to renegotiations and settlements .

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 37

The Power generation business from gas -fired plants reported a proforma adjusted Ebit of €47 million, down by €182 million.

The y -o-y comparison is affected by the circumstance that the first half of 2025 results were impacted by a one -off item.

The Global Gas & LNG Portfolio and Power segment achieved an adjusted net profit of €515 million, a sightly decrease ( down by €27 million ) compared to the first half of 202 5.

TRANSITION BUSINESSES

ENILIVE

(€ million) 2026 2025 Change % Ch.

Sales from operations 11,674 9,536 2,138 22.4 Proforma adjusted EBITDA 592 381 211 55.4 Proforma adjusted EBIT 433 224 209 93.3 of which: main JV/Associates 30 (24) 54 225.0 Operating profit (loss) of subsidiaries 375 174 201 115.5 Exclusion of inventory holding (gains) losses (35) 42 Exclusion of special items 63 32 Adjusted operating profit (loss) of subsidiaries 403 248 155 62.5 Adjusted profit (loss) before taxes 414 213 201 94.4 Adjusted net profit (loss) 301 141 160 113.5First Half

In the first half of 2026 the Enilive business reported a proforma adjusted Ebit of € 433 million, up by 93% compared to the same period of 2025, mainly thanks to the biorefining business which benefited from an improved market scenario, despite the Venice plant shutdown.

Proforma adjusted EBITDA amounted to € 592 million , up by 55% compared to a profit of €381 million in the first half of 2025.

PLENITUDE

(€ million) 2026 2025 Change % Ch.

Sales from operations 5,305 5,603 (298) (5.3) Proforma adjusted EBITDA 541 614 (73) (11.9) Proforma adjusted EBIT 439 374 65 17.4 Operating profit (loss) of subsidiaries 826 64 762 ..

Exclusion of special items (427) 302 Adjusted operating profit (loss) of subsidiaries 399 366 33 9.0 Adjusted profit (loss) before taxes 393 336 57 17.0 Adjusted net profit (loss) 264 223 41 18.4First Half

In the first half 2026 Plenitude reported a proforma adjusted Ebit of € 439 million, up by 17% compared to the first half of 2025, benefiting from volume growth in the renewables business and the halting of depreciation pending the proposed deconsolidation transaction .

Proforma adjusted EBITDA amounted to € 541 million , decreasing from € 614 million reported in the first half of 2025.

ENI 38

ENI INTERIM CONSOLIDATED REPORT 202 6

REFINING , CHEMICALS AND SITES IN TRANSFORMATION

(€ million) 2026 2025 Change % Ch.

Sales from operations 10,553 9,465 1,088 11.5 Proforma adjusted EBIT (300) (527) 227 43.1 Refining⁽ᵃ⁾ 66 (100) 166 ..

of which: main JV/Associates 23 29 (6) (20.7) Chemicals (223) (427) 204 47.8 Sites in transformation (143) (143) Operating profit (loss) of subsidiaries (302) (1,302) 1,000 76.8 Exclusion of inventory holding (gains) losses (555) 427 Exclusion of special items 534 319 Adjusted operating profit (loss) of subsidiaries (323) (556) 233 41.9 Adjusted profit (loss) before taxes (322) (550) 228 41.5 Adjusted net profit (loss) (316) (507) 191 37.7First Half (a)Due totheshutdown ofthegasoline production unit inthefirst half 2026, theLivorno hub, currenty being upgraded toabiorefinery, has been reclassified tothesegment “Sites in transformation” effective 1st January 2026.

In the first half of 2026, the Refining , Chemicals and Sites in transformation segment reported a proforma adjusted loss of €300 million, compared to a loss of € 527 million of the first half of 2025 (up by 43%) .

The Refining business , including contribution from the ADNOC R&GT associate, reported a proforma adjusted profit of €66 million , a better performance compared to the loss of €100 million reported in the first half of 2025. 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 .

The Chemical business, managed by Versalis, reported a proforma adjusted loss of € 223 million in the first half of 2026, a significatively improved performance compared to the loss of €427 million in the first half of 2025, 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 d emands and competitive pressures from players with advantaged cost structures. Polyethylene spreads have returned to unprofitable territory in July.

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 transformat ion phase, reported a proforma adjusted loss of € 143 million due to ongoing expenses for plant restructuring.

The Refining , Chemical and Sites in transformation segment reported a n adjusted net loss of €316 million and decreased from the loss of € 507 million of the first half of 2025 (up by 38%) .

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 39

ALTERNATIVE PERFORMANCE MEASURES (NON -GAAP MEASURES)

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 hedg e 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 performanc e, 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 cost method of inventory accounting as r equired 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 entities, 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 model s.

Non-GAAP financial measures should be read together with information determined by applying IFRS and do not stand in for them. Other 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 and net profit are determined by excluding inventory holding gains or losses, special items and, in determining the business segments’ adjusted results, finance charges on finance debt and interest income. The adjusted operating profit o f 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. Ac cordingly, also currency translation effects recorded through profit and loss are reported within business segments’ adjusted operating profit. The taxation effect of the items excluded from adjusted operating or net profit is determined based on the speci fic 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 equiv alents not related to operations. Therefore, the adjusted net profit of business segments includes finance charges or income deriving from certain segment operated assets, i.e., interest income on certain receivable financing and securities related to oper ations and finance charge pertaining to the accretion of certain 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 b e 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 fu ture ones. Exchange rate differences and derivatives relating to industrial activities and commercial payables and receivables, particularly exchange rate derivatives 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 exchange risks is made centrally by netting off naturally -

occurri ng opposite positions and then dealing with any residual risk exposure in the derivative market. Finally, special items

ENI 40

ENI INTERIM CONSOLIDATED REPORT 202 6

includ e the accounting effec ts of fair-valued commodity derivative s relating to commerc ial exposures, in additi on to those whic h lack th e criteria to be designed as hedges, also t hose whic h are not eligible for the ow n use exemption, including the ineffective port ion of cash flow hedges, as wel l as th e accounting effec ts of commodity a nd exchange ra tes derivatives wheneve r it is deemed that the underlying transacti on is expected to occur in future reporting periods.

Correspondently, spec ial charges/g ains also includ e the evalua tion effec ts relating to assets/liabilitie s utilized in a natural hedg e relat ion to offse t a mark et risk, as in the case of accrued currency differences at finance deb t denominated in a currency other than the reporting currency, where the cash outflows for the reimbursem ent are matched by highly probable cash inflow s in the sam e currency . The deferra l of both th e unrealized port ion of fair-valued commodity and oth er derivatives and evalua tion effec ts are reversed to future reporting periods w hen the underlying transacti on occurs.

As provided for in Decis ion No. 15519 of July 27, 2006 of the Italian mark et regulat or (CONSOB), non-recur ring material income or charges are t o be clearly reported in the management’s disc ussion and financi al tables.

EBITDA

Earnings Be fore Interest, Taxes, Deprec iation and Amortization, is calculated summing up th e operating p rofit and DD&A.

Represents the company’s profitability as a result of operations management.

Gearing

Gearing is calculated as th e ratio betwee n net borrowing s and cap ital employed net and measures how m uch of capital employed net is financed recur ring to third-party funding. Gearing before le ase liabilities 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 underway.

Adjusted net cash before chang es in working capital at replacement cost This is defined as net cash provided from operating activities before changes in working capital a t replacem ent cost. It also excludes certa in non-recur ring charge s suc h as extraordinary cred it allowances and, conside ring the hig h mark et volatility, change s in the fair value of commodity derivative s lacking th e form al criteria to be designed as hedges, including derivatives whic h were not eligible for the ow n use exemption, th e ineffective port ion of cash flow hedges, as wel l as th e effec ts of certa in settled commodity derivative s wheneve r it is deemed that th e underlying transaction is expected to occur in future reporting periods.

Free cash flow Free cash flow represents the link existing betwee n changes in cash and cash equivalents (deriving from the statutory cash flow s statement) and in net borrowing s (deriving from the summarized cash flow statement) that occurred from the beginning of th e period to the end of period . Free cash flow is t he cash in exces s of cap ital expenditur e need s. Starting from free cash flow it is possible to determine either: (i) change s in cash and cash equivalents for the period by adding/deductin g cash flow s relating to financi ng debts/receivable s (issuance/repaym ent of deb t and receivable s related to financing activities), shareholders’ equity (dividends paid, net repurchase of own shares, cap ital issuance) and th e effect of changes in consolidat ion and of exchange rate differences; (ii) changes in net borrowing s for the period by adding/deducting cash flows relating to shareholders’ equity and the effec t of changes in consolidation and of exchange rate differences.

Net borrowings

Net borrowing s is calculated as tota l finance deb t less cash, ca sh equivalent s and certa in very liquid investm ents not relate d to operations, including am ong oth ers non-operating financi ng receivable s and securities not related to operat ions. Financial activities are qualified as “not related to operations” w hen these are not strictly related to the business operations.

Proforma adjusted EBIT Is the measure adding th e operating marg in of the equity accounted entities to the adjusted EBIT, introduced by the managem ent to reflec t the increasing contribution from the JV/associates als o in connec tion with the Eni satellite model.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 41

Reconciliation tables of Non -GAAP results to the most comparable measures of financial performance determined in accordance to GAAPs First Half 2026 (€ million)

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 (expense recovered from third-parties) 15 48 90 (10) 143 143

- impairment losses (impairment reversals), net 1,203 11 187 73 1,474 1,474

- impairment of exploration projects

- 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) 2 2,450 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 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) 2,186Discontinued operations

exclusion

CONTINUING

OPERATIONSGROUPExploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Corporate and other

activities

Impact of unrealized

intragroup profit

eliminationRefining, Chemicals

and Sites in

transformationPlenitude

ENI 42

ENI INTERIM CONSOLIDATED REPORT 202 6

First Half 2025 (€ million)

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 (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) 489Discontinued operations

exclusion

CONTINUING

OPERATIONSGroupExploration &

Production

Global Gas & LNG Portfolio and Power

Enilive

Corporate and other

activities

Impact of unrealized

intragroup profit

eliminationRefining, Chemicals

and Sites in

transformationPlenitude

RECONCILIATION OF GROUP PROFORMA ADJUSTED EBIT

(€ million) 2026 2025 % Ch.

E&P adjusted Ebit of consolidated subsidiaries 5,259 3,889 35.2 main JV/Associates adjusted Ebit 2,867 1,841 55.7 E&P proforma adjusted Ebit 8,126 5,730 41.8 GGP and Power adjusted Ebit of consolidated subsidiaries 813 841 (3.3) main JV/Associates adjusted Ebit 17 19 (10.5) GGP and Power proforma adjusted Ebit 830 860 (3.5) Transition Businesses adjusted Ebit of consolidated subsidiaries 802 614 30.6 main JV/Associates adjusted Ebit 70 (16) ..

Transition Businesses proforma adjusted Ebit 872 598 45.8 Refining, Chemicals and Sites in transformation adjusted Ebit of consolidated subsidiaries (323) (556) 41.9 main JV/Associates adjusted Ebit 23 29 (20.7) Refining, Chemicals and Sites in transformation proforma adjusted Ebit (300) (527) 43 Other segments adjusted Ebit (526) (477) (10.3) Impact of unrealized intragroup profit elimination (91) 178 Group proforma adjusted Ebit ⁽ᵃ⁾ 8,911 6,362 40.1First Half (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.

CONDENSED CONSOLIDATED

INTERIM FINANCIAL STATEMENTS INTERIM CONSOLIDATED REPORT ANNEX 43

ADJUSTED GROUP NET CASH PROVIDED BY OPERATI NG ACTIVITIES

(€ million) 2026 2025 Change Group net profit (loss) 4,655 1,756 2,899 Adjustments to reconcile net profit (loss) to net cash provided by operating activities:

- depreciation, depletion and amortization and other non monetary items 1,776 3,558 (1,782)

- net gains on disposal of assets (5) (6) 1

- dividends, interests, taxes and other changes 2,700 2,384 316 Changes in working capital related to operations (1,516) 192 (1,708) Dividends received by investments 868 879 (11) Taxes paid (2,051) (2,230) 179 Interests (paid) received (730) (631) (99) Net cash provided by operating activities 5,697 5,902 (205)First Half

Group n et cash provided by operating activities amounted to € 5,697 million in the first half of 2026 .

Adjusted net cash before changes in working capital at replacement cost was €7,347 million in IH ’26 and is net of the

following items:

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

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

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

basis ;

- accrued post -merger balancing proceed s and other minor items.

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

(€ million) 2026 2025 Net cash provided by operating activities 5,697 5,902 Changes in working capital related to operations 1,516 (192) Exclusion of commodity derivatives 72 (53) Exclusion of inventory holding (gains) losses (585) 358 Net cash before changes in working capital at replacement cost 6,700 6,015 Extraordinary charges (gains) 647 174 Adjusted net cash before changes in working capital at replacement cost 7,347 6,189First Half

Net borrowings before lease liabilities ex IFRS 16 increased by around €1.74 billion in the first half of 2026. The main inflows comprised the adjusted operating cash flow (€7.35 billion ) and the issuance of a hybrid bond (€0.99 billion ) which were utilized to fund cash outflows related to organic capex (€3.71 billion ), working capital needs (€1.52 billion ), dividend payments to Eni’s shareholders and share repurchases of €2.53 billion (dividend payments of €1.6 billion and share repurchases of €0.9 billion ), acquisition of consolidated subsidiaries and other portfolio activities (€1 billion ) and repayment of lease liabilities and hybrid bond interest (€0.85 billion ).

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Risk Factors

The main strategic, industrial, operational, regulatory and legal risk factors to which the Group is exposed do not change significantly compared to 202 5; therefore, they are summarized in this section, referring for further details to the 2025 Annual Report.

Eni's results are exposed to the volatility of the price of oil and gas The price of crude oil is the m ost significant factor that influences Eni's financial results and industrial prospects and, like other commodities, has a history of volatility due to its correlation with the economic cycle and the evolution of the global sociopolitical framework.

The fundamentals of the physical market are the balance between global oil supply and demand and the level of inventories.

In the short term, oil demand is a function of the growth of the world gross domestic product, international trade flows, the level o f consumer and business confidence, the monetary policies of central banks, as well as affected by exogenous factors of various kinds (geopolitical tensions, wars, pandemics, etc.) that can induce industrial operators to increase or decrease inventories. P roduction has a lower degree of elasticity in the short term. When supply exceeds demand with a consequent increase in inventories, the price of crude oil declines; the opposite happens when the supply is short. Price movements driven by physical factors are amplified by the positioning of financial operators ( Commodity Trading Advisor s, hedge funds, money managers, etc.) with upward or downward bets in the futures market, which reflect expectations about the future evolution of supply and demand in the short -term and the possible impacts of geopolitical and macroeconomic phenomena on global balance. Financial exchanges fuel volatility, as the daily volumes traded in the derivatives markets are significan tly higher than physical exchanges. The volatility relate d to these factors significantly influences the predictability of the Group's consolidated results in the short -term, although the forward pricing structure can be a valid reference.

Oil volatility reached record levels during the first half of 2026. The outbreak of the crisis in the Middle East with acts o f hostility between the US A, Israel and Iran caused the sudden "spike" of prices with values close to 140 $/bbl for the spot (120 $/bbl for the future s) in March through the end of April, due to unprecedented interruptions in the flow of crude oil, gas and products for the closure of the Strait of Hormuz, through which about 10% of the global crude oil supply transits, and significant damage to oil and gas infrastructure s of the Gulf countries. However, the risk of shortages in the physical market has been mitigated by the prompt release of commercial and strategic inventories from the US A and other OECD countries and above all by the significant reduction in imports by China, which has leveraged its inventories and the reduction of stat e refinery runs to manage the temporary shortage of raw material. This ability of the market to adapt coupled with the mitigation of the risk of shortage and expectations f or a rapid resolution of the crisis have led financial operators to liquidate long positions in the futures market, triggering an equally fast correction of the price which , through May and June , lost 50% of its value compared to the peaks , to settle to around 70 $/bbl. In the first half of 2026, the average price was around 93 $/bbl with a positive effect on the realiz ations of equity crude oils.

Barring unpredictable geopolitical developments, the trend of crude oil prices in the second half of 2026 and in the short -

term is exposed to the risks of slowing growth or, in the "worst case scenario ", of a possible contraction of the global economy, which is weighed down by numerous factors of uncertainty, such as: the protectionist measures promoted by the USA administration, the financial instability resulting from sovereign debts, the increase in long -term interest rates and inflation, the uncertain recovery of China and the prolongation of the Russian -Ukrainian conflict. In addition, the OPEC+ alliance decided to accelerate the re -entry into the market of production cuts made in past years, while some member countries decided to leave the cartel to pursue their own production targets. Given these risks, Eni expects price to normalize in the second half of the year for an annual average of 85 $/bbl.

The events related to the Gulf crisis have not changed management's assessment of the long -term oil scenario.

Long -term price forecasts are based on complex subjective assumptions made by management about the future evolution of crude oil demand, influenced by numerous factors such as population growth, improving living standards, changing consumer preferences, risks of oil and gas replaced by other energy carriers as part of the economy's transition to a "low carbon" model , the role of technologies and the development of the supply . The long -term price forecast incorporates the best management estimates relating to the factors indicated and assumes a "mid -cycle" price level consistent with the expectations of the major importing countries and sufficiently remunerative with respect t o the marginal costs of production

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to stimulate an adequate level of supply with respect to the expected evolution of demand. This long -term price level is unchanged compared to the forecast adopted in the 2025 annual financial report; therefore, there is no indicator of impairment of Eni's assets in the Oil&Gas sector linked to the price effect .

The Group has identified indicators of impairment of certain mature cash generating units in relation to the re-prioritization of funds allocation away from the recovery of the residual mineral potential of long -life fields , for which no projects are underway that have involved the signing of contracts with third -party suppliers , towards new investment opportunities in Eni's current upstream portfolio in line with the financial framework of spending selection and capital discipline . For these mature assets, management has updated the impairment test methodology to align it with the fundamentals of Eni's upstream model, excluding future cash flows associated with the development of undeveloped probable reserves (P2 undeveloped) . This adjustment of estimate , together with t he revision of the production profile , led to write -downs of about €1.47 billion related to assets in Italy, Australia , the USA , Egypt and Congo .

Relating to natural gas, the forecast of a gradual decline in the price in the medium -to-long term is confirmed following the start -up of significant liquefaction capacity in the USA, Qatar and other countries and the growth of renewables that will keep the market in balance.

The Group's results, mainly in the Exploration & Production segment, are exposed to the volatility of oil prices and, to a le sser extent, natural gas. The reduction in hydrocarbon prices has negative effects on revenues, operating profit and cash flows at the consolidated level, leading to a decline in results in the year -on-year comparison. In Eni's current portfolio, exposure to price risk concerns approximately 40% of the Group's oil and gas production. This exposure, by strategic choice, is not the subj ect of management and/or economic coverage activities, except in particular business or market situations.

The remaining part of the Group's production is not directly exposed to price risk, as it is governed by the Production Shari ng Agreement ("PSA") contractual scheme, which guarantees the recovery of a fixed amount of the costs incurred through the allocati on of a corresponding number of barrels, thus exposing it to a risk related to the number of barrels.

The Group updates every year, on the basis of the evolution of the portfolio, the analysis of the variability of the main consolidated results (operating profit and operating cash flow) to movements in the price of crude oil: for 2026, Eni estimates that a change in the price of Brent oil of 1 $/bbl compared to the forecast price of 85 $/bbl, results in a change in operating cash flow before working capital at replacement cost of approximately €0.11 billion and operating profit of €0. 16 billion; while a gas price movement of about 8 % is needed to have effects similar to those of crude oil. These sensitivity analyses are considered valid for small price variations compared to the forecast. Oil & Gas is a business that requires significant finan cial resources for the exploration and development of hydrocarbon reserves. Historically, upstr eam investments have been financed through self -financing, proceeds from disposals and by resorting to new debt through the issuance of new bonds or using credit lines. The Group's operating cash flows and access to the capital market are subject to severa l variables, such as: (i) the amount of the Group's prove d reserves; (ii) the volume of crude oil and natural gas that the Group is able to produce and sell from existing wells; (iii) the selling prices; (iv) the ability to discover and put into production new reserves; (v ) the ability and willingness of banks and financial institutions and investo rs to grant credit/subscribe to the bonds issued by Eni to support the Group's development programs, given the strategic risk of the energy transition and the increasingly stringent constraints in the assessment of the ESG metrics of creditor companies applied by financial institutions. The profitability of upstream projects is exposed to the risks of rising input costs in relation to the current inflationary pressures due to the complex geopolitical scenario.

