Eni SpA

Eni is the most exploration-intensive of the European majors and has converted that capability into an unusually fast-cycle upstream machine: 900 million boe of resources discovered in 2025 alone, a 167% organic reserve replacement ratio, and roughly 11 billion boe of equity resources found since 2014. Around that core it has assembled a gas and LNG trading portfolio that monetises equity molecules into European and Asian markets, and two purpose-built transition vehicles — Plenitude (renewables, retail supply, e-mobility) and Enilive (biorefining and mobility retail) — each capitalised by outside private capital at valuations that together imply more than €23 billion of enterprise value. The satellite architecture is not incidental; it is the financing strategy. It allows Eni to fund transition growth off its own balance sheet while keeping upstream capital discipline intact. The result, as at mid-2026, is proforma gearing of 10% — the lowest in the company's 73-year history — alongside a rising distribution.

Eni S.p.A. is an Italian state-influenced integrated energy company, the smallest of the Western "supermajor" cohort by market value but among the most operationally distinctive, having built a strategy around exploration-led upstream growth, a natural-gas and LNG midstream franchise, and a "satellite" corporate-finance model that carves transition businesses into separately capitalised entities.

Eni describes itself in its 2025 Annual Report as an integrated energy company operating across the entire value chain — from exploration, development and extraction of oil and natural gas, through power generation from cogeneration and renewable sources, traditional and bio-refining, chemicals, and circular-economy processes, extending to end markets where it sells gas, power and products to retail and business customers together with energy-efficiency and sustainable-mobility services. The company frames its purpose around the "energy trilemma": environmental sustainability alongside energy security and affordability.

Independent characterisation. Eni is best understood as four businesses stapled to one balance sheet, with a fifth activity — financial engineering — that materially affects reported economics.

The first and dominant business is Exploration & Production, which generated proforma adjusted EBIT of €11,163 million in FY2025 out of a group total of €12,223 million, and €8,126 million in 1H 2026 out of €8,911 million. This is a price-taking, capital-intensive, reserve-depleting business whose competitive edge at Eni comes from exploration success rates and time-to-market rather than scale. Revenue is realised through the sale of crude, condensate and natural gas at benchmark-linked prices; the customer is effectively the global commodity market, with a meaningful share of gas volumes sold internally to the GGP segment.

The second is Global Gas & LNG Portfolio and Power (GGP), a midstream and marketing business that aggregates equity and third-party gas, optimises it across hubs, and sells into Italian and northern European markets plus a growing Asian LNG book. This is a margin business rather than a volume business, and its earnings are driven by contract renegotiations, asset-backed trading and portfolio optimisation. Worldwide gas sales were 43.72 bcm in FY2025 with LNG sales of 12.1 mmtonnes; 1H 2026 gas sales were 24.65 bcm, up 17% year on year.

The third is Transition Businesses, comprising Enilive and Plenitude. Enilive is a biorefining and mobility-retail hybrid: it converts waste and residue feedstocks to HVO diesel and SAF through the proprietary Ecofining process, and sells fuel and services through roughly 5,294 European service stations. Plenitude combines renewable generation (6.0 GW installed at 30 June 2026), retail energy supply (10.8 million customers) and EV charging (23,200 points). Plenitude is the one part of Eni with a genuine subscription-like revenue model — recurring retail supply contracts — and it is precisely this recurring customer base that management argues makes the renewables build-out bankable.

The fourth is Refining, Chemicals and Sites in Transformation, the structurally challenged leg. Refining is a European crack-spread business; chemicals, run through Versalis, has been loss-making through the European industry downturn and is being shrunk and converted. "Sites in transformation" is a new sub-segment created to house the decommissioning and remediation of closed petrochemical hubs — an explicit accounting acknowledgment that these assets are now a cost centre with an option value attached.