A decline in oil and gas prices for prolonged periods could have material negative effects on the Group's profitability, cash flows and industrial prospects, as a downturn scenario could limit the Group's ability to finance expansion projects, reducin g its ability to grow in the future in terms of production and revenues and to meet contractual obligations. Should this occur, the Group may be forced to review investment decisions and the feasibility of development projects and investment plans and, as a res ult of such review, may reschedule, postpone, reduce or cancel projects. A structural decline in hydrocarbon prices could lead to a revision of the book values of oil and gas properties, resulting in significant asset write -downs, as well as negative de -bookings of hydrocarbon reserves, should they become uneconomic in this type of environment.

Although Eni adopts measures to control the profitability of projects to verify their sustainability even in the presence of depressed price scenarios , operating as a financial framework based on selectivity in investment decisions and the maintenance of an adequate level of capitalization and liquidity reserves, the occurrence of these risks could negatively aff ect business prospects, operating results, cash gen eration, Group liquidity and shareholder s returns.

The refining and chemical businesses are exposed to the volatility of the economic cycle and structural weaknesses in the

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European industries .

In the first half of 2026, Eni's oil refining business recorded a positive result due to the significant recovery in the SERM margin due to the lower global supply of refined products relating to geopolitical factors (plant shutdowns in the Middle East and Russia) and the decision of the Chinese authorities to reduce product exports in favor of the domestic market. However, Eni's results did not reflect fully the indicator margin due to higher shipping costs and other de -optimizations.

Relating to the structural weaknesses of the European chemical business, the cost position of which is significantly less competitive than Chinese, US and Middle Eastern producers, Eni launched a restructuring plan of Eni's main petrochemical hubs to convert them to transition businesses. In the firs t half of 2026, Eni’s chemical business managed by Versalis contained operating losses.

Eni's operating environment is significantly affected by the policies to contrast the effects of climate change implemented by the governments of numerous States following the commitments announced under the Paris Agreement, reiterated and updated at subsequent COPs, as well as by the evolution of consumer preferences towards increasingly decarbonized products.

The transition of the economy towards a "carbon -neutral " model and the spread of more environmentally sustainable consumption models (such as electric vehicles, "plastic -free" products and greater energy efficiency) could lead to a structural decrease in hydrocarbon demand in the medium -to-long term. Uncertainties about demand trends and the feasibility/profitability of decarbonization technologies make long -term investment decisions riskier. In addition, Eni's activities in the Oil&Gas sector expose the Group to various regulatory, legal and reputational risks that could negatively affect the profitability and performance of Eni shares through an increase in costs and liabilities, restrictions and prohibi tions of various kinds, reduced a ccess to financial markets and a possible increase in the cost of capital for the Group.

Eni is committed to the execution of a portfolio repositioning strategy based on gradually reducing the weight of hydrocarbons to benefit the growth of renewable energy, biofuels, sustainable and environmentally friendly chemicals, as well as the developme nt of emission capture/abatement technologies and lower carbon energy carriers.

Eni projected results of operations and cash flow for the FY 2026 are exposed to the risk of the global economy slowdown and uncertainties in connection with the complex geopolitical situation due to the persistence of Russia’s military invasion of Ukraine, the tense situation in the Middle East and the deteriorating commercial relationships between the United States, Europe and China that could trigger global economic shock.

The persistence of systemic risks and uncertainty and volatility in financial and energy markets can affect global manufacturing activity, the supply chain and consumer, business and investor confidence, resulting in delays or stoppage in spending and inve stment decisions. These conditions could lead to a reduction in demand for raw energy materials and a consequent reduction in prices, negatively affecting the Group's economic results, cash flows and the implementation of the Group's business plans.

The most important exposure of Eni to Russia is relating to the ongoing long -term contracts for the purchase of natural gas from Russian state -owned company Gazprom and its affiliates, with take -or-pay clauses. I t is necessary to go back to 2022 to record volumes supplied from Russia which represented a material amount of our global portfolio of natural gas supplies at the time . From that year onwards, gas supplies from Russia have come a halt due to the unilateral decision from the Russian supplier to suspend deliveries to Eni, against the backdrop of a commercial dispute between the two parties . Eni is aiming at terminating the current supply contracts with Russian counterparties in the shortest possible timeframe. The process of replacing Russian -origin natural gas, including terminating existing contracts, may entail operational and financial risks which may be significant.

Eni is exposed to the risks of fluctuations in commodity prices, exchange rates of the euro with the main currencies, in particular the US dollar, and interest rates that could lead to a decrease in the book value of assets or an increase in liab ilities or a neg ative impact on expected cash flows.

Eni is exposed to the risk of default of commercial and financial counterparties, which may not fulfil their contractual obligations to the Group.

For further information on market risk, please refer to the Notes to the consolidated financial statements of the Annual Repo rt 2025 (note no. 28 Guarantees, Commitments and Risks).

Eni's upstream activity is mainly conducted in non -OECD countries characterized by different risks in the operating

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environment and associated with the instability of the political, institutional, social and legal framework.

Such instability may cause unpredictable developments, such as internal conflicts, revolutions, the establishment of non -

democratic regimes, social unrest, strikes, acts of vandalism of infrastructures and other forms of civil disorder and simila r phenomen a such as to temporarily or permanently compromise Eni's ability to operate in economic conditions and to secure access to hydrocarbon reserves. In addition, these countries are characterized by a certain degree of economic and financial weakness , due to their dependence on oil exports.

In the current scenario, the Eni Group is exposed to country risk in Libya, Venezuela and Egypt. As for Libya, one of the countries with the highest political risk in the recent past, despite the absence of a government of national unity and the persistence of internal conflicts intensified in recent months in the Tripoli area , the Country has maintained an overall internal stability in areas of activity that has allowed the normal conduct of mining activities in the first half of 202 6, as well as the continuation of ongoing development projects.

Following the restored political relations with the United States and the lifting of bans on crude oil exports, Venezuela's operating environment is gradually improving. In the first half of 2026, Venezuelan crude oil production and exports recovere d signi ficantly. These recent developments make Eni's prospects of recovering overdue receivables from the state -owned company Petróleos de Venezuela SA ("PDVSA") deriving from gas sales from the Perla field operated by the local company Cardón IV, a 50:50 joint venture with another international oil company, less uncertain. Eni has obtained "general licenses" from the US authorities that allow investment activities in the country and the possibility of marketing the oil. During the period, Eni collected current s upply invoices. However, at the moment Eni is not authorized to execute "debt swap" transactions. Industrial initiatives are being studied with PDVSA, such as the reactivation of some heavy oil fields owned by Eni, aimed at creating the conditions for the recovery of expired oil. Nominal credit exposure to PDVSA amounting to $2.7 billion are shown in the financial statements net of a provision for impairment losses of approximately 55%, which shows management's best estimate of the time value of the recover y plan.

The evolution of the economic, financial and political context of the countries in which the Group operates could affect Eni' s operating and investment choices, which could also, ultimately, decide to downsize the Group's presence in certain areas, with co nsequent possible negative consequences on the Group's economic and financial position.

The technical and operational complexity of the Group's activities, their scale and geographical scope, as well as the nature of the products expose the Group to significant health, safety and environmental risks.

Eni's industrial activities in the sectors of hydrocarbon research, development and production, refining, petrochemical production and hydrocarbon transport are exposed to operational risks related to the complexity of industrial operations and the chemica l-physical characteristics of raw materials and products (including flammability, toxicity, instability). Technical failures, malfunctions of equipment and plants, human error, acts of sabotage, containment leaks, well accidents, accidents to refineries an d petrochemical plants, adverse weather phenomena can cause damage to people, the environment and property of even significant proportions such as in the case of explosions, fires, leaks of crude oil, gas and products (from wells, platforms, tankers, pipel ines and depots ), release of contaminants into soil, groundwater and the aquatic environment, harmful emissions and other similar adverse consequences. There are risks that such events could take on catastrophic proportions. In addition, the environmental footprint of En i's activities is significant in terms of emissions considered climate -

altering, water withdrawals and other matrices.

The activities in which Eni operates are subject to strict national and international regulations to protect the environment, biodiversity, water resources, the health and safety of people, public safety and property. The charges and costs associated with the necessary actions to be implemented to comply with the obligations provided for by the regulations governing industrial activities in the hydrocarbons field constitute a significant recurring cost item in the financial statements. Eni adopted integrate d management systems, safety standards and operating practices of high quality and reliability to ensure compliance with environmental regulations and to protect the integrity of people, the environment, operations, property and the communities concerned. However, despite these measures and precautions, it is not possible to completely exclude the risk of accidents and other harmful events such as those described above or of incurring environmental liabilities that could have potentially material impacts on the Group's business, economic and financial results, development prospects and reputation, as well as returns for shareholders. Relating to historical contamination, with particular regard to Italy, Eni continues to be exposed to the risk of environmenta l liabilities and charges related to several sites that are currently inactive where it has conducted mineral -metallurgical and chemical activities in the past that were then closed, decommissioned or liquidated. In these sites, concentration levels of pollutants have emerged that are not in line with current environmental legislation. Eni's financial statements include the costs that it will have to incur in the future to carry out the remediati on and

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restoration of contaminated areas due to its industrial activities where there is a legal or other obligation and for which i t is possible to estimate the amount of the related costs in a reliable way (this also constitutes, in the implementation phases, a factor of uncertainty in relation to the complexity of the matter), regardless of the possible share of responsibility of oth er operators to whom Eni has taken over. It is possible that additional liabilities may be recognized in the future in relation to the results of ongoing environmental characterizations on sites of interest, based on current environmental legislation or future regulatory developments, the outcome of ongoing administrative or judicial proceedings, the emergence of new environmental li abilities and other risk factors.

Oil&Gas activities are subject to royalties and income taxes, which have a higher impact on pre -tax profit than other commercial activities.

Historically, the marginal tax rate in the Oil&Gas sector tends to rise in upwardly oil prices, making it more difficult for Eni to translate higher oil price into an increase in net profit. In addition, in these phases, extraordinary levies on the profits of oil companies are possible, such as windfall taxes, solidarity contributions and similar charges, with the intention of the tax administrations to spread the costs of the energy bill. Unfavorable changes in the tax rate applicable to the Group's pre -tax earnings in the Oil&Gas business would have a negative impact on future results of operations and cash flows.

Eni's competitive environment is characterized by volatile energy commodity prices and margins, limited product differentiation and complex relationships with the state -owned companies of the countries in which hydrocarbon reserves are located.

The company's competitiveness in this context requires continuous attention to technological innovation, cost efficiency and the effective management of capital resources.

Exploration, development and production of oil and natural gas require high level s of capital expenditures entailing long lead times for the return on invested capital and are subject to mining risk, price volatility, as well as significant operational risks depending on the nature of the operations. The Company may not be able to efficiently replace produced oil and gas reserves and the volumes of hydrocarbons that are recovered over the useful life of the fields may be lower than initial estimates due to uncertainty.

Mining risk is represented by the uncertainty of exploration activity that may fail due to the drilling of sterile wells or t he discovery of quantities of hydrocarbons that are not economic or insufficient to justify the completion of exploration wells as producers. In development activities, mining risk is due to the possible underperformance of reservoirs and the recovery of hydr ocarbon volumes lower than initial estimates due to the uncertainty and complexity of engineering assessments.

Hydrocarbon reserve development projects are characterized by long implementation and pay -back times and high financial exposure in the construct ion/commissioning phase, which exposes them to the risk of economic returns below the cost of capital due to unplanned increases in investment/operating costs, possible delays in the start of production and volatility i n hydrocarbon prices that could be lo wer than hired underlying the final investment decision (FID). In addition, numerous execution and operational risks can penalize the returns of these projects, such as unforeseen technical difficulties, failur e to meet deadlines/budgets by critical infras tructure providers (FPSO vessels, platforms, upstream plants), effectiveness of global contractors, timely issuance of authorizations by State Authorities and delays in the commissioning phases, as well as the possible occurrence of operational incidents i n particular in the field of offshore (such as explosions with uncontrolled release of oil or natural gas from accidented wells, so -called "blowouts", equipment malfunctions resulting in oil spills, gas spills, fires of wells, platforms or floating product ion units, marine collisions and other similar events).

Eni's future production levels depend on the company's ability to replace the reserves produced through successful exploration, the effectiveness and efficiency of development activities, the application of technological improvements able to maximize the recovery rates of the fields in production and the outcome of negotiations with the states holding the reserves. Failure to obtain adequate production replacement rates could adversely affect the Group's growth prospects, results, cash flow, liquidity and shareholder returns. The time -to-market of reserves is a critical factor for the profitability of the oil industry, given the technological and construction complexity of the projects, the financial exposure during the construction phase and the defer ral of positive cash flows. Industry is exposed to the risks of bottlenecks in supply chains and logistics, reduced availability of yards of construction, as well as increases in the cost of inputs such as raw material s (steel, cement), skilled labor and o ther inputs, as has occurred in recent years in relation to inflationary pressure in all production sectors starting with raw materials. Inflationary pressure in the upstream supply chain are expected to emerge for 202 6. Daily rates of rigs and other naval drilling and development equipment are expected to remain at high levels due to the financial discipline adopted by the industrial services sector in response to the contraction in investment by the oil se ctor during rece nt downturns and the maintenance of a selective approach to the capital budget. As a result, oil companies are

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exposed to the risk of competing against a limited supply of drilling units and other equipment .

Risks associated with the generation of electricity from renewable sources Projects for the development and construction of plants for the generation of electricity from renewable sources are exposed to the risks of authorizations and increased costs and delays in the supply chain, with negative repercussions on the expecte d profitability of investments. The return of projects in the field of renewables is influenced by factors such as (i) incentive policies for the generation of electricity from renewable sources, (ii) any malfunctions and interruptions in the operation of the transmission and generation plants of electricity from renewable sources , including in relation to extreme weather phenomena (so -called physical risk), (iii) technological evolution and (iv) climate change .

Risks associated with the GGP market Eni's Global Gas & LNG Portfolio (GGP) operates in the wholesale gas market mainly in Europe and in the LNG market globally.

The results of this business are influenced by the global and regional dynamics of natural gas supply and demand and the consequent competitive environmen t. The current market environment is characterized by substantial oversupply, driven by the significant increase in liquefaction capacity in the United States and subdued gas demand trend in Europe, due to sluggish economic growth. These factors influenced the weak reaction of spot gas prices at the main European hubs to the Strait of Hormuz crisis, which effectively halted exports from Qatar. Over the medium to long term, continued LNG inflows from new upstream/midstream projects are expected to contribute to the b alance between global supply and demand.

The GGP sector is exposed to risks due to the significant presence in the procurement portfolio of long -term contracts with take -or-pay clauses. To ensure adequate gas availability in the medium to long term, to support sales programs, contributing to the security of supply of the European market in general and the Italian market in particular, Eni in the past has entered into long -term supply contracts and intends to enter into in the future with the main producing countries that supply the European system. These contracts which were intended to support Eni’s sales plan in Italy and in other European markets, provide take -or-pay clauses whereby the Company has an obligation to lift minimum, preset volumes of gas in each year of the contractual term or, in cas e of failure, to pay the whole price, or a fraction of that price, up to a minimum contractual quantity. The contractual advance payment mechanism exposes the Company to significant financial risks in the event that, due to potential oversupply, market prices are not remunerative compared with the portion of minimum take not covered by sales contracts and risk management activities, thereby triggering the application of the clause. Similar considerations apply to long -term ship -or-pay contractual obligations which Eni has entered into to secure long -term transport capacity along the main European routes that convey gas from production areas to consumption markets. In this scenario, Eni's management is engaged in the renegotiation of long -term supply contracts and in portfolio optimization actions, as levers to manage take -

or-pay/ship -or-pay risk s. With regard to take -or-pay supply contracts with Russian state -owned companies (Gazprom and its affiliates) which are actually suspended but still current , Eni intends to end commercial agreements with Russia n companies. As a consequence, the Group could be exposed to certain operating and financial risks .

The Group is a party to numerous judicial and arbitration proceedings , and pursuant to Legislative Decree 231/01 , on

corporate liability

In the ordinary course of the business, Eni is a party to legal proceedings, including civil or administrative cases, arbitration or crimes committed by its officers and employees , which can also trigger Company’s liability as per Italian Legislative Decree 231/01. These proceedings involve the consequent use of resources, costs and legal expenses. Eni has recognized in the financial statements the liabilities associated with the proceedings for which an unfavorable outcome is probable, and the associated liability can be reliably estimated. In the event that the provisions made relating to pending proceedings are insufficient to fully meet the charges, expenses, penalties and claims for damages and restitution formulated in the event of negative verdicts depending, for example, on new information and developments not foreseen at the time of the initial estimate of the provision , there could be negative effects on the business, on the Group's financial position and results of operations.

The Group is exposed to cybersecurity risk It is an increasingly pervasive risk both due to the increasing digitalization of the Group's activities and to considerations regarding the operating environment:

• Eni is a particularly attractive target for cyber criminals due to the sector in which it operates and the current geopolit ical context (e.g. Russia -Ukraine conflict);

• cyber -attacks , also implemented through the use of artificial intelligence, are constantly increasing (e.g. spear phishing, malware, deep fakes, etc.).

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The Group is exposed to the risk of violations of the relevant legislation on the management, processing and protection of personal data, with detrimental effects on the Group's activities and prospects, with particular reference to the end markets in whic h the Group sells gas, electricity and products to retail and business customers.

The Group is exposed to the risk of possible breaching national and international anti -corruption laws and regulations.

This risk is significant because Eni operates in several countries around the world and in complex activities such as the productio n of hydrocarbons characterized by constant relations with National oil companies, a s well as commodity trading.

Although the Group has adopted an internal control system, procedures and a code of ethics to prevent corruption crimes by its employees, which could impact Eni as foreseen by Legislative Decree 231/01 on corporate responsibility and international anti -corruption codes . It is not possible to completely exclude the risk of non-compliance with anti -corruption laws which could expose Eni and its employees to criminal and civil penalties and could be damaging Eni’s reputation, business prospects and results of operations.

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Outlook

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 billion , 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 billion (from €1.1 billion ) for Enilive and confirmed at €1.3 billion 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 billion , representing an underlying improvement of €0.7 billion vs Group’s sensitivities1.

• Gross capex confirmed at €7 billion ; net capex is guided to less than €5 billion , 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 billion , up 20% from last quarter already revised guidance of €2.8 billion , in line with the Group distribution policy of returning 60% of upside vs. the budgeted CFFO (€11.5 billion ) to shareholders till a Brent price of 90 $/bbl. Th e new buyback amount represents more than double the initial guidance of €1.5 billion 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 billion per each one -dollar change in the SERM margin).

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

Other information

Subsequent events

Subsequent business developments are described in Note 35 of the Condensed consolidated interim financial statements.

Transactions with related parties See Note 32 of the Condensed consolidated interim financial statements.

Buy-back program

On February 18, 202 6, was finalized the buy -back program authorized by the Shareholders' Meeting held on May 1 4, 202 5 with the total purchase of 119 million of shares for a total amount of € 1.8 billion .

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 . The first tranche was concluded with the purchase of 5.1 million treasury shares (equal to 0.1 7 percent of the share capital) for a total consideration of € 120 million. The second tranche concerns up to a maximum of 297.9 million of shares . Since the start of the program to July 24, 202 6, 44 million shares have been purchased for a cash outlay of € 960 million.

1 Group ’s sensitivities are confirmed as follows: €0.11 billion and €0.08 billion per each one -dollar change in the Brent price and SERM margin respectively; €0.03 billion for each one -

euro per MWh change in the spot price of European gas.

CONDENSED

CONSOLIDATED INTERIM FINANCIAL STATEMENTS

Financial statements

Notes to the condensed consolidated interim financial statements Management’s certificationReport of Independent Auditors54 60 97 98

ENI

54 ENI INTERIM CONSOLIDATED REPORT 2026

Consolidated balance sheet

(€ million) NoteTotal amountof which with

related partiesTotal

amountof which with

related parties

ASSETS

Current assets

Cash and cash equivalents 8,365 8,100 Financial assets at fair value through profit or loss (5) 6,723 6,991 Other current financial assets (14) 5,034 2,813 3,710 2,357 Trade and other receivables (6) 12,407 1,585 12,436 1,375 Inventories (7) 6,407 5,143 Income tax receivables 820 539 Other current assets (8) (20) 3,413 95 3,943 76

43,169 40,862

Non-current assets

Property, plant and equipment (9) 49,165 50,536 Right-of-use assets (10) 4,948 5,184 Intangible assets (11) 1,532 6,022 Inventory - Compulsory stock (7) 1,655 1,187 Equity-accounted investments (13) 17,743 13,155 Other investments (13) 1,427 1,329 Other non-current financial assets (14) 1,126 671 1,109 612 Deferred tax assets (19) 6,084 6,716 Income tax receivables 125 125 Other non-current assets (8) (20) 1,498 213 2,839 207

85,303 88,202

Discontinued operations and assets held for sale (21) 18,533 110 8,005

TOTAL ASSETS 147,005 137,069

LIABILITIES AND EQUITY

Current liabilities

Short-term debt (16) 5,334 501 4,929 265 Current portion of long-term debt (16) 2,388 34 3,434 128 Current portion of long-term lease liabilities (10) 1,083 71 1,263 108 Trade and other payables (15) 19,979 4,628 20,261 4,283 Income tax payables 420 343 Other current liabilities (8) (20) 5,798 140 4,039 86

35,002 34,269

Non-current liabilities

Long-term debt (16) 23,827 66 20,139 52 Long-term lease liabilities (10) 4,358 18 4,437 40 Provisions (18) 13,887 14,580 Provisions for employee benefits 559 596 Deferred tax liabilities (19) 4,222 4,805 Income tax payables 25 40 Other non-current liabilities (8) (20) 1,493 6 3,390 462

48,371 47,987

Liabilities directly associated with discontinued operations and assets held for sale (21) 6,702 384 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) Profit 4,390 2,608 Equity attributable to equity holders of Eni 52,001 47,940 Non-controlling interests 4,929 4,847

TOTAL EQUITY (22) 56,930 52,787

TOTAL LIABILITIES AND EQUITY 147,005 137,069June 30, 2026 December 31, 2025

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

55

Consolidated profit and loss account

(€ million) NoteTotal

amountof which

with related

partiesTotal

amountof which

with related

parties

Sales from operations (25) 42,056 1,645 35,752 1,005 Other income and revenues 673 218 649 102

REVENUES AND OTHER INCOME 42,729 36,401

Purchases, services and other (26) (33,929) (10,072) (30,054) (6,868) Net (impairments) reversals of trade and other receivables (6) (101) (1) (73) (1) Payroll and related costs (26) (1,582) 9 (1,554) 6 Other operating income (expense) (20) (321) (168) 436 (183) Depreciation and amortization (9) (10) (11) (3,321) (3,478) Net (impairments) reversals of tangible, intangible and right-of-use assets (9) (10) (11) (1,474) (641) Write-off of tangible and intangible assets (9) (11) (119) 14

OPERATING PROFIT 1,882 1,051

Finance income (27) 3,217 135 5,359 101 Finance expense (27) (3,707) (35) (5,729) (26) Net finance income (expense) from financial assets at fair value through profit or loss (27) 95 111 Derivative financial instruments (20) (27) 9 (70)

FINANCE INCOME (EXPENSE) (386) (329)

Share of profit (loss) from equity-accounted investments 1,172 669 Other gain (loss) from investments 2,146 1 106 4

INCOME (EXPENSE) FROM INVESTMENTS (13) (28) 3,318 775

PROFIT BEFORE INCOME TAXES 4,814 1,497

Income taxes (29) (2,117) (2,056)

PROFIT (LOSS) - CONTINUING OPERATIONS 2,697 (559)

PROFIT (LOSS) - DISCONTINUED OPERATIONS (21) 1,958 (1,083) 2,315 (871)

PROFIT 4,655 1,756

Attributable to Eni

- continuing operations 3,023 (406)

- discontinued operations 1,367 2,121

4,390 1,715

Attributable to non-controlling interests (22)

- continuing operations (326) (153)

- discontinued operations 591 194

265 41

Earnings per share attributable to Eni shareholders (€ per share)(30)

- basic 1.45 0.52

- diluted 1.42 0.52 Earnings per share attributable to Eni shareholders - Continuing

operations

(€ per share) (30)

- basic 0.98 (0.17)

- diluted 0.97 (0.17)First half 2026 First half 2025

ENI

56 ENI INTERIM CONSOLIDATED REPORT 2026

Consolidated statement of comprehensive income (loss) (€ million) First half 2026 First half 2025 Profit (loss) 4,655 1,756 Other items of comprehensive income (loss) Items that are not reclassified to profit or loss in later periods Share of other comprehensive income (loss) on equity-accounted investments 1 Change of minority investments measured at fair value with effects to OCI 9 5

10 5

Items that may be reclassified to profit or loss in later periods Currency translation differences 1,600 (6,063) Change in the fair value of cash flow hedging derivatives (482) 732 Share of other comprehensive income (loss) on equity-accounted investments (56) 24 Tax effect 151 (212)

1,213 (5,519)

Total other items of comprehensive income (loss) 1,223 (5,514) Total comprehensive income 5,878 (3,758) Attributable to Eni shareholders

- continuing operations 4,104 (5,600)

- discontinued operations 1,424 2,051

5,528 (3,549)

Attributable to non-controlling interests

- continuing operations (266) (395)

- discontinued operations 616 186

350 (209)

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

57

Consolidated statement of changes in equity

(continued)

(€ million)

Note

Share capital

Retained earnings

Cumulative

currency translation

differences

Other reserves and equity

instruments

Treasury shares

Profit for the period

Total

Non-controlling interests

Total equity

Balance at December 31, 2025 (22)4,005 33,209 1,936 8,964 (2,782) 2,608 47,940 4,847 52,787 Profit for the first six months of 2026 4,390 4,390 265 4,655 Other items of comprehensive income (loss) Share of “Other comprehensive income (loss)” on equity-accounted investments 1 1 1 Change of minority investments measured at fair value with effects to OCI 9 9 9 Items that are not reclassified to profit or loss in later periods 10 10 10

Currency translation

differences 1,534 1,534 66 1,600 Change in the fair value of cash flow hedge derivatives net of tax effect (348) (348) 17 (331) Share of “Other comprehensive income (loss)” on equity-accounted investments (58) (58) 2 (56) Items that may be reclassified to profit or loss in later periods 1,534 (406) 1,128 85 1,213 Total comprehensive income (loss) of the period 1,534 (396) 4,390 5,528 350 5,878 Dividend distribution of Eni SpA (1,558) (1,558) (1,558) Dividend distribution of other companies (153) (153) Allocation of 2025 profit 2,608 (2,608) Cancellation of treasury shares (1,800) 1,800 Purchase of treasury shares (880) 880 (880) (880) (880) Long-term share-based incentive plan 26 26 26 Issuing of perpetual subordinated bonds 1,000 1,000 1,000 Coupon payment on perpetual subordinated bonds (184) (184) (184) Change in non-controlling interests 115 115 (115) Transactions with holders of equity instruments 127 80 920 (2,608) (1,481) (268)(1,749) Other changes 28 (14) 14 14 Other changes in equity 28 (14) 14 14 Balance at June 30, 2026 (22)4,005 33,364 3,470 8,634 (1,862) 4,390 52,001 4,929 56,930 Equity attributable to equity holders of Eni

ENI

58 ENI INTERIM CONSOLIDATED REPORT 2026

(continued) Consolidated statement of changes in equity

(€ million)

Note

Share capital

Retained earnings

Cumulative

currency translation

differences

Other reserves and

equity instruments

Treasury shares

Profit for the period

Total

Non-controlling interests

Total equity

Balance at December 31, 2024 4,005 32,552 8,081 8,406 (2,883) 2,624 52,785 2,863 55,648 Profit for the first six months of 2025 1,715 1,715 41 1,756 Other items of comprehensive income (loss) Change of minority investments measured at fair value with effects to OCI 4 4 1 5 Items that are not reclassified to profit or loss in later periods 4 4 1 5 Currency translation differences (5,815) (5,815) (248) (6,063) Change in the fair value of cash flow hedge derivatives net of tax effect 521 521 (1) 520 Share of “Other comprehensive income (loss)” on equity-

accounted investments 26 26 (2) 24 Items that may be reclassified to profit or loss in later periods (5,815) 547 (5,268) (251) (5,519) Total comprehensive income (loss) of the period (5,815) 551 1,715 (3,549) (209) (3,758) Dividend distribution of Eni SpA (1,528) (1,528) (1,528) Dividend distribution of other companies (63) (63) Allocation of 2024 profit 2,624 (2,624) Capital contribution by non-controlling interests 709 709 Change in non-controlling interest 2,703 6 2,709 360 3,069 Cancellation of treasury shares (1,908) 1,908 Purchase of treasury shares (660) 660 (660) (660) (660) Long-term share-based incentive plan 17 17 17 Issuing of perpetual subordinated bonds 1,500 1,500 1,500 Repurchase of perpetual subordinated bonds (1,251) (1,251) (1,251) Coupon payment on perpetual subordinated bonds (105) (105) (105) Transactions with holders of equity instruments 3,051 (993) 1,248 (2,624) 682 1,006 1,688 Other changes (173) (7) (180) 7 (173) Other changes in equity (173) (7) (180) 7 (173) Balance at June 30, 2025 4,005 35,430 2,266 7,957 (1,635) 1,715 49,738 3,667 53,405 Profit for the second six months of 2025 893 893 109 1,002 Other items of comprehensive income (loss) Remeasurements of defined benefit plans net of tax effect (9) (9) 2 (7) Change of minority investments measured at fair value with effects to OCI (36) (36) 1 (35) Items that are not reclassified to profit or loss in later periods (45) (45) 3 (42)

Currency translation

differences (329) (329) (18) (347) Change in the fair value of cash flow hedge derivatives net of tax effect 109 109 (22) 87 Share of “Other comprehensive income (loss)” on equity-

accounted investments 47 47 (6) 41 Items that may be reclassified to profit or loss in later periods (329) 156 (173) (46) (219) Total comprehensive income (loss) of the period (329) 111 893 675 66 741 Dividend distribution of Eni SpA (1,553) (1,553) (1,553) Dividend distribution of other companies (212) (212) Change in non-controlling interests 714 (35) (11) 668 1,335 2,003 Purchase of treasury shares (1,221) 1,221 (1,221) (1,221) (1,221) Long-term share-based incentive plan 18 (74) 74 18 18 Repurchase of perpetual subordinated bonds (249) (249) (249) Coupon payment on perpetual subordinated bonds (205) (205) (205) Transactions with holders of equity instruments (2,247) (35) 887 (1,147) (2,542) 1,123 (1,419) Other changes 26 34 9 69 (9) 60 Other changes in equity 26 34 9 69 (9) 60 Balance at December 31, 2025 (22)4,005 33,209 1,936 8,964 (2,782) 2,608 47,940 4,847 52,787 Equity attributable to equity holders of Eni

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

59

Consolidated statement of cash flows (€ million) Note First half 2026 First half 2025 Profit (loss) of the period - continuing operations 2,697 (559) Profit (loss) of the period - discontinued operations 1,958 2,315 Profit (loss) of the period 4,655 1,756 Adjustments to reconcile profit (loss) to net cash provided by operating activities:

Depreciation and amortization (9) (10) (11) (21) 3,398 3,696 Net impairments (reversals) of tangible, intangible and right-of-use assets (9) (10) (11) 1,474 641 Write-off of tangible and intangible assets (9) (11) (21) 120 (13) Share of (profit) loss of equity-accounted investments (13) (21) (1,158) (649) Net gain on disposal of assets (5) (6) Dividend income (28) (60) (100) Interest income (223) (202) Interest expense 629 607 Income taxes (21) (29) 2,354 2,079 Other changes (28) (2,077) (125) Cash flow from changes in working capital (1,516) 192

- inventories (1,729) 401

- trade receivables (1,233) 2,655

- trade payables 1,794 (2,437)

- provisions (423) (439)

- other assets and liabilities 75 12 Change in the provisions for employee benefits 19 8 Dividends received 868 879 Interest received 87 117 Interest paid (817) (748) Income taxes paid, net of tax receivables received (2,051) (2,230) Net cash provided by operating activities 5,697 5,902

- of which with related parties (32) (8,123) (4,972) Cash flow from investing activities (5,074) (4,535)

- tangible assets (9) (4,478) (3,707)

- intangible assets (11) (163) (258)

- consolidated subsidiaries and businesses net of cash and cash equivalents acquired (23) (499)

- investments (13) (301) (351)

- securities and financing receivables held for operating purposes (33) (35)

- change in payables in relation to investing activities 400 (184) Cash flow from disposals 250 320

- tangible assets 12 66

- consolidated subsidiaries and businesses net of cash and cash equivalents disposed of (23) 38

- investments 27 18

- securities and financing receivables held for operating purposes 43 16

- change in receivables in relation to disposals 130 220 Net change in securities and financing receivables held for non-operating purposes (830) (190) Net cash used in investing activities (5,654) (4,405)

- of which with related parties (32) (1,367) (1,255) Increase in long-term financial debt (16) 5,116 3,721 Repayments of long-term financial debt (16) (2,906) (4,803) Payments of lease liabilities (10) (669) (675) Increase (decrease) in short-term financial debt (16) 250 (242) Dividends paid to Eni's shareholders (1,552) (1,524) Dividends paid to non-controlling interests (126) (33) Capital contribution (reimbursement) by non-controlling interests 709 Other contributions 9 Sale (purchase) of additional interests in consolidated subsidiaries 3,069 Purchase of treasury shares (22) (849) (666) Net issuance (repayment) of perpetual subordinated bonds (22) 988 231 Coupon payment on perpetual subordinated bonds (22) (184) (105) Net cash used in financing activities 68 (309)

- of which with related parties (32) 67 294 Effect of exchange rate changes and other changes on cash and cash equivalents 23 (204) Net increase (decrease) in cash and cash equivalents 134 984 Cash and cash equivalents - beginning of the year 8,421 8,183 Cash and cash equivalents - end of the year (a)8,555 9,167 (a)As ofJune 30,2026,cashandcashequivalents included€190millionofcashandcashequivalents ofconsolidatedsubsidiaries heldfor salethat were reported under the line item "Discontinued operations and assets held for sale".

ENI

60 ENI INTERIM CONSOLIDATED REPORT 2026

Notes on Consolidated Financial Statements

1 Basis of preparation The Condensed Consolidated Interim Financial Statements as of June 30, 2026 (hereinafter Interim Financial Statements) have been prepared on a going concern basis in accordance with the requirements of IAS 34 “Interim Financial Reporting” (hereinafter IAS 34). The Interim Financial Statements have been prepared in accordance with the same principles of consolidation and accounting policies described in the last Consolidated Annual Financial Statements (see the related report for more information). Consistently with the requirements of IAS 34, the Interim Financial Statements include selected explanatory notes; conversely, the primary financial statements have been prepared in conformity to the requirements of IAS 1 “Presentation of Financial Statements” for a complete set of financial statements. Current income taxes have been calculated based on the estimated taxable profit for the interim period. Current income tax assets and liabilities have been measured at the amount expected to be paid to/recovered from the taxation Authorities, using tax laws that have been enacted or substantively enacted by the end of the reporting period and the tax rates estimated on an annual basis. The results of discontinued operations are separately presented in a dedicated line item of the profit and loss account, net of the related tax effects; the results of the discontinued operations are also presented for comparative periods; further details are provided in note 21. The annexes outline the changes in the scope of consolidation that occurred during the reporting period. On July 28, 2026, Eni’s Board of Directors approved the Interim Financial Statements as of June 30, 2026. The Interim Financial Statements are subject to limited review, which is significantly less in scope than an audit performed in accordance with the generally accepted auditing standards, carried out by the external auditor PricewaterhouseCoopers SpA. The Interim Financial Statements are presented in euros and all values are rounded to the nearest million euros (€ million), except where otherwise indicated.

2 Changes in accounting policies The amendments to IFRSs effective from January 1, 2026, disclosed in the note “IFRSs not yet effective” of the last Consolidated Annual Financial Statements and adopted by Eni, did not have a material impact on the Consolidated Financial Statements.

3 Significant accounting estimates and judgements The significant accounting estimates and judgements made by management are disclosed in the last Consolidated Annual Financial Statements. The assumptions underlying the impairment review of assets are disclosed in the notes to the Interim Financial Statements.

4 IFRSs not yet effective Besides the IFRSs not yet effective already disclosed in the last Consolidated Annual Financial Statements, an update of the IFRSs adopted by the European Commission is provided below.

On May 27, 2026, the IASB issued IFRS 20 “Regulatory Assets and Regulatory Liabilities”, which replaces IFRS 14 and sets out the accounting of rate-regulated activities. IFRS 20 shall be applied for annual reporting periods beginning on or after January 1, 2029.

On June 26, 2026, the IASB issued the amendments to IAS 28 “Amendments to the Fair Value Option for Investments in Associates and Joint Ventures” aimed to clarify the circumstances in which the fair value option may be applied, instead of the equity method, to measure investments in associates and joint ventures. The amendments shall be applied for annual reporting periods beginning on or after January 1, 2027.

Eni is currently reviewing the IFRSs not yet effective in order to determine the likely impact on the Group’s financial statements.

In this regard, during the first half of 2026, the Group continued the mapping, started in 2025, of the issues potentially affected by the adoption of IFRS 18 “Presentation and Disclosure in Financial Statements” (hereinafter IFRS 18); in parallel, for the issues identified, the Group started further assessments aimed to evaluate the implications of adopting the new standard.

As regards the latter, based on the analyses performed to date, which will continue throughout the second half of 2026, the areas expected to be primarily affected are:

 the presentation within the investment category of the profit and loss account of: (i) the effects arising from the application of the equity method and the dividends from investments in equity instruments; (ii) income and expenses related to cash

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

61

and cash equivalents, financial assets held for trading and other financial assets measured at fair value; (iii) interest income and impairment losses on financing receivables provided to investees;

 the classification of foreign exchange differences within the same category of the profit and loss account as the income and expenses from the items that gave rise to the foreign exchange differences;

 with reference to derivative financial instruments, the recognition of the economic effects of: (i) derivatives designated in hedge accounting, in the same category of the profit and loss account as the income/expenses arising from the hedged items; (ii) derivatives not designated in hedge accounting but used for risk management purposes, within the same category of the profit and loss account as the income/expenses affected by the risks the financial instrument is used to manage, unless such allocation involve undue cost or effort; in such case, the related economic effects are presented in the operating category; (iii) derivatives not used to manage identified risk, within the operating category, regardless of the nature of the underlying item;

 the presentation, within the statement of cash flows, of interests received and dividends received from investees as part of net cash used in investing activities rather than net cash flows provided by operating activities; furthermore, interests paid will be presented as part of net cash used in financing activities and no longer as part of net cash provided by operating activities.

During the second half of 2026, the Group will continue its IFRS 18 implementation program, taking into account also the update of IT systems.

5 Financial assets at fair value through profit or loss

The breakdown by issuing entity and credit rating of securities did not show significant changes compared to the Annual Report 2025.

The fair value hierarchy of financial assets held for trading is level 1 for €6,259 million and level 2 for €406 million. The fair value hierarchy of Other financial assets at fair value through profit or loss is level 2. During the first half of 2026 there were no significant transfers between the different hierarchy levels of fair value.

6 Trade and other receivables

The €58 million increase in trade receivables was primarily driven by the Enilive business line (€732 million), the Global Gas & LNG Portfolio and Power segment (€515 million), and the Refining, Chemicals and Sites in transformation segment (€278 million). This increase was partially offset by the reclassification of €1,552 million of trade receivables to assets held for sale and discontinued operations. The rise in trade receivables within the Global Gas & LNG Portfolio and Power segment and the Enilive business line was mainly attributable to higher energy commodity prices, which increased the nominal value of outstanding receivables.

As part of its ordinary course of business, Eni entered into non-recourse sales of receivables during the first half of 2026, primarily involving trade receivables, with maturities extending beyond June 30, 2026, up by approximately €0.2 billion compared to December 31, 2025.