The fifth activity, the satellite model, is not a reporting segment but drives a large share of value realisation. By selling minority stakes in Enilive (KKR, ~€3.6 billion), Plenitude (Energy Infrastructure Partners and Ares Management, €2 billion for 20% implying more than €12 billion enterprise value, subsequently 13.1 billion implied after a further 5% sale to Ares) and Eni CCUS Holding (Global Infrastructure Partners, 49.99%), Eni converts development-stage assets into cash and third-party funding commitments without ceding operational control. In 2026 the model was extended to upstream itself, with a $2 billion capital contribution from an Ares-managed vehicle against an infrastructure-based upstream portfolio.

Revenue model mix is overwhelmingly product sales (crude, gas, LNG, refined products, chemicals, biofuels, electricity) rather than services, subscriptions or licensing. The service and recurring components — retail energy contracts at Plenitude, EV charging, energy-efficiency services, Eni Rewind environmental remediation performed for third parties, and technology licensing of Ecofining — are strategically significant but a small share of consolidated turnover. End markets served are, in descending order of contribution: global crude and refined-product markets, European wholesale and retail gas and power, Asian and European LNG buyers, European road transport and marine fuels, and industrial chemicals customers.

The 2026–2030 Strategic Plan

Presented at the Capital Markets Update on 19 March 2026. Management articulated four connected and synergistic pillars: Exploration & Production as the cornerstone; the gas and LNG midstream; technology; and the transition satellites, all sitting on a financial strategy of low gearing and enhanced returns.

Descalzi's framing at the event: "Eni's strategic cornerstone remains consistency, which is crucial in an uncertain and volatile market environment. Our world-class exploration operations, our significant project execution capabilities, our cutting-edge technologies, and a clear and defined financial strategy are the pillars that synergistically fuel our growth, guarantee resilience, and a highly attractive remuneration policy for our shareholders."

On the FY2025 results, Descalzi's stated theme was that "the consistent execution of our strategy, developed in the most recent years, is delivering a resilient business with structurally stronger earnings power."

Medium-term financial targets (2026–2030)

The plan reduces average annual investment by approximately €2 billion versus the 2025–2028 plan, attributed to efficiency and focus initiatives and to the deconsolidation of certain activities. The distribution range was raised from 35–40% to 35–45% of CFFO.

Business-unit targets

Zero entries indicate the figure was not disclosed for that period on a comparable basis. Enilive's 2026 EBITDA guidance was initially €1.1 billion and was revised upward to €1.3 billion at the 2Q 2026 results. Enilive's 5 Mt biofuel capacity target carries optionality for more than 2 Mt of SAF. Approximately 2 Mt of capacity (Eni share) was under construction across five projects as at March 2026.

Announced strategic initiatives, last 24 months

Satellite capitalisation and deconsolidation. KKR's minority investment in Enilive completed with €3.6 billion of proceeds. Ares Management closed a 20% investment in Plenitude for €2 billion in 2025, implying enterprise value above €12 billion; a further 5% sale to Ares lifted implied enterprise value to €13.1 billion. GIP acquired 49.99% of Eni CCUS Holding. In aggregate Eni cites over €23 billion of enterprise value crystallised through private-capital transactions in its two main transition businesses.

Plenitude deconsolidation (announced 19 March 2026). A reorganisation of Plenitude's shareholding structure with Ares and Energy Infrastructure Partners to establish joint control between Eni and Ares, effected via a non-proportional capital increase of approximately €1.5 billion of which at least €1 billion is expected from Ares. Eni retains approximately 65%. Plenitude was accounted for as a discontinued operation from 1Q 2026; completion was targeted for 3Q 2026. The transaction is expected to reduce Eni's consolidated gearing by approximately 3.5 percentage points.

Searah (Petronas JV). Binding agreement signed 2025, entity established June 2026, seven months from signing. 50/50, unconsolidated, combining Indonesian and Malaysian gas portfolios; described by Eni as its largest-ever business combination.

Mercuria trading JV (July 2026). Equally owned, independently operated global commodity trading venture spanning oil, biofuels, gas, LNG and logistics/infrastructure rights.