Receivables from other counterparties comprised: (i) the recoverable amount of €909 million (€881 million at December 31, 2025) of overdue trade receivables owed to Eni by the State-owned oil company of Venezuela, PDVSA, in respect of Eni’s equity (€ million)June 30,

2026December 31,

2025

Financial assets held for trading Bonds issued by sovereign states 695 734 Other securities 5,970 6,168

6,665 6,902

Other financial assets at fair value through profit or loss Other securities 58 89

6,723 6,991

(€ million)June 30,

2026December 31,

2025

Trade receivables 9,044 8,986 Receivables from joint ventures in exploration and production activities 1,255 1,238 Receivables from divestments 74 209 Other receivables 2,034 2,003 Total trade and other receivables net of allowance for doubtful accounts 12,407 12,436

ENI

62 ENI INTERIM CONSOLIDATED REPORT 2026

share of gas supplied by Cardón IV SA, joint venture equally owned by Eni and Repsol. Those trade receivables were transferred by the joint venture to the two shareholders. The recoverable amount (nominal value of $2,301 million, equivalent to €2,019 million, with exclusion of accrued interest income) was estimated, consistent with the valuation approach adopted in the 2025 financial statements, by discounting the expected repayment cash flows at the cost of capital of the E&P segment, adjusted to reflect Venezuela’s specific country risk premium (adjusted WACC). In the first half 2026, US authorities granted Eni new general licenses to resume the marketing of Venezuelan crude oil, provided the activities are not aimed at debt-swap transactions. Pursuant to these authorizations, Eni negotiated with PDVSA the allocation of crude oil cargoes owned by the state-owned oil company to Cardón IV SA, for the settlement of revenue accrued during the financial year; (ii) prepayments for services of €409 million (€404 million at December 31, 2025).

Net (impairments) reversals of trade and other receivables are analyzed as follows:

New provisions related to the Exploration & Production segment for €126 million, for the supply of hydrocarbons and cash-

calls receivable from partners in oil projects operated by Eni.

Reversals of unused provisions related to the Exploration & Production segment for €30 million.

Receivables with related parties are disclosed in note 32 – Transactions with related parties.

7 Current and non-current inventories

Non-current inventories related to Italian subsidiaries for €1,634 million (€1,165 million at December 31, 2025) are maintained for compliance purposes, in accordance with minimum stock requirements for oil and petroleum products set forth by applicable laws. The increase in the carrying amount was driven by higher crude oil and refined product prices.

8 Other assets and liabilities

The fair value related to derivative financial instruments is disclosed in note 20 – Derivative financial instruments.

Other assets included: (i) a receivable of €525 million (€550 million at December 31, 2025) arising from an agreement with an with an Italian operator on the allocation of past and future environmental remediation costs incurred by Eni in connection with activities performed or currently underway at certain domestic sites previously managed jointly by the two partners; (ii) current underlifting positions of the Exploration & Production segment of €318 million (€199 million at December 31, 2025); (iii) non-

current receivables for divesting activities for €171 million (€169 million at December 31, 2025); (iv) prepayments for gas volumes made in prior years as a result of take-or-pay obligations under the Company’s long-term supply contracts, of which Eni expects to recover €3 million within 12 months and €96 million thereafter (€2 million and €85 million, respectively, at (€ million) First half 2026 First half 2025 New provisions (154) (110) Net credit losses (2) (3) Reversals 55 40 Net (impairments) reversals of trade and other receivables (101) (73) (€ million) Current inventoriesNon-current

inventories

Gross carrying amount at December 31, 2025 5,799 1,300 Write down provisions at December 31, 2025 656 113 Net carrying amount at December 31, 2025 5,143 1,187 Changes of the period 1,253 468 Other changes 11 Net carrying amount at June 30, 2026 6,407 1,655 Gross carrying amount at June 30, 2026 7,083 1,822 Write down provisions at June 30, 2026 676 167 (€ million) CurrentNon-

current CurrentNon-

current CurrentNon-

current CurrentNon-

current

Fair value of derivative financial instruments 1,586 86 2,250 20 791 81 827 146 Contract liabilities 574 531 788 520 Other taxes 692 7 2,277 35 919 24 1,589 47 Other 1,135 1,405 697 907 2,233 2,734 835 2,677 3,413 1,498 5,798 1,493 3,943 2,839 4,039 3,390June 30, 2026 December 31, 2025 Assets Liabilities Assets Liabilities

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

63

December 31, 2025). Receivables acquired in connection with tax credits, bonuses, energy efficiency measures and similar instruments, amounting of €2,020 million as of June 30, 2026, and relating to the Plenitude business line, were classified to discontinued operations (compared with €2,982 million as of December 31, 2025, when they were reported under other assets).

Contract liabilities included: (i) advances received from the companies operating Concessione Gorgoglione (CG Group) for the upgrade of the crude oil transportation infrastructure connecting Val d’Agri production area to the Taranto refinery for €524 million (€496 million at December 31, 2025); (ii) electronic prepaid fuel vouchers for €284 million (€346 million at December 31, 2025); (iii) advances and deposits received from customers for future gas supplies for €117 million (€227 million at December 31, 2025); (iv) advances received from Engie SA relating to a long-term agreement for supplying natural gas and power for €38 million (€44 million at December 31, 2025), of which current for €12 million (same amount at December 31, 2025).

Other liabilities included: (i) current overlifting imbalances of the Exploration & Production segment for €338 million (€267 million at December 31, 2025); (ii) a put option granted by Eni to Energy Infrastructure Partners (EIP), a minority shareholder of Plenitude, in connection with the subscription of a €588 million reserved capital increase in March 2024 and a €209 million reserved capital increase in March 2025. Under this arrangement, Eni has committed to repurchase EIP's interest at a minimum value that allows the fund to repay the debt incurred to finance the transaction. The carrying amount of the put option reflects the present value of Eni's maximum financial commitment of €546 million (€541 million at December 31, 2025). The option expires in 2027; (iii) liabilities of €57 million (same amount as of December 31, 2025) relating to gas volumes prepaid by customers but not yet withdrawn, following the activation of take-or-pay provisions under the relevant long-term supply contracts.

Non-current liabilities to factoring companies amounting to €556 million at June 30, 2026, relating to the Plenitude business line and arising from the assignment of tax credits accrued under the Ecobonus and Superbonus schemes, have been classified under liabilities directly associated with assets held for sale (€1,422 million as of December 31, 2025, previously reported under other non-current liabilities). Liabilities related to investing activities amounting to €55 million (€49 million as of December 31, 2025) relating to the Plenitude business line have been classified under discontinued operations.

Transactions with related parties are described in note 32 — Transactions with related parties.

9 Property, plant and equipment

Capital expenditures primarily related to the Exploration & Production segment for €3,770 million (€2,962 million in the first half of 2025).

Additional information about Eni’s impairments and reversals is disclosed in note 12 – Reversals (Impairments) of tangible and intangible assets and right-of-use assets.

Currency translation differences primarily related to subsidiaries whose functional currency is the U.S. dollar.

Reclassification as discontinued operation related to the Plenitude business line.

Other changes included: (i) the reclassification of €1,262 million, relating to the termination of the planned disposal of a 25% (€ million)Property, plant

and equipment

Gross carrying amount at December 31, 2025 169,192 Provisions for depreciation and impairments at December 31, 2025 118,656 Net carrying amount at December 31, 2025 50,536

Additions 4,478

Depreciation capitalized 154

Depreciation (*)(2,857)

Reversals 305

Impairments (1,763)

Write-offs (117)

Currency translation differences 1,436 Initial recognition and changes in estimates 38 Reclassification to discontinued operations (3,227) Other changes 182 Net carrying amount at June 30, 2026 49,165 Gross carrying amount at June 30, 2026 171,962 Provisions for depreciation and impairments at June 30, 2026 122,797 (*) Before capitalization of depreciation charges.

ENI

64 ENI INTERIM CONSOLIDATED REPORT 2026

interest in the Congo LNG project, from assets held for sale to continuing assets. Therefore, the asset was restated at its original carrying amount as of the reclassification date, adjusted for the depreciation that would have been recognized had the asset not been classified as held for sale. The company recognized a reversal of previously recorded impairment losses of €290 million; (ii) investments in property, plant, and equipment under supplier financing arrangements, resulting in the classification of the related liability as financial debt amounting to €561 million; (iii) the reclassification of oil & gas assets for €1,585 million to assets held for sale.

Property, plant and equipment included capitalized costs related to wells, plant and machinery, pending exploration and appraisal activities and tangible assets in progress of the Exploration & Production segment as follows:

Transfers from E&P tangible assets in progress to E&P UOP wells, plant and machinery related for €2,243 million to commissioning of wells, plants and machinery primarily in Congo, Mexico, Egypt, Kazakhstan, Italy, Libya, United Arab Emirates and Iraq.

Write-offs of €80 million were recorded as part of exploration and appraisal activities and related to suspended costs of ongoing or completed exploration wells which results were determined to be unsuccessful during the period, concerning initiatives in Oman and Libya.

Write-offs of assets under construction, amounting to €37 million, related in particular to initiatives in Italy and Indonesia.

Unproved mineral interests, comprised in assets in progress, included the purchase price allocated to unproved reserves following business combinations or the cost incurred when acquiring mineral interests and were as follows:

Unproved mineral interests comprised mineral rights relating to the Oil Prospecting License 245 property (“OPL 245”), in the pre-development phase offshore Nigeria. The net book value of OPL 245 amounting to €1,180 million includes €861 million corresponding to the equivalent euro amount of the price paid in 2011 to the Nigerian Government to acquire a 50% interest in the license (unproved mineral interest) as well as subsequent capitalized exploration and pre-development costs. Having closed all complex legal proceedings relating to alleged international corruption cases in connection with the award of the license in a positive manner for Eni, in March 2026 a final agreement was signed with the Nigerian Federal Government and the Company whereby the parties waived all respective claims regarding past events and defined the economic terms for the exploitation of the reserves of the license that was converted into a development title.

(€ million)Wells, plant and

machineryExploration

assets and

appraisalTangible

assets in

progress Total

Carrying amount at December 31, 2025 33,554 1,549 5,946 41,049 Additions 262 3,493 3,755 Depreciation capitalized 24 130 154 Depreciation (*)(2,639) (2,639) Net (impairments) reversals (917) (285) (1,202) Write-offs (80) (37) (117) Currency translation differences 1,072 50 266 1,388 Initial recognition and changes in estimates 13 (4) 27 36 Transfers 2,516 (48) (2,468) Other changes 650 (8) (642) Carrying amount at June 30, 2026 34,249 1,745 6,430 42,424 (*) Before capitalization of depreciation charges.

(€ milioni)

Congo

Nigeria

USA

Algeria

Egypt

United Arab

Emirates

Indonesia

Netherlands

Tunisia

Australia

Total

Carrying amount at December 31, 2025 9874 33130 2232 35 24 7221,368 Net (impairments) reversals 5 (33) (23) (51) Reclassification to Proved Mineral Interest (1) (1) Currency differences and other changes 1 23 4 7 1 36 Carrying amount at June 30, 2026 15897 133 2239 35 24 7 1,352

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

65

10 Right-of-use assets and lease liabilities

Lease liabilities related for €601 million (€761 million at December 31, 2025) to the portion of liabilities attributable to joint operators in projects operated by Eni which will be recovered through the mechanism of the cash calls.

Current portion of long-term lease liabilities amounted to €1,083 million (€1,263 million at December 31, 2025).

Reclassification of right-of use assets and lease liabilities as discontinued operation related to the Plenitude business line.

Other changes in right-of-use assets and lease liabilities were mainly attributable to early termination or renegotiation of lease contracts.

Liabilities for leased assets with related parties are described in note 32 — Transactions with related parties.

11 Intangible assets

Additions of €163 million (€258 million in the first half of 2025) included €103 million (€119 million in the first half of 2025) relating to the capitalization of customer acquisition costs in the Plenitude business line.

The change in the scope of consolidation related to the Plenitude business line, specifically the acquisition of Acea Energia SpA for €515 million.

Reclassification as discontinued operation related to the Plenitude business line.

(€ million)Right-of-use

assetsLease

liabilities

Gross carrying amount at December 31, 2025 9,892 Provisions for amortization and impairment at December 31, 2025 4,708 Net carrying amount at December 31, 2025 5,184 5,700 Additions 657 657

Decreases (669)

Depreciation (*)(570)

Net (impairments) reversals (14) Currency translation differences 86 94 Reclassification to discontinued operations (223) (226) Other changes (172) (115) Net carrying amount at June 30, 2026 4,948 5,441 Gross carrying amount at June 30, 2026 10,094 Provisions for depreciation and impairment at June 30, 2026 5,146 (*) Before capitalization of depreciation charges of tangible and intangible assets.

(€ million)Intangible

assets with

finite useful

lives GoodwillIntangible

assets with

undefinite

useful lives Total Gross carrying amount at December 31, 2025 8,319 Provisions for amortization and impairment at December 31, 2025 5,487 Net carrying amount at December 31, 2025 2,832 3,164 26 6,022 Additions 163 163 Amortization capitalized 6 6 Amortization (*)(54) (54) Impairments (2) (2) Write-offs (2) (2) Currency translation differences 14 14 Changes in the scope of consolidation 200 363 563 Reclassification to discontinued operations (1,857) (3,280) (5,137) Other changes (41) (41) Net carrying amount at June 30, 2026 1,259 247 26 1,532 Gross carrying amount at June 30, 2026 4,983 Provisions for amortization and impairment at June 30, 2026 3,724 (*) Before capitalization of depreciation charges.

ENI

66 ENI INTERIM CONSOLIDATED REPORT 2026

The carrying amount of intangible assets with finite useful lives included exploration licenses and leasehold acquisition costs

as follows:

The carrying amount of goodwill is stated net of cumulative impairment charges amounting to €2,647 million.

No impairment losses were recognized on goodwill during the first half of 2026.

12 Reversals (Impairments) of tangible and intangible assets and right-of-use assets.

The energy commodity price/margin scenario adopted for the preparation of the 2026 Eni’s consolidated Interim Report confirmed the assumptions utilized to test the recoverability of the carrying amounts of Eni's fixed assets adopted in the 2025 Annual Report.

In response to short-term volatility in crude oil prices, driven by heightened geopolitical risks associated with the ongoing crisis in the Middle East, management raised its price forecasts for the 2026–2027 period, while retaining the long-term price assumptions.

The Group's cost of capital, increased by the specific risk of each country in which Eni operates, used as the discount rate of future cash flows in the impairment test, did not undergo significant changes with the base rate before each country step-up confirmed at 6%.

The Group identified indicators of impairment for certain mature cash-generating units as the management is re-directing risk capital to new opportunities in the portfolio and away from the recoverability of the residual mineral potential of certain, mature long-life fields based on the Group financial framework of project selection and discipline in allocating funds. Those fields nearing depletion and lacking ongoing commitments involving signed third-party contracts underwent a review to align their recoverability with the fundamentals of Eni’s upstream model and future cash flows associated with the development of probable reserves were excluded from value-in-use estimates. This adjustment, in conjunction with the revised estimates of production profiles at other fields, resulted in impairment charges totaling about €1.47 billion for assets in Italy, Australia, USA, Egypt and Congo.

Approximately €194 million impairment charges concerned capitalizations of safety/stay-in-business expenditures at refineries and petrochemical complexes with negative cash flows.

The criteria adopted to identify the Group’s Cash Generating Units (CGU) and to perform the impairment review of the recoverability of carrying amounts of fixed assets remain unchanged from the 2025 Annual Report to which reference is made (note 15 - Reversals (Impairments) of tangible and intangible assets and right-of-use assets. Sensitivity of outcomes to decarbonization scenarios).

(€ million)June 30,

2026December 31,

2025

Proved license and leasehold property acquisition costs 63 61 Unproved license and leasehold property acquisition costs 396 385

459 446

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

67

13 Investments

Equity-accounted investments

Acquisitions and subscriptions related to: (i) the acquisition of SENI SpA (Eni’s interest 30%) for €55 million; (ii) the capital increase of Qatar Energy LNG NFE (5) (Eni’s interest 25%), which holds a 12.5% stake in the North Field East (NFE) project, for €32 million, securing for Eni a 3.125% interest in Qatar’s LNG development megaproject; (iii) the capital increase of Mangistau Power BV (Eni’s interest 51%) for €21 million.

Divestments and reimbursements related the repayment of capital of €26 million from E&E Algeria Touat BV.

Equity valuation – effect on profit and loss essentially referred to: (i) Vår Energi ASA for €617 million; (ii) Azule Energy Holdings Ltd for €212 million; (iii) Searah Ltd for €73 million; (iv) ADNOC Global Trading Ltd for €63 million; (v) Mozambique Rovuma Venture for €57 million; (vi) Ithaca Energy Plc for €51 million.

Reduction for dividends related to: (i) Vår Energi ASA for €324 million; (ii) Azule Energy Holdings Ltd for €171 million; (iii) Cardón IV SA for €160 million; (iv) Saipem SpA for €72 million; (v) Ithaca Energy Plc for €62 million.

Change in the scope of consolidation related, for €103 million, to the recognition of the investment in Blue Stream Pipeline Co BV, which, following the expiry of the transportation contract, changed its classification from joint operation to joint venture.

The reclassification as a discontinued operation related to the Plenitude business line.

Other changes related to the recognition of the new joint venture Searah Ltd, amounting to €4,850 million.

As of June 30, 2026, the carrying amounts and corresponding market values of Eni’s interests in the listed companies Saipem SpA, Vår Energi ASA, and Ithaca Energy Plc, accounted for using the equity method, were as follows:

As of June 30, 2026, the book value of the investments included: (i) Searah Ltd for €4,987 million; (ii) Azule Energy Holdings Ltd for €4,819 million; (iii) Abu Dhabi Oil Refining Company (TAKREER) for €2,032 million; (iv) St. Bernard Renewables Llc for €728 million; (v) QatarEnergy LNG NFE (5) for €713 million; (vi) E&E Algeria Touat BV for €688 million; (vii) Saipem SpA for €512 million; (viii) Ithaca Energy Plc for €464 million; (ix) Mozambique Rovuma Venture SpA for €436 million; (x) SeaCorridor Srl for €414 million; (xi) ADNOC Global Trading Ltd for €263 million; (xii) Vår Energi ASA for €253 million; (xiii) Cardón IV SA for €252 million; (xiv) Coral FLNG SA for €186 million; (xv) Eni CCUS Holding Ltd for €139 million; (xvi) Blue Stream Pipeline Co BV for €107 million.

(€ million)Equity-accounted

investments

Carrying amount at December 31, 2025 13,155 Additions and subscriptions 199 Divestments and reimbursements (27) Equity valuation – effect on profit and loss 1,175 Deduction for dividends (824) Currency translation differences 446 Changes in the scope of consolidation 125 Reclassification to discontinued operations (1,184) Other changes 4,678 Carrying amount at June 30, 2026 17,743 Saipem SpA Vår Energi ASA Ithaca Energy Plc Number of ordinary shares held 422,920,192 1,573,713,749 594,048,748 % of the investment 21.80 63.04 35.92 Share price (€) 4.409 3.644 2.519 Market value (€ million) 1,865 5,734 1,496 Book value (€ million) 512 253 464 Market value vs Book value (€ million) 1,353 5,481 1,032

ENI

68 ENI INTERIM CONSOLIDATED REPORT 2026

Other investments

Other investments consist of minority interests in entities functional to the business. For the evaluation methodology applied, see Annual Report 2025.

Additions and subscriptions included the purchase for €60 million of a minority stake in Nouveau Monde Graphite Inc, a Canadian company, listed on the Toronto Stock Exchange and the New York Stock Exchange, engaging in the mining of natural graphite and in the advanced battery materials sector.

The investment book value as of June 30, 2026, included: (i) Nigeria LNG Ltd for €626 million; (ii) Saudi European Petrochemical Co “IBN ZAHR” for €120 million; (iii) Darwin LNG Pty Ltd for €87 million.

Dividends declared by other minority interests are disclosed in note 28 – Income (expense) from investments.

14 Other financial assets

Financing receivables are stated net of the valuation allowance for doubtful accounts of €393 million (€377 million at December 31, 2025).

Financing receivables held for operating purposes mainly related to funding provided to associates and joint agreements to support the execution of industrial projects of interest to Eni in the Exploration & Production segment (€762 million). These receivables are the expression of long-term interest in the underlying industrial initiatives. The largest exposure was towards Coral FLNG SA (Eni’s interest 25%) for €408 million (€417 million at December 31, 2025), which built a floating gas liquefaction plant in the Area 4 concession in Mozambique.

Fair value of non-current financing receivables held for operating purposes of €933 million has been estimated based on the present value of expected future cash flows discounted at rates ranging from 2.1% to 5.1% (1.9% and 4.8% at December 31, 2025).

Financing receivables related to: (i) the joint venture Mozambique Rovuma Venture SpA (Eni’s interest 35.71%) for €2,779 million (€2,318 million at December 31, 2025) engaged in the production of natural gas reserves at the Coral South field and in the development of natural gas reserves of the Coral North field in the exclusivity area. This financing receivable differs from those held for operating purposes by virtue of the venture's operational and financial autonomy, resulting in Eni being exposed solely to counterparty credit risk; (ii) €1,028 million (€710 million at December 31, 2025) of receivables from co-ventures arising from the reallocation of working interest in ongoing development projects in Area 4 offshore Mozambique; (iii) for €1,060 million (€495 million as of December 31, 2025) to restricted deposits held in escrow as collateral for transactions involving derivative contracts entered into by the trading companies Eni Global Energy Markets SpA and Eni Trade & Biofuels SpA.

Fair value of securities derived from quoted market prices and amounted to €63 million.

Receivables with related parties are described in note 32 – Transactions with related parties. (€ million)Other

investments

Carrying amount at December 31, 2025 1,329 Additions and subscriptions 102 Change in the fair value with effect to OCI 9 Currency translation differences 30 Reclassification to discontinued operations (36) Other changes (7) Carrying amount at June 30, 2026 1,427 (€ million) Current Non-current Current Non-current Long-term financing receivables held for operating purposes 933 1 910 933 1 910 Long-term financing receivables 3,849 129 3,067 136 Short-term financing receivables 1,185 642 5,034 129 3,709 136 5,034 1,062 3,710 1,046 Securities held for operating purposes 64 63 Total net of impairment provisions 5,034 1,126 3,710 1,109June 30, 2026 December 31, 2025

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

69

15 Trade and other payables

The increase in trade payables of €962 million related to the Global Gas & LNG Portfolio business line for €863 million and to the Exploration & Production segment for €795 million, primarily in the trading business line in relation to the increase in oil prices, which increased the nominal value of the payables. The increase was partially offset by a reclassification to assets held for sale and discontinued operations amounting to €1,100 million.

Trade payables include liabilities for letters of credit with payment terms aligned to trade terms and with fixed fees.

Other payables included: (i) payroll payables for €237 million (€260 million at December 31, 2025); (ii) payables for social security contributions for €113 million (€124 million at December 31, 2025). Payables to factoring companies in relation to the derecognition of Eni’s tax credits deriving from incentives and energy saving, amounting to €1,159 million and relating to the Plenitude business line were classified as discontinued operation (€1,322 million at December 31, 2025, classified under other payables).

Trade and other payables due to related parties are described in note 32 – Transactions with related parties.

16 Finance debt

Finance debt increased by €3,047 million as disclosed in the table “Changes in liabilities arising from financing activities” at the end of this paragraph.

As of December 31, 2025, financial debt to banks included €200 million of sustainability-linked financing agreements entered into with leading banking institutions, the cost of which was indexed to achievement of Company’s sustainability targets.

Other financial institutions included Supplier Finance Arrangements (SFAs) for €1,269 million (€1,585 million at December 31, 2025).

Eni entered into long-term borrowing facilities with the European Investment Bank. These borrowing facilities are subject to the retention of a minimum level of credit rating. According to the agreements, should the Company lose the minimum credit rating, new guarantees could be required to be agreed upon with the European Investment Bank. As of June 30, 2026, debts subjected to restrictive covenants amounted to €1,457 million (€981 million at December 31, 2025). As of June 30, 2026, Eni met all the agreed conditions.

(€ million)June 30,

2026December 31,

2025

Trade payables 14,863 13,901 Down payments and advances from joint ventures in exploration & production activities 580 714 Payables for purchase of non-current assets 1,617 1,666 Payables due to partners in exploration & production activities 1,336 1,114 Other payables 1,583 2,866

19,979 20,261

(€ million)Short-term

debtCurrent

portion of

long-term

debtLong-term

debt TotalShort-term

debtCurrent

portion of

long-term

debtLong-term

debt Total

Banks 3,863 100 1,770 5,733 3,394 330 1,268 4,992 Ordinary bonds 1,680 21,090 22,770 2,320 17,855 20,175 Sustainability-linked convertible bonds 23 945 968 9 939 948 Other financial institutions 1,471 585 22 2,078 1,535 775 77 2,387 5,334 2,388 23,827 31,549 4,929 3,434 20,139 28,502June 30, 2026 December 31, 2025

ENI

70 ENI INTERIM CONSOLIDATED REPORT 2026

The following table provides a breakdown of ordinary bonds by issuing entity, maturity date, interest rate and currency as of June 30, 2026:

During the first half of 2026, Eni issued new ordinary bonds in euro with a nominal value of €4,634 million.

As of June 30, 2026, ordinary bonds maturing within 18 months amounted to €2,509 million of nominal value.

Information relating to the convertible senior unsecured sustainability-linked bonds issued is as follows:

As of June 30, 2026, Eni SpA had outstanding sustainability-linked bonds for an aggregate nominal amount of €3,750 million, as well as convertible senior unsecured sustainability-linked bonds of €1,000 million. These bonds provide that if the Company fails to reach the relevant agreed sustainability targets, a step-up adjustment to the interest rates will apply, During the first half of the year, a step-up event occurred in connection with the target relating to Eni’s share of installed (€ million) AmountDiscount

on bond

issue and

accrued

expense Total Currency Maturity Rate (%)

Issuing entity

Euro Medium Term Notes

Eni SpA 1,250 (2) 1,248 EUR 2033 4.250

Eni SpA 1,250 (14) 1,236 EUR 2035 4.000

Eni SpA 1,000 20 1,020 EUR 2029 3.625

Eni SpA 1,000 1 1,001 EUR 2030 0.625

Eni SpA 1,000 1 1,001 EUR 2031 2.000

Eni SpA 1,000 8 1,008 EUR 2034 3.875

Eni SpA 800 800 EUR 2028 1.625

Eni SpA 750 5 755 EUR 2027 1.500

Eni SpA 750 2 752 EUR 2034 1.000

Eni SpA 750 (4) 746 EUR 2031 3.500

Eni SpA 658 8 666 EUR 2027 variable

Eni SpA 600 4 604 EUR 2028 1.125

Eni SpA 100 1 101 EUR 2028 5.441

Eni SpA 75 2 77 EUR 2043 3.875

Eni SpA 70 70 USD 2032 4.000

Eni SpA 50 1 51 EUR 2031 4.800

Eni SpA - Sustainability-linked 1,000 (1) 999 EUR 2028 0.625 Eni SpA - Sustainability-linked 750 3 753 EUR 2027 4.125 12,853 35 12,888

Other bonds

Eni SpA 1,317 2 1,319 USD 2036 5.250

Eni SpA 1,317 (30) 1,287 USD 2056 6.000

Eni SpA 1,097 (21) 1,076 USD 2054 5.950

Eni SpA 878 9 887 USD 2028 4.750

Eni SpA 878 3 881 USD 2029 4.250

Eni SpA 878 878 USD 2034 5.500

Eni SpA 878 (8) 870 USD 2035 5.750

Eni USA Inc 351 3 354 USD 2027 7.300

Eni SpA 307 1 308 USD 2040 5.700

Eni SpA - Sustainability-linked - Retail 2,000 22 2,022 EUR 2028 4.300 9,901 (19) 9,882 22,754 16 22,770 (€ million) AmountDiscount

on bond

issue and

accrued

expense Total Currency MaturityRate (%)

Issuing entity

Eni SpA - Convertible senior unsecured sustainability-linked bonds 1,000 47 1,047 EUR 2030 2.950 of which financial liabilities 920 48 968 of which equity 80 (1) 79

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

71

capacity in the renewable energy generation activity, as defined in the contractual documentation of the respective bond issuance. This circumstance triggered an increase in the interest rate applicable to coupons already accrued and/or those that will accrue in the future, in accordance with the terms of each instrument, with either recurring or one-off effects. The increase in finance charges associated with this contractual trigger is immaterial.

As of June 30, 2026, Eni retained committed borrowing facilities of €9,011 million (€9,012 million as of December 31, 2025), of which €9,000 undrawn (same amount as of December 31, 2025). Those facilities bore interest rates reflecting prevailing conditions in the marketplace.

Fair value of long-term debt, including the current portion of long-term debt, is described below:

Fair value of finance debts was calculated by discounting the expected future cash flows at discount rates ranging from 2.1% to 5.1% (1.9% and 4.8% at December 31, 2025).

Because of the short-term maturity and conditions of remuneration of short-term debt, the fair value approximated the carrying amount.

Changes in liabilities arising from financing activities

Other non-monetary changes included increases in lease liabilities for €657 million and €600 million arising from supplier financing arrangements classified as financial debt.

Lease liabilities are described in note 10 – Right-of-use assets and lease liabilities.

Reclassification as discontinued operation related to the Plenitude business line.

Transactions with related parties are described in note 32 – Transactions with related parties.

17 Information on net borrowings (€ million)June 30,

2026December 31,

2025

Ordinary bonds and sustainability-linked bonds 22,751 20,119 Convertible sustainability-linked bonds 1,270 1,071 Banks 1,819 1,608 Other financial institutions 607 852

26,447 23,650

(€ million)Long-term debt

and current

portion of long-

term debt Short-term debtLong-term and current portion of

long-term lease

liabilities Total

Carrying amount at December 31, 2025 23,573 4,929 5,700 34,202 Cash flows 2,210 250 (669) 1,791 Currency translation differences 187 (181) 96 102 Changes in the scope of consolidation 3 106 (3) 106 Reclassification to discontinued operatins (39) (149) (226) (414) Other non-monetary changes 281 379 543 1,203 Carrying amount at June 30, 2026 26,215 5,334 5,441 36,990 (€ million)June 30,

2026December 31,

2025

A.Cash 2,495 2,796 B. Cash equivalents 5,870 5,304 C. Other current financial assets 11,757 10,700 D. Liquidity (A+B+C) 20,122 18,800 E. Current financial debt 7,037 7,258 F. Current portion of non-current financial debt 1,768 2,368 G. Current financial indebtedness (E+F) 8,805 9,626 H. Net current financial indebtedness (G-D) (11,317) (9,174) I. Non-current financial debt 6,150 5,782 J. Debt instruments 22,008 18,756 K. Non‐current trade and other payables L.Non-current financial indebtedness (I+J+K) 28,158 24,538 M.Total financial indebtedness (H+L) 16,841 15,364

ENI

72 ENI INTERIM CONSOLIDATED REPORT 2026

Net borrowings did not include €129 million of non-current receivables (€136 million at December 31, 2025).

Cash and cash equivalents include €2 million (€1 million at December 31, 2025) of restricted cash subjected to foreclosure measures by third parties and payment guarantees.

Other current financial assets include: (i) financial assets at fair value through profit or loss, disclosed in note 5 – Financial assets at fair value through profit or loss; (ii) financial receivables, disclosed in note 14 – Other financial assets.

Current and non-current financial debts are disclosed in note 16 – Finance debts.

Financial payables included €27 million (€38 million at December 31, 2025) of fair value hedge derivative contracts entered into to hedge fixed rate bonds.

Current portion of non-current financial debt and non-current financial debt included lease liabilities of €1,083 million and €4,358 million (€1,263 million and €4,437 million at December 31, 2025, respectively). More information about lease liabilities is disclosed in note 10 – Right-of-use assets and lease liabilities.

18 Provisions

Provisions recognized in the first half of 2026 primarily related to environmental costs, site decommissioning and restoration projects and costs for insurance claims.

Reversals of utilized provisions related to the progress in spending the accrued amounts in environmental and remediation projects and in site decommissioning and restoration projects.

Reversals of unutilized provisions mainly related to accrued amounts for site abandonment and restoration projects and renegotiation of commercial contracts as part of the ordinary course of the business.

The reclassification of provisions as a discontinued operation related to the Plenitude business line.

19 Deferred tax assets and liabilities

(€ million) Provisions Carrying amount at December 31, 2025 14,580 New or increased provisions 493 Initial recognition and changes in estimates of provisions for site restoration, abandonment and social projects 38 Accretion discount 142 Reversal of utilized provisions (754) Reversal of unutilized provisions (293) Currency translation differences 164 Changes in the scope of consolidation (96) Reclassification to discontinued operations (270) Other changes (117) Carrying amount at June 30, 2026 13,887 (€ million)June 30,

2026December 31,

2025

Deferred tax liabilities before offsetting 6,281 6,937 Deferred tax assets available for offset (2,059) (2,132) Deferred tax liabilities 4,222 4,805 Deferred tax assets before offsetting (net of accumulated write-down provisions) 8,143 8,848 Deferred tax liabilities available for offset (2,059) (2,132) Deferred tax assets 6,084 6,716

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FINANCIAL STATEMENTS

73

The following table summarizes the changes in deferred tax liabilities and assets:

Taxes are also described in note 29 – Income taxes.

20 Derivative financial instruments

Derivatives fair values were estimated based on market quotations provided by primary info-provider or, alternatively, appropriate valuation techniques generally adopted in the marketplace. (€ million)Deferred tax

liabilities

before

offsettingDeferred tax

assets before

offsetting,

grossAccumulated

write-downs of

deferred tax

assetsDeferred tax

assets before

offsetting net

of accumulated

write-down

provisions

Carrying amount at December 31, 2025 6,937 (13,003) 4,155 (8,848) Changes to profit and loss account (287) 459 113 572 Changes with effect recognised within equity 28 (235) (235) Changes in the scope of consolidation (536) 307 (49) 258 Currency translation differences 191 (175) 60 (115) Reclassification to discontinued operations (270) 328 (34) 294 Other changes 218 (194) 125 (69) Carrying amount at June 30, 2026 6,281 (12,513) 4,370 (8,143) (€ million)Fair value

assetFair value

liabilityLevel of Fair

valueFair value

assetFair value

liabilityLevel of Fair

value

Non-hedging derivatives

Derivatives on interest rate

- Interest rate swap 29 19 1 41 18 2

- Other 1 2 29 19 42 18 Derivatives on exchange rate

- Currency swap 114 46 2 26 72 2

- Interest currency swap 1 6 2 5 2 2

- Outright 1 2 11 2 116 52 31 85 Derivatives on commodities

- Over the counter 1,846 1,950 2 633 767 2

- Future 2,628 2,804 1 816 999 1

- Options 113 169 1 11 22 1

- Other 5 2 6 2 4,587 4,928 1,466 1,788 4,732 4,999 1,539 1,891 Fair value hedge derivatives Derivatives on interest rate

- Interest rate swap 27 2 38 2

27 38

Cash flow hedge derivatives Derivatives on commodities

- Over the counter 98 192 2 167 2

- Future 234 498 1 256 89 1

- Other 5 105 2 332 690 428 194

Options

- Other options 21 2 21 Gross amount 5,091 5,689 2,005 2,106 Offsetting (3,419) (3,419) (1,133) (1,133) Net amount 1,672 2,270 872 973

- current 1,586 2,250 791 827

- non-current 86 20 81 146 June 30, 2026 December 31, 2025

ENI

74 ENI INTERIM CONSOLIDATED REPORT 2026

The offsetting of financial derivatives primarily related to Eni Global Energy Markets SpA and Eni Trade & Biofuels SpA.

During the first half of 2026, there were no transfers between the different hierarchy levels of fair value.

Effects recognized in other operating profit (loss) Other operating profit (loss) related to derivative financial instruments on commodities are detailed as follows:

Effects recognized in finance income (loss) Financial income (loss) on derivative financial instruments is detailed as follows:

More information is disclosed in note 32 – Transactions with related parties.

21 Discontinued operations, assets held for sale and liabilities directly associated with assets held for sale

Discontinued operations

Plenitude

On March 19, 2026, Eni announced a plan to reorganize Plenitude's shareholding structure, together with the existing shareholders Ares Management Alternative Credit funds (“Ares”) and Energy Infrastructure Partners, with the goal of establishing a new governance framework based on joint control between Eni and Ares, resulting in the loss of control over Plenitude.

The transaction involves a non-proportional capital increase to be subscribed to by the shareholders amounting to approximately €1.5 billion, of which at least €1 billion euros is expected to be provided by Ares, based on a 100% pre-money equity valuation of Plenitude of €10.75 billion (and an implied enterprise value of €13.1 billion). Following the capital increase, Eni anticipates retaining an equity stake of close to 65%.

The capital increase is designed to strengthen Plenitude's capital structure, supporting its growth targets, including with respect to an installed capacity of 15 GW and 15 million retail customers by 2030. Plenitude is also pursuing an investment grade credit rating.

The transaction is subject to regulatory and other approvals.

As of the first quarter of 2026, the Plenitude Group has been classified as a disposal group held for sale, as it is the subject of a disposal program that will trigger loss of control, and also as a discontinued operation, as it represents a major line of business under the applicable international accounting standards.

With reference to the classification as discontinued operations as required by the international accounting standards (IFRS 5), Plenitude remains within the scope of consolidation as of 30 June 2026 and, therefore, the amounts presented comprise the elimination of intercompany transactions and of the associated internal margins. Consequently, the results of both continuing and discontinued operations did not reflect the performance of the individual entities on a stand-alone basis. Following this accounting representation: (i) in the balance sheet statement, assets and liabilities have been presented, respectively, in a single line item under assets and liabilities; (ii) in the income statement, the results net of tax effects have been recognized in a separate line item presented before the profit of the period. Comparative information is provided for both the income statement and the cash flow statement amounts relating to discontinued operations.

(€ million) First half 2026 First half 2025 Net income (loss) on cash flow hedging derivatives (17) 6 Net income (loss) on other derivatives (304) 430

(321) 436

(€ million) First half 2026 First half 2025 Derivatives on exchange rate 53 (52) Derivatives on interest rate (44) (18)

9 (70)

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

75

Below are the main amounts of assets and liabilities relating to the discontinued operations, net of intercompany balances.

Below are the key financial performance and cash flows data relating to the discontinued operations, net of intercompany balances.

Assets held for sale and liabilities directly associated with assets held for sale Assets held for sale amounting to €3,268 million (€8,005 million at December 31, 2025) and directly associated liabilities of €1,014 million (€2,026 million at December 31, 2025) primarily related to oil & gas assets in the United Arab Emirates, Ivory Coast and Nigeria.

Details of the Indonesian assets divested during the first half of the year are presented in Note 23 – Other Information.

(€ million)June 30,

2026

Current assets 3,469 Non-current assets 11,796 Total assets 15,265 Current liabilities 3,174 Non-current liabilities 2,514 Total liabilities 5,688 (€ milioni) First half 2026 First half 2025 Revenues and other income 5,407 5,685 Purchases, services and other (2,930) (2,810) Net (impairments) reversals of trade and other receivables (53) (77) Payroll and related costs (158) (140) Other operating income (expense) 1 Depreciation and amortization (77) (218) Write-off of tangible and intangible assets (1) (1) Operating income 2,189 2,439 Finance income (expense) 7 (81) Share of profit (loss) from equity-accounted investments (14) (20) Income (expense) from investments 13 Profit before income taxes 2,195 2,338 Income taxes (237) (23) Profit 1,958 2,315

- attributable to Eni 1,367 2,121

- attributable to non-controlling interest 591 194 Basic earnings per share (€ per share) 0.47 0.69 Diluted earnings per share (€ per share) 0.45 0.69 Net cash provided from operating activities 1,930 2,791 Net cash used in investing activities (832) (478) Net cash used in financing activities (281) 95 Capital expenditure in tangible and intangible assets 219 340

ENI

76 ENI INTERIM CONSOLIDATED REPORT 2026

22 Equity

Non-controlling interests

Non-controlling interests in Eni Marine Services SpA related to a perpetual subordinated bond issued in U.S. dollar to finance a Group capital project. The bond was recognized as non-controlling interests due to the Group's unconditional right to avoid transferring cash or other financial assets to the bondholders. The carrying amount as of June 30, 2026, was adjusted to the EUR/USD exchange rate, resulting in an increase of €54 million.