Ares/PIMCO upstream infrastructure partnership (2Q 2026). A partnership with AC Europe II SCSp, an Ares Credit Management vehicle, in exchange for a $2 billion capital contribution cashed in 3Q 2026, backed by binding commitment letters from Ares Alternative Credit Asset Management funds and PIMCO.

Critical minerals entry (2026). Acquisition of an 11.6% stake in Nouveau Monde Graphite (Canada, natural graphite and advanced battery materials) in May 2026, and an agreement to acquire 25% of EnergyX's Chilean subsidiary Black Giant SpA, holding a northern Chile lithium project using lower-impact extraction technology, in July 2026. Both support the Brindisi stationary-battery gigafactory.

Fusion. RH3OVA, a joint venture with the UK Atomic Energy Authority formed July 2026, delivering specialist consultancy and operational services to the fusion industry, focused on the fuel cycle. Eni retains its longstanding magnetic confinement fusion programme.

Chemicals conversion. Versalis transformation plan with permanent closure of the Brindisi and Priolo crackers; a Priolo SPV to build a biorefinery complemented by a post-consumer plastics recycling plant using proprietary technology; the LFP battery facility at Brindisi; and a partnership with Lummus Technology.

Sustainability and ESG commitments. Net Zero upstream Scope 1 and 2 by 2030; carbon neutrality by 2050; zero routine flaring across operated assets, achieved and maintained through 1H 2026; methane emissions intensity maintained below the 0.2% industry benchmark; a commitment to provide clean-cooking access to 20 million people by 2030, with 2.2 million reached in 2025 alone and approximately 3.7 million cumulatively; maintenance of 70% of R&D expenditure directed to decarbonisation.

2026 guidance as revised at 2Q results

The initial production growth guidance was a 3–4% range, shown here at its midpoint; the revised figure is "around 5%." Initial GGP guidance is shown as the implied base against which the revised figure represents a 40% increase. A zero entry indicates the assumption was not stated at the initial guidance date.

Distribution mechanics. Eni returns 60% of CFFO upside above the budgeted €11.5 billion to shareholders via buyback up to a Brent price of $90/bbl. Above $90/bbl Brent, or where gas prices or refining margins exceed budget by 50%, the policy is to return 100% of the incremental cash flow, via extraordinary dividend. With the revised SERM assumption at $14/bbl against a $6 budget, an extraordinary dividend was expected to be defined in October 2026 and paid in the fourth quarter, provided the margin remains at or above $9/bbl. Group sensitivities are €0.11 billion of CFFO per $1 change in Brent, €0.08 billion per $1 change in SERM, and €0.03 billion per €1/MWh change in European spot gas.

Exploration & Production

Crude oil and condensate. Equity liquids production averaged 832 kbbl/d in 2Q 2026 and 847 kbbl/d in 1H 2026, against 825 kbbl/d in 2Q 2025. Average liquids realisation was $96.50/bbl in 2Q 2026 versus $62.77/bbl a year earlier, against a Brent dated marker of $104.52 (2Q 2026) and $67.82 (2Q 2025). Target customers are refiners and trading houses; pricing is benchmark-linked, with no disclosed premium pricing model.

Natural gas (equity). Production of 5,006 mmcf/d in 2Q 2026 and 4,950 mmcf/d in 1H 2026, up 14% and 11% respectively year on year, driven by organic growth in Norway and Congo. Average gas realisation $8.42/kcf in 2Q 2026 against $7.14 a year earlier.

Named flagship upstream assets and projects.