Equity attributable to equity holders of Eni

Share capital

As of June 30, 2026, the parent company’s issued share capital consisted of €4,005,358,876 (same amount as of December 31, 2025) represented by 3,027,982,186 ordinary shares without nominal value (3,146,765,114 ordinary shares at December 31, 2025).

On May 6, 2026, Eni’s Shareholders’ Meeting resolved: (i) to distribute available reserves, recurring if necessary or suitable in the interest of the Shareholders to the revaluation reserve pursuant to Law No. 342/2000, by way of and in place of the payment of the dividend for the year 2026 of €1.10 per share in four tranches, in September 2026 (€0.27 per share), November 2026 (€0.27 per share), March 2027 (€0.28 per share) and May 2027 (€0.28 per share); (ii) to authorize the Board of Directors -

pursuant to and for the purposes of Art. 2357 of the Italian Civil Code - to proceed with the purchase of treasury shares of the Company, in multiple tranches, for a period up to the end of April 2027, up to a maximum of 303,000,000 ordinary shares for a total outlay of up to €4 billion, of which: a) up to a maximum of no. 297,900,000 shares for the purpose of remunerating Shareholders; b) up to a maximum of 5,100,000 shares allocated to serve the LTI Plan; (iii) to authorize the Board of Directors to cancel up to a maximum of 297,900,000 treasury shares which will eventually be acquired based on the shareholders' authorization of the previous point. As of June 30, 2026, in execution of these resolutions, 26,742,570 treasury shares have been acquired for a total value of €600 million .

Perpetual subordinated hybrid bonds Hybrid bonds are governed by the English law and are traded on the regulated market of the Luxembourg Stock Exchange. As of June 30, 2026, hybrid bonds amounted to €6 billion (€5 billion at December 31, 2025). (€ million)First Half

2026First Half

2025June 30,

2026December 31,

2025

Eni Plenitude Group 162 (1) 1,911 1,816 Eni Marine Services SpA 1,755 1,701 Enilive Group 93 13 839 860 EniPower Group 17 29 417 457 Others (7) 7 13 265 41 4,929 4,847 Profit (Loss) Equity (€ million)June 30,

2026December 31,

2025

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:

- Perpetual subordinated hybrid bonds 6,000 5,000

- Legal reserve 959 959

- Reserve for treasury shares 1,862 2,782

- Reserve for OCI on cash flow hedging derivatives net of tax effect (320) 42

- Reserve for OCI on defined benefit plans net of tax effect (94) (94)

- Reserve for OCI on equity-accounted investments 35 92

- Reserve for OCI on other investments valued at fair value 113 104

- Reserve for convertible bond issue 79 79 Treasury shares (1,862) (2,782) Profit 4,390 2,608

52,001 47,940

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

77

In January 2026, Eni issued one perpetual subordinated hybrid bond with a nominal amount of €1 billion. The Hybrid Bond provides a re-offer price of 99.342% and an annual coupon of 4.125% until the first reset date, scheduled to fall 6.25 years from issue (April 19, 2032). If an early redemption will not take place, the annual coupon will be redetermined starting from April 19, 2032 and every 5 years thereafter, with a rate equal to the 5-year Euro Mid Swap rate in force from time to time plus an initial margin of 163.7 basis points. Such margin will be further increased by 25 basis points from April 19, 2037 and a subsequent increase of a further 75 basis points from April 19, 2052.

Treasury shares

A total of 113,570,677 Eni’s ordinary shares (189,083,769 at December 31, 2025) were held in treasury for a total cost of €1,862 million (€2,782 million at December 31, 2025).

During the first half of 2026, 43,269,743 shares were acquired for a total value of €880 million; 118,782,928 treasury shares have been cancelled for a total value of €1,800 million; 93 shares erroneously allocated to an employee were returned to Eni.

23 Other information Supplemental cash flow information

On April 10, 2026, Eni finalized the acquisition of 100% of the share capital of Acea Energia SpA, active in the retail sale of electricity and natural gas on the free market, for a total consideration of €498 million, including the acquisition of: (i) current assets for €351 million; (ii) non-current assets for €217 million; (iii) net financial debt of €32 million, of which cash and cash equivalents amounting to €34 million; (iv) current and non-current liabilities for €454 million. The allocation of the purchase price of the net assets acquired was carried out on a provisional basis, with the recognition of goodwill amounting to €352 million. The acquisition relates to the Plenitude segment.

On May 31, 2026, as announced to the market on June 8, 2026, the creation of a 50-50 joint venture "Searah" with Petronas was finalized. This venture combines the partners' respective asset portfolios in Indonesia and Malaysia, positioning the new entity as a regional leader in the strategic LNG sector within the Asia-Pacific region. The initiative aims to drive growth and value creation through the development of significant mineral resources discovered by Eni in Indonesia in recent years, which will be independently funded.

At the closing date, Eni contributed its Indonesian assets (seven production sharing contracts, including the two North/South (€ million)First Half

2026

Investment in consolidated subsidiaries and businesses Current assets 360 Non-current assets 259 Net borrowings 27 Current and non-current liabilities (459) Net effect of investments 187

Goodwill 361

Transfer of non-consolidated equity interests (13) Purchase price 535

less:

Cash and cash equivalents acquired (36) Disposal of consolidated subsidiaries and businesses 499 Divestments/Contributions involving consolidated companies and business units disposed of Current assets 766 Non-current assets 3,657 Net borrowings 752 Current and non-current liabilities (1,935) Net effect of disposals/contributions 3,240 Current value of the interest held after the business combination (4,850) Reclassification to P&L of OCI items 71 Gains arising from business combinations 2,088 Total cash effect of business combination 549

less:

Cash and cash equivalents contributed (511) Consolidated subsidiaries and businesses net of cash and cash equivalent disposed of 38

ENI

78 ENI INTERIM CONSOLIDATED REPORT 2026

Hub projects in the offshore Kutei Basin) to the JV Searah, receiving a 50% equity interest in the combined entity in return.

Based on the information currently available and considering that assessments are still in progress, the transaction resulted in the deconsolidation of net assets amounting to €3,240 million, the recognition of the equity interest in Searah for €4,850 million, and the recognition of a gain from business combinations of €2,088 million, including the reclassification to profit and loss accounts of currency translation differences negative for €71 million. This gain was calculated as the difference between the value of the equity interest received and the net book value of the contributed assets and recognized, to the extent of third-

party interest (50%), in accordance with the so-called "downstream transaction" method. The unrealized gain, eliminated against the carrying amount of the investment, will subsequently be recognized through the application of the equity method.

24 Guarantees, commitments and risks

Guarantees, commitments and risks The amount of guarantees, commitments and risks did not show significant changes compared to the Annual Report 2025, with the exception of the issuance of a new parent company guarantee amounting to €1,351 million, provided in the interest of AP Baleine 3 (UK) Ltd to secure payment obligation arising from the lease agreement relating to the FPSO unit for the development of the Baleine field.

Risk factors

For the disclosure relating to the management of financial risks, reference is made to the Annual Report 2025.

Updates relating to "Market risk " and "Liquidity risk" are provided below.

Market risk

As of June 30, 2026, the average rating of the Strategic liquidity investment portfolio was A/A-, unchanged compared to December 31, 2025.

The following tables show amounts in terms of VaR, recorded in first half of 2026 (compared with 2025), relating to interest rate and exchange rate risks, and commodity risk (aggregated by type of exposure). Regarding the management of strategic liquidity, the tables analyze the sensitivity to changes in interest rates.

(€ million) High LowAverage At period end High LowAverage At year end Interest rate (a)8.80 3.81 6.27 6.62 10.29 4.45 7.48 4.45 Exchange rate (a)3.91 0.08 1.62 0.26 7.99 0.07 2.07 0.43 (€ million) High LowAverage At period end High LowAverage At year end Commercial exposures - Management Portfolio (a)98.95 22.12 56.89 63.49 34.93 2.79 16.37 2.79 Trading (b)4.82 0.32 1.07 2.06 1.34 0.30 0.63 0.37(Value at risk - parametric method variance/covariance; holding period: 1 day; confidence level: 99%) (Value at risk - Historic simulation method; holding period: 1 day; confidence level: 95%) (a) Refers to Global Gas & LNG Portfolio business area, Power Generation & Marketing, Supply, Plenitude, Eni Trading & Biofuels, Eni Global Energy Markets (commercial portfolio) until 17/03/2026, then jointly monitored as Global Trading BU. VaR is calculated on the so-called Statutory view, with a time horizon that coincides with the year considering all the volumes delivered in the year and the relevant financial hedging derivatives. Consequently, during the year the VaR pertaining to GGP, Power G&M, Supply and Plenitudeduring theyear presentsa decreasing trend following the progressivereaching of the maturity of thepositions within the annual horizon.

(b) Cross-commodity proprietary trading, through financial instruments, refers to Eni Trading & BiofuelsSpA and Eni Global Energy Markets SpA and Eni Trading & Shipping Inc until 17/03/2026, then jointly monitored as Global Trading BU.First half 2026 2025 (a) Value at risk deriving from interest and exchange rates exposures includes the Group's Finance Departments of Eni Corporate and Banque Eni SA.

First half 2026 2025

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

79

Liquidity risk

Eni has in place a program for the issuance of Euro Medium-Term Notes up to €20 billion; as of June 30, 2026, €15.4 billion were drawn.

The Group has the following credit ratings: Standard & Poor’s assigns Eni a long-term debt rating of A- with a negative outlook and a short-term debt rating of A-2; Moody’s assigns Eni a long-term debt rating of A3 with a stable outlook and a short-term debt rating of P-2; Fitch assigns Eni a long-term debt rating of A- with a stable outlook and a short-term debt rating of F1. Eni’s rating is linked, in addition to endogenous and market variables, to the sovereign rating of Italy. Based on the methodologies used by the rating agencies, a downgrade of Italy’s sovereign rating may trigger a potential knock-on effect on the credit rating of Italian issuers such as Eni.

As of June 30, 2026, Eni retained committed borrowing facilities of €9 billion. The related contracts provide for interest and non-use fees negotiated on the basis of normal market conditions.

Eni has put in place payment agent agreements with third parties to facilitate the operational processing of the suppliers’ payment chain and enable the batch settlement of invoices. Those invoices are settled by the agents at their due date, who is reimbursed by Eni at the beginning of the following month. As of June 30, 2026, the amount payable to payment agents amounted to about €0.8 billion.

Expected payments for financial debts, lease liabilities and trade and other payables The table below summarizes the Group main contractual obligations for finance debt and lease liability repayments, including expected payments for interest charges and liabilities for derivative financial instruments.

Lease liabilities, including interest charges, of €869 million (€1,082 million at December 31, 2025) pertained to the share of joint operators participating in unincorporated joint operation operated by Eni which will be recovered through a partner-billing process.

The amount relating to financial guarantees represents the actual commitment corresponding to the maximum liquidity risk exposure in the event that the guarantee is called as of the balance sheet date.

(€ million) High LowAverage At period end High LowAverage At year end Strategic liquidity - € Portfolio 0.54 0.37 0.46 0.44 0.64 0.53 0.58 0.54 ($ million) High LowAverage At period end High LowAverage At year end Strategic liquidity - US dollar Portfolio 0.17 0.11 0.15 0.17 0.18 0.12 0.15 0.16(Sensitivity - Dollar value of 1 basis point - DVBP) (Sensitivity - Dollar value of 1 basis point - DVBP) First half 2026 2025 First half 2026 2025 (€ million)2026 2027 2028 2029 20302031 and

thereafterTotal

Financial liabilities 5,928 2,817 5,470 1,972 2,142 13,173 31,502 Lease liabilities 697 821 622 497 465 2,320 5,422 Fair value of derivative instruments 2,246 15 3 1 5 2,270 8,871 3,653 6,095 2,470 2,607 15,498 39,194 Interest on finance debt 373 943 843 665 607 5,356 8,787 Interest on lease liabilities 261 261 221 189 161 607 1,700 634 1,204 1,064 854 768 5,963 10,487 Financial guarantees 290 290 Maturity year

ENI

80 ENI INTERIM CONSOLIDATED REPORT 2026

The table below presents the timing of the expenditures for trade and other payables.

Expected payments under contractual obligations In addition to financial liabilities, lease liabilities, trade and other payables presented in the balance sheet, Eni has entered non-

cancellable contractual obligations or obligations whose cancellation would entail the payment of a penalty, the settlement of which will result in cash outflows in future reporting periods. These liabilities are valued based on the net cost for the company to fulfill the contract, which consists of the lowest amount between the costs for the fulfillment of the contractual obligation and the contractual compensation/penalty in the event of non-performance.

Company’s main contractual obligations at the balance sheet date comprise take-or-pay clauses contained in Eni’s gas supply contracts or shipping arrangements, whereby the obligations consist of off-taking minimum gas volumes or paying the corresponding cash amount, with the option to take delivery of the underlying volumes in future years. The amounts due were calculated on the basis of the assumptions for gas prices and services included in the 2026-2030 industrial plan approved by the Company’s management and for subsequent years on the basis of management’s long-term assumptions.

The table below summarizes Group’s principal contractual obligations for the main existing contractual obligations as of the balance sheet date, shown on an undiscounted basis. Amounts expected to be paid in the second half of 2026 for decommissioning oil & gas assets and for environmental clean-up and remediation are based on management’s estimates and do not represent financial obligations at the closing date.

(€ million)20262027 and

thereafterTotal

Trade payables 14,863 14,863 Other payables and advances 5,116 236 5,352 19,979 236 20,215 Maturity year (€ million)2026 2027 2028 2029 20302031 and

thereafterTotal

Decommissioning liabilities (a)547 911 634 527 569 10,512 13,700 Environmental liabilities 664 593 439 336 297 1,196 3,525 Purchase obligations (b) 10,426 15,538 12,132 11,170 9,251 63,280 121,797

- Gas

. take-or-pay contracts 9,255 14,734 11,461 10,863 9,011 62,916 118,240 . ship-or-pay contracts 281 274 269 282 218 327 1,651

- Other purchase obligations 890 530 402 25 22 37 1,906 Total (c)11,637 17,042 13,205 12,033 10,117 74,988 139,022 (b) Represents any agreement to purchase goods or services that is enforceable and legally binding and that specifies all significant terms.Maturity year (a) Represents the estimated future costs for the decommissioning of oil and natural gas production facilities at the end of theproducing lives of fields,well-

plugging, abandonment and site restoration.

(c) Expected payments under contractual obligations comprises obligations of discontinued operations and subsidiaries held for sale for €671 million.

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

81

Disclosures about the offsetting of financial instruments

The offsetting of financial assets and liabilities related to: (i) receivables and payables pertaining to the Exploration & Production segment towards state entities for €5,152 million (€4,581 million at December 31, 2025); (ii) other current and non-

current assets and liabilities for derivative financial instruments of €3,419 million (€1,133 million at December 31, 2025) and other assets and liabilities of €56 million (€13 million at 31 December 2025).

(€ million)Gross amount of financial assets and liabilitiesGross amount of financial assets and liabilities subject to offsettingNet amount of financial assets and liabilities June 30, 2026

Financial assets

Trade and other receivables 17,559 5,152 12,407 Other current assets 6,828 3,415 3,413 Other non-current assets 1,558 60 1,498

Financial liabilities

Trade and other liabilities 25,131 5,152 19,979 Other current liabilities 9,213 3,415 5,798 Other non-current liabilities 1,553 60 1,493 December 31, 2025

Financial assets

Trade and other receivables 17,017 4,581 12,436 Other current assets 5,076 1,133 3,943 Other non-current assets 2,852 13 2,839

Financial liabilities

Trade and other liabilities 24,842 4,581 20,261 Other current liabilities 5,172 1,133 4,039 Other non-current liabilities 3,403 13 3,390

ENI

82 ENI INTERIM CONSOLIDATED REPORT 2026

Legal Proceedings

In the ordinary course of the business, Eni is the defendant in several legal proceedings in relation to claims for damage compensation, administrative cases, possible Company’s liabilities pursuant to Legislative Decree no. 231/01 due to alleged crimes committed by its officers and employees when performing their duties, as well as arbitration procedures for alleged violations of petroleum contracts and other commercial disputes.

The Condensed Consolidated Interim Financial Statement pursuant to IAS 34 is an update of the Annual Report and, as such, presumes full knowledge of the latter. In the first half of 2026, the developments in the proceedings to which the Company is a party did not significantly alter the level of risk or the potential losses associated with ongoing litigations. Accordingly, for a complete disclosure of the legal proceedings in which Eni is involved, please refer to note 28 – Guarantees, commitments and risks of the Annual Report 2025 where the most significant proceedings currently pending are disclosed. Unless otherwise indicated, these legal proceedings have not been provisioned because Eni believes a negative outcome to be unlikely or because the amount of the provision cannot be estimated reliably.

The proceedings that had significant developments compared to December 31, 2025 and as of the date of publication of Eni’s first half 2026 financial report are reported below:

(i) Criminal proceedings concerning alleged environmental crimes at the Gela site: the appeal filed by the Public Prosecutor against the first-instance acquittal judgment, including alleged crimes pursuant to Legislative Decree No. 231/2001, was declared inadmissible.

(ii) Public Prosecutor of Palermo/alleged crimes related to illegal waste trafficking involving Raffineria di Gela SpA and EniMed SpA: the acquittal judgment has become final and is no longer subject to appeal.

(iii) Public Prosecutor of Pavia/alleged environmental crimes at the Sannazzaro refinery: a dismissing order was issued with respect to Eni SpA, which had been under investigation pursuant to Legislative Decree No. 231/2001.

(iv) Proceedings have been initiated in relation to alleged environmental crimes for administrative corporate liability pursuant to Legislative Decree No. 231/2001 against Raffineria di Gela SpA, Versalis SpA and ISAF SpA (in liquidation) involving an omitted clean-up at the Gela site.

(v) Administrative proceedings initiated by the Province of Vicenza concerning the clean-up of the Trissino site: the Council of State, in a recent judgment, confirmed Eni Rewind’s liability for the contamination, jointly and severally with other operators responsible for defining an adequate clean-up plan. Any potential liability for Eni cannot currently be estimated reliably. The possibility of pursuing further legal remedies is currently under evaluation.

(vi) Proceedings for alleged abuse of dominant position in the market of biofuels and bio compounds: the appeals filed by Eni against the decisions of the Italian Antitrust Authority (AGCM) were dismissed at first instance. Eni will appeal to the Council of State. Eni believes that these developments do not modify the risk profile of the two proceedings, for which provisions have already been recognized.

(vii) Arbitration proceedings are ongoing in relation to cost recovery and other claims brought by the Republic of Kazakhstan (RoK) against the two international oil company consortia operating the Karachaganak oil project (Eni interest 29.25%) under the Final Production Sharing Agreement and the Kashagan oil project (Eni interest 16.67%) under the North Caspian Sea Production Sharing Agreement. Eni continues to assess the merits of the claims submitted by the Republic in the arbitration proceedings considering the available investigative evidence and, therefore, it is not currently possible to estimate the outcome of both proceedings.

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

83

25 Sales from operations

Sales from operations by industry segment are disclosed in note 31 – Segment information.

Sales from operations with related parties are disclosed in note 32 – Transactions with related parties.

(€ million)

Exploration

& Production

Global Gas & LNG

Portfolio and

Power

Refining,

Chemicals and

Sites in

transformation

Enilive

Corporate and

Other activities

Total

First half 2026 Sales from operations 21,955 7,258 2,599 10,131 113 42,056 Sales from operations by geographical area Italy 246 4,793 1,407 6,226 59 12,731 Rest of European Union 2,271 1,473 888 3,035 8 7,675 Rest of Europe 8,968 426 114 470 33 10,011 Americas 3,783 73 93 2 3,951 Asia 3,199 554 96 292 2 4,143 Africa 3,486 12 19 15 9 3,541 Other areas 2 2 4 21,955 7,258 2,599 10,131 113 42,056 Products sales and service revenues Sales of crude oil 16,956 1 16,957 Sales of oil products 2,224 619 9,906 12,749 Sales of natural gas and LNG 2,381 5,989 1 8,371 Sales of petrochemical products 1,623 1,623 Sales of power 1,124 1 1,125 Sales of other products 34 1 225 46 21 327 Services 360 144 129 179 92 904 21,955 7,258 2,599 10,131 113 42,056 Transfer of goods/services Goods/Services transferred in a specific moment 21,710 7,258 2,575 10,131 111 41,785 Goods/Services transferred over a period of time 245 24 2 271 First half 2025 Sales from operations 17,984 6,541 2,885 8,216 126 35,752 Sales from operations by geographical area Italy 328 3,832 1,753 5,257 68 11,238 Rest of European Union 1,518 1,813 754 2,328 37 6,450 Rest of Europe 6,140 139 109 358 6,746 Americas 2,897 62 55 1 3,015 Asia 3,787 745 180 208 6 4,926 Africa 3,299 12 25 10 14 3,360 Other areas 15 2 17 17,984 6,541 2,885 8,216 126 35,752 Products sales and service revenues Sales of crude oil 13,200 13,200 Sales of oil products 2,113 808 7,963 10,884 Sales of natural gas and LNG 2,429 4,967 1 7,397 Sales of petrochemical products 1,723 1,723 Sales of power 1,268 1 1,269 Sales of other products 32 1 182 37 31 283 Services 210 305 170 216 95 996 17,984 6,541 2,885 8,216 126 35,752 Transfer of goods/services Goods/Services transferred in a specific moment 17,771 6,468 2,838 8,216 119 35,412 Goods/Services transferred over a period of time 213 73 47 7 340

ENI

84 ENI INTERIM CONSOLIDATED REPORT 2026

26 Costs

Purchases, services and other charges

Purchases, services and other charges included prospecting costs, geological and geophysical studies of exploration activities of the Exploration & Production segment for €134 million (€86 million in the first half of 2025).

Payroll and related costs

Costs with related parties are disclosed in note 32 – Transactions with related parties.

27 Finance income (expense)

The analysis of finance income (expense) was as follows:

Information about leases is disclosed in note 10 – Right-of-use assets and lease liabilities.

The analysis of derivative financial income (expense) is disclosed in note 20 – Derivative financial instruments.

Finance income (expense) wit related parties is disclosed in note 32 – Transactions with related parties. (€ million) First half 2026 First half 2025 Production costs - raw, ancillary and consumable materials and goods 27,060 24,027 Production costs - services 5,049 4,536 Lease expense and other 686 687 Net provisions for contingencies 165 207 Other expenses 1,046 810

34,006 30,267

less:

- capitalized direct costs associated with self-constructed assets (77) (213)

33,929 30,054

(€ million) First half 2026 First half 2025 Payroll and related costs 1,633 1,618

less:

- capitalized direct costs associated with self-constructed assets (51) (64)

1,582 1,554

(€ million) First half 2026 First half 2025 Finance income 3,217 5,359 Finance expense (3,707) (5,729) Net finance income (expense) from financial assets at fair value through profit or loss 95 111 Income (expense) from derivative financial instruments 9 (70) Finance income (expense) (386) (329) (€ million) First half 2026 First half 2025 Finance income (expense) related to net borrowings Interest and other finance expense on ordinary bonds (346) (367) Net finance income (expense) on financial assets held for trading 94 120 Net expenses on other financial assets valued at fair value with effects on profit and loss 1 (9) Interest and other expense due to banks and other financial institutions (164) (129) Interest on lease liabilities (162) (180) Interest from banks 68 103 Interest and other income on financial receivables and securities held for non-operating purposes 129 94

(380) (368)

Foreign exchange differences 93 182 Income (expense) from derivative financial instruments 9 (70) Other finance income (expense) Capitalized finance expense 35 70 Interest and other income on financing receivables and securities held for operating purposes 18 18 Finance expense due to the passage of time (accretion discount) (a) (142) (162) Other finance income (expense) (19) 1

(108) (73)

(386) (329)

(a) The item relates to the increase in provisions that are shown at present value in non-current liabilities.

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

85

28 Income (expense) from investments Share of profit (loss) of equity-accounted investments Information relating to gains and losses on investments accounted for using the equity method is provided in note 13 – Investments.

Other gain (loss) from investments

Dividend income related to Nigeria LNG Ltd for €31 million (€52 million in the first half of 2025) and Everen Ltd for €20 million (€30 million in the first half of 2025).

Other net income mainly related for €2,088 million to the gain arising from the fair value measurement of the business combination between Eni and Petronas in relation to the joint venture Searah Ltd, including the reclassification to profit and loss accounts of currency translation differences negative for €71 million.

29 Income taxes

The tax rate for the first half of 2026 in continuing operations was 44.0%. The higher tax rate compared to the IRES tax rate currently in force in Italy of 24% is essentially due to the higher taxation of foreign companies in the Exploration & Production segment.

The effects of the application of the OECD provision relating to a global minimum level of taxation for multinational business groups introduced by EU Directive 2022/2523 (so-called Pillar 2) are not significant.

30 Earnings per share Basic earnings per share are calculated by dividing the profit of the period attributable to Eni’s shareholders by the weighted average number of ordinary shares issued and outstanding during the period, excluding treasury shares.

Diluted earnings per share are calculated by dividing the profit of the period attributable to Eni’s shareholders by the weighted average number of fully diluted shares, excluding treasury shares, and including the number of potential shares to be issued.

As of June 30, 2026, the shares that could be potentially issued related to the estimation of new shares that will vest in connection with the 2023-2025 Long-Term Monetary Incentive Plan and the shares relating to the convertible bond issued in 2023.

In determining basic and diluted earnings per share, the profit of the period attributable to Eni is adjusted to take into account the remuneration, calculated by using the amortized cost method, net of tax effect of perpetual subordinated bonds and, limited to diluted earnings per share, of convertible bond.

(€ million) First half 2026 First half 2025 Dividends 60 100 Other net income (expense) 2,086 6

2,146 106

(€ million) First half 2026 First half 2025 Current taxes 1,832 1,961 Net deferred taxes 285 95

2,117 2,056

ENI

86 ENI INTERIM CONSOLIDATED REPORT 2026

The determination of basic and diluted earnings per share is indicated below:

31 Segment information Eni’s segmental reporting is based on the Group’s operating segments, whose results are regularly reviewed by the Chief Operating Decision Maker (the CEO) to assess underlying business performance and to allocate funds to segment’s capital projects.

With regard to financial information by business segment (“segment information”), management has determined that the decision-making processes regarding funds allocation and the assessment of financial and industrial performance by the CEO take place at a more disaggregated level than the operating segments utilized for reporting purposes. As permitted by the international reporting standard that regulates the segment reporting (IFRS 8), Eni’s reportable segments as of June 30, 2026, have been defined as follows:

- Exploration & Production : exploration, development and production of crude oil, condensates and natural gas. The business also engages in oil and products trading activities, designed to perform supply balancing transactions in the market for refining operations, and to stabilize or hedge commercial margins.

- Global Gas & LNG Portfolio (GGP) and Power : wholesale supply and marketing of gas via pipeline, international transport and purchase and marketing of equity and third-party LNG. It includes gas trading activities finalized to hedge and stabilize commercial margins, as well as to optimize the gas asset portfolio. This reportable segment includes the results of the Power business, which involves the generation and wholesale of electricity from thermoelectric plants, which presents similar economic returns given the commonality of industrial dynamics relating to gas and electricity demand. It includes trading of CO 2 emission certificates and forward power sales for the purpose of hedging/optimizing margins.

- Refining, Chemicals and Sites in transformation : Oil processing activities for the production of traditional fuels carried out by the "Refining" operating segment and the production of petroleum-based chemicals, carried out by its wholly owned subsidiary Versalis and its subsidiaries, which have been combined into a single reportable segment because the two activities exhibit similar economic returns and have exposure to common market dynamics. Versalis also engages in the production of bioplastics through its subsidiary Novamont and in compounding chemistry. The business Sites in transformation manage the restructuring, remediation/decommissioning and site preparation activities in view of the subsequent phase of investments for the reconversion/transformation of shutdown petrochemical or refinery hubs.

- Enilive: engages in the manufacturing of biofuels from renewable feedstock and in retail marketing activities of traditional fuels and biofuels as well as products and services aimed at drivers with a view to sustainable mobility. It also engages in wholesale marketing of fuels, bitumen and lubricants.

- Plenitude : engages in the retail sales of gas, electricity and related services, production and wholesale of electricity from First half

2026First half

2025

Weighted average number of shares used for basic earnings per share 2,939,974,225 3,056,156,097 Potential shares to be issued for LTI incentive plan 8,057,287 5,621,740 Potential shares to be issued for convertible bond 57,578,811 56,975,836 Weighted average number of shares used for diluted earnings per share 3,005,610,323 3,118,753,673 Profit attributable to Eni shareholders (€ million) 4,390 1,715 Remuneration of subordinated perpetual bonds net of tax effect (€ million) (132) (116) Eni’s shareholders profit for basic earnings per share (€ million) 4,258 1,599 Remuneration of convertible bond net of tax effect (€ million) 16 15 Eni’s shareholders profit for diluted earnings per share (€ million) 4,274 1,614 Basic earnings per share (€ per share) 1.45 0.52 Diluted earnings per share (€ per share) 1.42 0.52 Eni’s shareholders profit - continuing operations (€ million) 3,023 (406) Remuneration of subordinated perpetual bonds net of tax effect (€ million) (132) (116) Eni’s shareholders profit - continuing operations for basic earnings per share (€ million) 2,891 (522) Remuneration of convertible bond net of tax effect (€ million) 16 15 Eni’s shareholders profit - continuing operations for diluted earnings per share (€ million) 2,907 (507) Basic earnings per share (€ per share) 0.98 (0.17) Diluted earnings per share (€ per share) 0.97 (0.17) Eni’s shareholders profit - discontinued operations for basic and diluted earnings per share (€ million) 1,367 2,121 Basic earnings per share (€ per share) 0.47 0.69 Diluted earnings per share (€ per share) 0.45 0.69

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

87

renewable energy plants, and electric mobility services (installation of charging points).

- Corporate and Other activities : includes the main business support functions, in particular holding, central treasury, IT, human resources, real estate services, captive insurance activities, research and development, new technologies, business digitalization and the environmental activity managed by the subsidiary Eni Rewind. The segment also includes activities related to CCUS, agri-business, forest conservation and production of bioenergy, and projects currently under development.

Segment information presented to the CEO (the Chief Operating Decision Maker, ex IFRS 8) includes: revenues, operating profit and directly attributable assets and liabilities.

As a result of the planned reorganization of the ownership structure of the subsidiary Plenitude, aimed at modifying the governance to establish joint control over the entity with a private equity fund, the Plenitude business (Eni 70%) has been classified as a discontinued operation. Comparative data has been restated accordingly. The financial information relating to the Plenitude business continues to be reported within the segment information, as it is still reviewed by the Chief Operating Decision Maker.

The main performance items relating to the restatement for discontinued operations are set out below.

Information as reported in 2025

Information as restated

(€ milioni)

Exploration &

Production

Global Gas & LNG

Portfolio and

Power

Refining and

Chemicals

Enilive

Plenitude

Eliminations

Total

Corporate and

Other activities

Adjustments for

intragroup profits

Total

First half 2025 Sales from operations (a)24,942 9,034 9,465 9,536 5,603 (17,374) 41,206 126 41,332 Operating profit 3,446 1,358 (1,302) 174 64 3,740 (539) 289 3,490 December 31, 2025 Identifiable assets (b)60,407 4,988 6,377 6,117 13,622 91,511 2,630 (253) 93,888 (a) Including intersegment sales.

(b) Including assets/liabilities directly associated with the generation of operating profit. Does not include financial assets and liabilities, investments income tax assets and liabilities.

(€ milioni)

Exploration &

Production

Global Gas & LNG Portfolio and Power

Refining, Chemicals

and Sites in

transformation

Enilive

Plenitude

Eliminations

Total

Corporate and Other

activities

Adjustments for

intragroup profits

Total

Plenitude

Intragroup

eliminations

Continuing

operations

First half 2025 Sales from operations (a)24,942 9,034 9,465 9,536 5,603(17,374) 41,206 126 41,332 (5,603) 2335,752 Operating profit 3,446 1,358(1,302) 174 64 3,740 (539) 2893,490 (64)(2,375) 1,051 December 31, 2025 Identifiable assets (b)60,407 4,988 6,377 6,117 13,622 91,511 2,630 (253)93,888 (a) Including intersegment sales.Discontinued

operations

(b) Including assets/liabilities directly associated with the generation of operating profit. Does not include financial assets and liabilities, investments income tax assets and liabilities.

ENI

88 ENI INTERIM CONSOLIDATED REPORT 2026

Segment Information:

32 Transactions with related parties In the ordinary course of its business, Eni enters into transactions mainly regarding:

(a) purchase/supply of goods and services and provision of financing to joint ventures, associates and unconsolidated

subsidiaries;

(b) purchase/supply of goods and services to entities controlled by the Italian Government;

(c) contributions to Eni Foundation e a Fondazione Eni Enrico Mattei, non-profit entities correlated to Eni with the aim to develop solidarity, culture and research. Transactions with these parties are not material.

There were no material transactions involving Directors, Statutory Auditors or their affiliates Transactions with related parties were conducted in the interest of the Eni companies and, with exception of those with entities whose aim is to develop charitable, cultural and research initiatives, are related to the ordinary course of Eni’s business.

(€ milioni)

Exploration &

Production

Global Gas & LNG Portfolio and Power

Refining, Chemicals

and Sites in

transformation

Enilive

Plenitude

Total

Corporate and Other

activities

Adjustments for

intragroup profits

Total

Plenitude

Intragroup

eliminations

Continuing

operations

First half 2026 Sales from operations including intersegment sales 30,317 9,433 10,553 11,674 5,305 67,282

- less intersegment sales (8,362) (2,175) (7,954) (1,543) (24) (20,058) Sales from operations 21,955 7,258 2,599 10,131 5,281 47,224 113 47,337 (5,281) 42,056 Operating profit 3,502 381 (302) 375 826 4,782 (615) (96) 4,071 (826) (1,363) 1,882 First half 2025 Sales from operations including intersegment sales 24,942 9,034 9,465 9,536 5,603 58,580

- less intersegment sales (6,958) (2,493) (6,580) (1,320) (23)(17,374) Sales from operations 17,984 6,541 2,885 8,216 5,580 41,206 126 41,332 (5,580) 35,752 Operating profit 3,446 1,358 (1,302) 174 64 3,740 (539) 289 3,490 (64) (2,375) 1,051Discontinued

operations

(€ milioni)

Exploration &

Production

Global Gas & LNG

Portfolio and

Power

Refining,

Chemicals and

Sites in

transformation

Enilive

Plenitude

Total

Corporate and

Other activities

Adjustments for

intragroup profits

Total

June 30, 2026 Identifiable assets (a)58,956 5,683 7,973 7,229 13,590 93,431 3,109 (374) 96,166 Unallocated assets (b) 50,839 Identifiable liabilities (a) 20,408 5,530 5,421 3,584 4,299 39,242 5,118 (106) 44,254 Unallocated liabilities (b) 45,821 December 31, 2025 Identifiable assets (a)60,407 4,988 6,377 6,117 13,622 91,511 2,630 (253) 93,888 Unallocated assets (b) 43,181 Identifiable liabilities (a) 19,934 4,691 4,153 3,303 5,490 37,571 5,239 (90)42,720 Unallocated liabilities (b) 41,562 (b) Including assets/liabilities not directly associated with the generation of operating profit.(a) Including assets/liabilities directly associated with the generation of operating profit. Does not include financial assets and liabilities, investments income tax assets and liabilities..

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

89

TRADE AND OTHER TRANSACTIONS AND BALANCES WITH RELATED PARTIES

(€ million)

Continuing operations

Joint venture and associates Agiba Petroleum Co 4 191 1 248 Coral FLNG SA 16 1,286 11 Eni CCUS Holding 159 1,234 132 Azule Group 137 496 3,033 45 1,042 70 Saipem Group 41 213 9 4 395 SeaCorridor Group 57 37 1 207 Vårgrønn Group 548 1 In Salah Gas Ltd 101 428 Ithaca Energy Plc 82 85 5 228 (359) Karachaganak Petroleum Operating BV 30 166 1 542 Mellitah Oil & Gas BV 60 383 3 625 Petrobel Belayim Petroleum Co 16 556 3 324 Searah Ltd 53 282 4 Société Centrale Electrique du Congo SA 36 37 St. Bernard Renewables Llc 126 10 Vår Energi ASA 16 1,682 2,014 20 4,391 (28) Others (*)155 68 5 79 126 862 3,978 8,537 347 8,566 (317) Unconsolidated entities controlled by Eni Industria Siciliana Acido Fosforico - ISAF SpA (in liquidation) 174 1 4 Others 15 11 14 9 6 189 12 14 13 6 1,051 3,990 8,551 360 8,572 (317) Entities controlled by Italian Government Enel Group 117 110 23 7 14 Snam Group 168 183 171 689 Terna Group 102 92 246 207 3 GSE - Gestore Servizi Energetici 110 128 974 289 132 Others (*)55 31 64 16 552 544 1,478 1,208 149 Other related parties 2 2 17 Groupement Sonatrach – Eni «GSE» 288 238 25 267 1,893 4,774 8,551 1,863 10,064 (168)

Discontinued operations

Joint venture and associates Vårgrønn Group 139 Others 15 13 27 9 15 15 13 166 9 15 Unconsolidated entities controlled by Eni Others 4 2 4 2 Entities controlled by Italian Government Enel Group 1 138 2 378 Italgas Group 66 6 429 Terna Group 8 39 9 130 GSE - Gestore Servizi Energetici 30 57 161 357 Others 7 15 46 7 46 315 224 1,301 65 328 168 233 1,316 Total 1,958 5,102 8,719 2,096 11,380 (168) (*) Each individual amount included herein was lower than €50 million. June 30, 2026 First half 2026

Receivables

and other

assetsPayables

and other

liabilitiesGuarantees Revenues CostsOther

operating

(expense)

income

ENI

90 ENI INTERIM CONSOLIDATED REPORT 2026

(€ million)

Continuing operations

Joint venture and associates Agiba Petroleum Co 3 135 162 Cardón IV SA 1 134 2 Coral FLNG SA 12 1,247 9 Eni CCUS Holding 118 1,218 Azule Group 119 361 2,939 36 679 Saipem Group 41 136 9 2 311 SeaCorridor Group 67 19 1 165 Vårgrønn Group 1 678 1 In Salah Gas Ltd 57 83 Ithaca Energy Plc 146 73 164 (343) Karachaganak Petroleum Operating BV 27 119 512 Mellitah Oil & Gas BV 56 241 395 Petrobel Belayim Petroleum Co 13 470 1 364 Società Oleodotti Meridionali SpA 22 500 14 10 Société Centrale Electrique du Congo SA 91 44 St. Bernard Renewables Llc 1 98 Vår Energi ASA 26 1,321 1,948 33 2,520 Others (*) 86 78 26 36 158 830 3,644 8,163 179 5,523 (343) Unconsolidated entities controlled by Eni Industria Siciliana Acido Fosforico - ISAF SpA (in liquidation) 170 1 4 VME Oilfield Chemicals Llc 112 Others 19 10 21 11 6 189 11 133 15 6 1,019 3,655 8,296 194 5,529 (343) Entities controlled by Italian Government Enel Group 89 183 20 46 2 Italgas Group 2 190 2 Snam Group 110 247 (6) 602 Terna Group 62 75 160 82 1 GSE - Gestore Servizi Energetici 112 100 622 289 157 ITA Airways - Italia Trasporto Aereo SpA 3 69 Others (*) 45 70 28 25 423 865 893 1,046 160 Other related parties 4 17 Groupement Sonatrach – Eni «GSE» 216 307 20 271 1,658 4,831 8,296 1,107 6,863 (183)

Discontinued operations

Joint venture and associates Others 1 21

1 21

Unconsolidated entities controlled by Eni

Others 1

1 Entities controlled by Italian Government Enel Group 1 333 Italgas Group 5 353 Snam Group 10 Terna Group 17 87 GSE - Gestore Servizi Energetici 483 613 Others 24 6

540 1,392

542 1,413

Total 1,658 4,831 8,296 1,649 8,276 (183) (*) Each individual amount included herein was lower than €50 million.December 31, 2025 First half 2025

Receivables

and other

assetsPayables

and other

liabilitiesGuarantees Revenues CostsOther

operating

(expense)

income

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

91

The most significant transactions with joint ventures, associates and unconsolidated subsidiaries concerned:

- Eni’s share of expenses incurred to develop oil fields from Agiba Petroleum Co, Karachaganak Petroleum Operating BV, Mellitah Oil & Gas BV, Petrobel Belayim Petroleum Co, Groupement Sonatrach - Eni «GSE» and, limited to Karachaganak Petroleum Operating BV, purchase of crude oil by Eni Trade & Biofuels SpA; costs recovered from Eni associates are invoiced on the basis of costs incurred;

- supply of upstream specialist services and a guarantee issued on a pro-quota basis granted to Coral FLNG SA on behalf of the Consortium TJS for the contractual obligations assumed following the award of the EPCIC contract for the construction of a floating gas liquefaction plant;

- guarantees issued on behalf of Eni CCUS Holding in relation with the sale of CCUS assets in the United Kingdom and the

Netherlands;

- supply of upstream specialist services, purchase of crude oil and issue of guarantees against leasing contracts of FPSO vessels to Azule Group;

- engineering, construction and drilling services by Saipem Group mainly for the Refining business line and for the Exploration & Production segment;

- acquisition of transport services from SeaCorridor Group;

- guarantees issued to Vårgrønn Group mainly in relation to the participation in the Dogger Bank offshore wind project;

- the purchase of gas from In Salah Gas Ltd;

- receivables relating to the business combination, the purchase of crude oil and condensate and the stipulation of derivative contracts on commodities with Ithaca Energy Plc Group;

- the issuance of guarantees in the interest of Searah Ltd in relation to exploration and production activities in Malaysia and

Indonesia;

- sale of gas to Société Centrale Electrique du Congo SA;

- guarantees issued in the interest of St. Bernard Renewables LLC on behalf of suppliers for feedstock purchasing

operations;

- guarantees issued in compliance with contractual agreements in the interest of Vår Energi ASA, the supply of upstream specialist services and maritime transport, the purchase of crude oil, condensates and gas, and the executed portion of physical gas purchase forward contracts;

- services for environmental restoration to Industria Siciliana Acido Fosforico - ISAF SpA (in liquidation).

The most significant transactions with entities controlled by the Italian Government concerned:

- sale of fuel and combustibles, sale and purchase of gas, acquisition of power distribution services and derivatives instruments with Enel Group;

- acquisition of natural gas distribution, transportation and storage services with Italgas Group and Snam Group on the basis of the tariffs set by the Italian Regulatory Authority for Energy, Networks and Environment, as well as, from the Snam group, the receivable for divestment relating to the sale of the 49.9% share capital of SeaCorridor Srl and the purchase and sale of gas for granting the system balancing needs on the basis of prices referred to the quotations of the main energy

commodities;

- acquisition of electricity transmission services and sale and purchase of electricity for granting the system balancing based on prices referred to the quotations of the main energy commodities, and derivatives on commodities entered to hedge the price risk related to the utilization of transport capacity rights with Terna Group;

- sale and purchase of electricity, gas, environmental certificates and fair value of derivative instruments, sale of oil products and storage capacity with GSE - Gestore Servizi Energetici for the setting-up of a specific stock held by the Organismo Centrale di Stoccaggio Italiano (OCSIT) according to the Legislative Decree No. 249/12; the contribution to cover the charges deriving from the performance of OCSIT functions and activities and the contribution paid to GSE for the use of biomethane and other advanced biofuels in the transport sector;

- the sale of jet fuel to ITA Airways - Italia Trasporto Aereo SpA.

ENI

92 ENI INTERIM CONSOLIDATED REPORT 2026

Transactions with other related parties concerned:

- provisions to pension funds managed by Eni of €12 million and debts for contributions to be paid for €2 million;

- costs for contributions paid to the Supplementary Healthcare Fund for Managers of Eni Group Companies (FISDE) for €3

million;

- contributions paid and service provisions to Eni Enrico Mattei Foundation for €2 million.

FINANCING TRANSACTIONS AND BALANCES WITH RELATED PARTIES

(€ million)

Continuing operations

Joint ventures and associates Coral FLNG SA 408 7 E&E Algeria Touat BV 92 Eni CCUS Holding 133 14 8 Saipem Group 98 3 Mozambique Rovuma Venture SpA 2,779 173 91 8 Searah Ltd 80 St. Bernard Renewables Llc 66 140 2 Pengerang Biorefinery Sdn Bhd 46 481 Others (*)14 76 26 20 3,446 533 621 134 31 Unconsolidated entities controlled by Eni Others (*)38 68 1 1 38 68 1 1 Entities controlled by Italian Government Cassa Depositi e Prestiti Group 66 2 Others 21 1 87 2 1 Other related parties 2 1 3,484 690 621 135 35 1

Discontinued operations

Joint ventures and associates Others 39 4 1 39 4 1 Unconsolidated entities controlled by Eni

Others 6

6 Entities controlled by Italian Government Cassa Depositi e Prestiti Group 51 1

Others 5

56 1

45 56 4 1 1 Total 3,529 746 625 136 36 1 (*) Each individual amount included herein was lower than €50 million.June 30, 2026 First half 2026

Receivables

and cash

and cash

equivalentsPayables GuaranteesFinance

incomes and

derivative

financial

instrumentsFinance

ExpensesGain on

disposals

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

93

The most significant transactions with joint ventures, associates and unconsolidated subsidiaries concerned:

- a financing loan granted to Coral FLNG SA for the construction of a floating gas liquefaction plant in Area 4 offshore

Mozambique;

- a cash deposit at the Group finance companies in the interest of E&E Algeria Touat BV;

- a financing loan granted to Eni CCUS Holding, within the framework of the agreement with the partner Global Infrastructure

Partners;

- lease liabilities towards Saipem Group related to long-term contracts for the use of drilling rigs;

- a financing loan granted to Mozambique Rovuma Venture SpA for the development of gas reserves offshore Mozambique;

- cash deposits at the Group treasury companies of Searah Ltd;

- guarantees issued in the interest of the joint venture St. Bernard Renewables LLC in connection with the transfer of tax credits and the financing arrangements obtained by the joint venture;

- a Parent Company Guarantee in the interest of Pengerang Biorefinery Sdn Bhd under the Construction Term Facility Agreement in relation to the financing for the construction of a new biorefinery in Malaysia.

(€ million)

Continuing operations

Joint ventures and associates Coral FLNG SA 417 9 E&E Algeria Touat BV 56 Eni CCUS Holding 123 Saipem Group 247 11 Mozambique Rovuma Venture SpA 2,318 91 69 8 Others (*)70 57 4 21 3 2,928 451 4 99 22 Unconsolidated entities controlled by Eni Others (*)41 55 1 1 41 55 1 1 Entities controlled by Italian Government Cassa Depositi e Prestiti Group 52 Others 35 1 3 4 87 1 3 4 Other related parties 2,969 593 4 101 26 4

Discontinued operations

Joint ventures and associates

Others 1

1 Entities controlled by Italian Government Cassa Depositi e Prestiti Group 1 1 1 1 Total 2,969 593 4 102 27 4 (*) Each individual amount included herein was lower than €50 million.December 31, 2025 First half 2025

Receivables

and cash

and cash

equivalentsPayables GuaranteesFinance

incomes and

derivative

financial

instrumentsFinance

ExpensesGain (loss)

on disposals

ENI

94 ENI INTERIM CONSOLIDATED REPORT 2026

The most significant transactions with entities controlled by the Italian Government concerned:

- finance debts due to Cassa Depositi e Prestiti Group related to the development of electric vehicle charging infrastructure and in support of Agri Feedstock activities.

Impact of transactions and positions with related parties on the balance sheet, profit and loss account and statement of cash flows The impact of transactions and positions with related parties on the balance sheet consisted of the following:

(€ million) TotalRelated

parties Impact

% TotalRelated

parties Impact

% Cash and cash equivalent 8,365 8,100 Other current financial assets 5,034 2,813 55.88 3,710 2,357 63.53 Trade and other receivables 12,407 1,585 12.78 12,436 1,375 11.06 Other current assets 3,413 95 2.78 3,943 76 1.93 Other non-current financial assets 1,126 671 59.59 1,109 612 55.18 Other non-current assets 1,498 213 14.22 2,839 207 7.29 Discontinued operations and assets held for sale 18,533 110 0.59 8,005 Short-term debt 5,334 501 9.39 4,929 265 5.38 Current portion of long-term debt 2,388 34 1.42 3,434 128 3.73 Current portion of non-current lease liabilities 1,083 71 6.56 1,263 108 8.55 Trade and other payables 19,979 4,628 23.16 20,261 4,283 21.14 Other current liabilities 5,798 140 2.41 4,039 86 2.13 Long-term debt 23,827 66 0.28 20,139 52 0.26 Non-current lease liabilities 4,358 18 0.41 4,437 40 0.90 Other non-current liabilities 1,493 6 0.40 3,390 462 13.63 Liabilities directly associated with discontinued operations and assets held for sale 6,702 384 5.73 2,026June 30, 2026 December 31, 2025

INTERIM CONSOLIDATED R EPORT ANNEX CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

95

The impact of transactions with related parties on the profit and loss accounts consisted of the following:

Main cash flows with related parties are provided below:

The impact of cash flows with related parties consisted of the following:

(€ million) TotalRelated

parties Impact

% TotalRelated

parties Impact

%

Continuing operations

Sales from operations 42,056 1,645 3.91 35,752 1,005 2.81 Other income and revenues 673 218 32.39 649 102 15.72 Purchases, services and other (33,929) (10,072) 29.69 (30,054) (6,868) 22.85 Net (impairments) reversals of trade and other receivables (101) (1) 0.99 (73) (1) 1.37 Payroll and related costs (1,582) 9 .. (1,554) 6 ..

Other operating income (expense) (321) (168) 52.34 436 (183) ..

Finance income 3,217 135 4.20 5,359 101 1.88 Finance expense (3,707) (35) 0.94 (5,729) (26) 0.45 Other income (expense) from investments 2,146 1 0.05 106 4 3.77

Discontinued operations

Revenues 5,407 233 4.31 5,685 542 9.53 Operating costs (3,218) (1,316) 40.89 (3,246) (1,413) 43.53 Finance income (expense) 7 (81)First half 2026 First half 2025 (€ million) First half 2026 First half 2025 Revenues and other income 2,096 1,649 Costs and other expenses (9,913) (7,192) Other operating income (loss) (168) (183) Net change in trade and other receivables and payables (229) 691 Net interests 91 63 Net cash provided from operating activities (8,123) (4,972) Capital expenditure in tangible and intangible assets (1,466) (1,083) Net change in accounts payable and receivable in relation to investments 201 122 Change in financial receivables (102) (294) Net cash used in investing activities (1,367) (1,255) Change in financial and lease liabilities 67 294 Net cash used in financing activities 67 294 Change in cash and cash equivalents 1 Total financial flows to related parties (9,423) (5,932) (€ million) TotalRelated

parties Impact

% TotalRelated

parties Impact

% Net cash provided from operating activities 5,697 (8,123) .. 5,902 (4,972) ..

Net cash used in investing activities (5,654) (1,367) 24.18 (4,405) (1,255) 28.49 Net cash used in financing activities 68 67 98.53 (309) 294 ..First half 2026 First half 2025

ENI

96 ENI INTERIM CONSOLIDATED REPORT 2026

33 Significant non-recurring events and operations In the first half of 2026 and 2025, Eni did not report any non-recurring events and/or operations.

34 Positions or transactions deriving from atypical and/or unusual operations In the first half of 2026 and 2025, no transactions deriving from atypical and/or unusual operations were reported.

35 Subsequent events In July, a long-term partnership agreement was finalized 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 billion capital contribution to be cashed-in the third quarter of 2026. 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 practice for an aggregate amount equal to the investment to be made by it.

Certification pursuant to article 154-bis, paragraph 5 of the Legislative Decree No. 58/1998 (Testo Unico

della Finanza)

1.The undersigned Claudio Descalzi and Francesco Esposito , in their quality as Chief Executive Officer and Officer responsible for the preparation of financial reports of Eni, also pursuant to article 154-bis, paragraphs 3 and 4 of Legislative Decree No. 58 of February 24, 1998, certify that internal controls over financial reporting in place for the preparation of the condensed consolidat ed interim financial statements as of June 30, 2026 and during the period covered by the report, were:

•adequate to the Company structure, and •effectively applied during the process of preparation of the report.

2.Internal controls over financial reporting in place for the preparation of the condensed consolidated interim financial statements as of June 30, 2026 have been defined and the evaluation of their effectiveness has been assessed based on principles and methodologies adopted by Eni in accordance with the Internal Control -Integrated Framework Model issued by the Committee of Sponsoring Organizations of the Treadway Commission, which represents an internationally -accepted framework for the internal control system.

3.The undersigned officers also certify that :

3.1 Condensed consolidated interim financial statements as of June 30, 20 26:

a) have been prepared in accordance with applicable international accounting standards adopted by the European Community pursuant to Regulation (CE) n. 1606/2002 of the European Parliament and European Council of July 19, 2002 ;

b) correspond to the accounting books and ent ries;

c) fairly and truly represent the financial position, the performance and the cash flows of the issuer and the companies included in the consolidation as of, and for, the period presented in this report.

3.2 The interim management report include s a reliable analysis of the material events occurred during the first half of 20 26 and their impact on condensed consolidated interim financial statemen ts, as well as a description of the main risks and uncertainties for the second half of the year. The interim operating and financial review contains a reliable analysis of the disclosure on significant related -partly transaction .

July 28, 2026 /s/ Claudio Descalzi /s/ Francesco Esposito Claudio Descalzi Francesco Espo sito Chief Executive Officer Officer responsible for the preparation of financial reports 97

Review report on condensed consolidated interim financial

statements

To the Shareholders of

Eni SpA

Foreword

We have reviewed the accompanying condensed consolidated interim financial statements of Eni SpA and its subsidiaries ( the “Eni Group ”) as of 30 June 2026, comprising the consolidated balance sheet, consolidated profit and loss account , consolidated statement of comprehensive income (loss) , consolidated statement of changes in equity, consolidated statement of cash flows and related notes.

The directors are responsible for the preparation of the condensed consolidated interim financial statements in accordance with the accounting standard IAS 34 as issued by the International Accounting Standards Board and adopted by the European Union applicable to interim financial reporting. Our responsibility is to express a conclusion on these condensed consolidated interim financial statements based on our review.

Scope of review We conducted our work in accordance with the criteria for a review recommended by Consob in Resolution 10867 /1997. A review of condensed consolidated interim financial statements consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than a full- scope audit conducted in accordance with International Standards on Auditing (ISA Italia) and, consequently, does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an aud it opinion on the condensed consolidated interim financial statements. Report of Independent Auditors 98

2 of 2

Conclusion

Based on our review, nothing has come to our attention that causes us to believe that the condensed consolidated interim financial statements of Eni Group as of 30 June 2026 are not prepared, in all material respects, in accordance with the accounting standard IAS 34 as issued by the International Accounting Standards Board and adopted by the European Union applicable to interim financial reporting.

Rome , 31 July 2026

PricewaterhouseCoopers SpA

Signed by

Francesco Ronco

(Partner)

This review report has been translated into the English language solely for the convenience of international readers. Accordingly, only the original text in Italian language is authoritative. 99

ANNEX TO THE

CONSOLIDATED

INTERIM

FINANCIAL

STATEMENTS

Investments owned by Eni as of June 30, 2026 Changes in the scope of consolidation for the first half 101 102

INTERIM CONSOLIDATED R EPORT CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

101

ANNEX

INVESTMENTS OWNED BY ENI SPA AS OF JUNE 30, 202 6

As of June 30, 2026 , the breakdown of the companies owned by Eni is provided in the table below:

ItalyOutside

ItalyTotal ItalyOutside

ItalyTotal ItalyOutside

ItalyTotal

Fully consolidated subsidiaries 63 333 396 Consolidated joint operations 4 6 10 Investments owned by consolidated companies (b) Equity-accounted investments 12 51 63 35 88 123 Investments at cost 4 4 5 24 29 Investments at fair value 3 20 23 16 51 67 40 112 152 3 20 23 Investments owned by unconsolidated companies Owned by controlled companies 4 4 4 4 Owned by joint arrangements 1 35 36 4 4 1 39 40 Total 79 388 467 45 157 202 3 20 23SubsidiariesJoint arrangements and associatesOther significant

investments(a)

(a) Relate to investments other than subsidiaries, joint arrangements and associates w ith an ow nership interest greater than 2% for listed companies or 10% for unlisted companies.

(b) Investments in subsidiaries accounted using the equity method and at cost relate to non-significant companies.

ENI

102 ENI INTERIM CONSOLIDATED REPORT 202 6

Changes in the scope of consolidation for the first half 202 6

Fully consolidated subsidiaries

COMPANIES INCLUDED (No. 15)

Acea Energia SpA Rome Plenitude Acquisition Eni Argentina LNG BV Amsterdam Exploration & Production Relevancy Eni Cardon Holding BV Amsterdam Exploration & Production Relevancy Eni East Ganal BV The Hague Exploration & Production Relevancy Eni East Sepinggan BV The Hague Exploration & Production Relevancy Eni Ganal BV The Hague Exploration & Production Relevancy Eni Industrial Evolution SpA Rome Refining Relevancy Eni Muara Bakau II BV The Hague Exploration & Production Relevancy Eni North Ganal BV The Hague Exploration & Production Relevancy Eni Rapak BV The Hague Exploration & Production Relevancy Eni Uruguay Ltd London Exploration & Production Relevancy Eni West Ganal BV The Hague Exploration & Production Relevancy Pentagas Global Service Srl Segrate (MI) Plenitude Acquisition Siel Agrisolare Srl Cesena Plenitude Acquisition of control VME Oilfield Chemicals Llc Doha Chemicals Relevancy

INTERIM CONSOLIDATED R EPORT CONDENSED CONSOLIDATED INTERIM

FINANCIAL STATEMENTS

103

ANNEX

COMPANIES EXCLUDED (No. 23)

Consolidated Joint Operation

COMPANIES EXCLUDED (No. 1)

Eni China BV Amsterdam Exploration & Production Irrelevancy Eni East Ganal Ltd London Exploration & Production Lose of control Eni East Sepinggan Ltd London Exploration & Production Lose of control Eni Energy East Ganal BV The Hague Exploration & Production Lose of control Eni Energy East Sepinggan BV The Hague Exploration & Production Lose of control Eni Energy Group Holdings Ltd (in liquidation)London Exploration & Production Irrelevancy Eni Energy Group Ltd (in liquidation)London Exploration & Production Irrelevancy Eni Energy Group Midco Ltd (in liquidation)London Exploration & Production Irrelevancy Eni Energy Muara Bakau BV The Hague Exploration & Production Lose of control Eni Energy North Ganal BV The Hague Exploration & Production Lose of control Eni Energy West Ganal BV The Hague Exploration & Production Lose of control Eni Ganal Deepwater Ltd Hamilton Exploration & Production Lose of control Eni Ganal Ltd London Exploration & Production Lose of control Eni Isatay BV Amsterdam Exploration & Production Irrelevancy Eni Muara Bakau BV Amsterdam Exploration & Production Lose of control Eni North Ganal Ltd London Exploration & Production Lose of control Eni Plenitude Technical Services Romania Srl Cluj-Napoca Plenitude Sale Eni Rapak Deepwater Ltd Hamilton Exploration & Production Lose of control Eni Rapak Ltd London Exploration & Production Lose of control Eni West Ganal Ltd London Exploration & Production Lose of control Export LNG Ltd Hong Kong Exploration & Production Irrelevancy Versalis Kimya Ticaret Limited Sirketi Instambul Chemicals Irrelevancy Versalis UK Ltd London Chemicals Irrelevancy Blue Stream Pipeline Co BV Amsterdam Global Gas & LNG PortfolioChanges to contractual agreements relating to a joint arrangement

Eni SpA

Headquarters

Piazzale Enrico Mattei, 1 - Rome - Italy Capital Stock as of June 30, 2026: € 4,005,358,876.00 fully paid Branches Via Emilia, 1 - San Donato Milanese (Milan) - ItalyPiazza Ezio Vanoni, 1 - San Donato Milanese (Milan) - Italy

Contacts

eni.com+39-0659821800940924segreteriasocietaria.azionisti@eni.com

Investor Relations

Piazza Ezio Vanoni, 1 - 20097 San Donato Milanese (Milan)Tel. +39-0252051651 - Fax +39-0252031929e-mail: investor.relations@eni.com