• Zohr (Egypt, offshore Eastern Mediterranean) — the largest Mediterranean gas discovery, in production since December 2017. Now also designated as host processing infrastructure for third-country volumes: the Cyprus Cronos development will be transported to and processed at Zohr facilities.
• Nooros (Egypt) — Nile Delta gas, in production since 2015.
• Denise W 1 (Egypt, Temsah Concession) — April 2026 discovery, preliminary estimate ~2 Tcf gas in place plus 130 Mbbl condensate, near existing facilities for fast-track development.
• Baleine (Côte d'Ivoire) — Eni-operated, phased development. FID on Phase 3 taken May 2026, taking full-field oil production to 150 kbbl/d and gas to 200 mmcf/d, roughly doubling current rates. Eni sold a 10% interest to SOCAR with expected closing in 1Q 2026 and a further divestment near completion at mid-2026.
• Congo LNG / Marine XII (Republic of Congo) — Phase 2 started up ahead of plan, raising capacity to the 3 MTPA design target from 0.6 MTPA; first LNG loading from the expanded facility achieved February 2026. A previously announced disposal of a 25% interest lapsed when conditions precedent were not satisfied; the asset was reclassified to continuing operations with a net revaluation gain of approximately €0.29 billion.
• Coral South, Coral North and Rovuma LNG (Mozambique, Area 4) — floating and onshore LNG developments operated through the Mozambique Rovuma Venture.
• Kutei Basin hubs (Indonesia) — Jangkrik and Merakes in production; the Geliga-1 discovery (Eni 82%, Ganal block, April 2026) with preliminary in-place resources of ~5 Tcf and 300 Mbbl condensate supports a possible third production hub; the Konta discovery (4Q 2025) indicated potential in excess of 1 Tcf.
• Searah (Indonesia/Malaysia) — 50/50 JV with Petronas established June 2026; 19 gas-producing and development assets (14 Indonesia, 5 Malaysia); ~300 kboe/d current production with a sustainable plateau target above 500 kboe/d; a $6 billion revolving credit facility secured; investment pipeline in excess of $20 billion over five years to develop more than 3 billion boe of discovered resources.
• Greater PAJ (Angola, Blocks 31 and 31/21, operated by Azule Energy) — FID June 2026; five fields developed via a new FPSO with 95 kbbl/d oil and 70 mmcf/d gas capacity; start-up expected 1H 2029.
• NGC / New Gas Consortium (Angola) — first non-associated gas project in the country; gas treatment plant inaugurated with first gas into plant February 2026, feeding Angola LNG and the domestic market.
• Cronos (Cyprus, Block 6) — FID July 2026, first Cypriot gas targeted for 2028, plateau ~500 mmcf/d, routed via Zohr and liquefied at Damietta. Eni markets 50% of the LNG, equivalent to 1.4 MTPA.
• Kashagan, Karachaganak (Kazakhstan) — legacy giant fields. From 2026 Eni discontinued separate country reporting for Kazakhstan reserves and production, as the country fell below the 15% US SEC single-country disclosure threshold for three consecutive years; data are now aggregated into "Asia."
• Ghasha, Ruwais (United Arab Emirates); Bahr Essalam / Sabratha Compression (Libya, with NOC — start-up June 2026, supporting roughly 800 mln cubic metres per year of additional gas); Bir Rebaa North (Algeria); Adam, Tataouine (Tunisia); OCTP (Ghana); Area 1 (Mexico); Balder and Norwegian assets via Vår Energi.
• Argentina LNG — 12 MTPA integrated upstream-to-liquefaction project with YPF and XRG, via two 6 MTPA floating LNG units, fed by Vaca Muerta gas. Joint Development Agreement signed; in June 2026 Eni agreed to acquire a 32% interest in three upstream blocks (Meseta Buena Esperanza, Aguada Villanueva, Las Tacanas).
• New geographies entered 2025–2026 — Uruguay (50% and operatorship of offshore Block OFF-5), The Gambia (Block A1, awarded June 2026), and a Venezuela MOU signed April 2026 with the Ministry of Hydrocarbons and PDVSA covering relaunch of activities including the Junin-5 heavy oil field (Eni 40%) as part of recovering amounts owed to Eni on Perla gas supplies.

Dual exploration model (service/monetisation capability). Eni's practice of discovering, then selling down equity in, large finds before or during development is a distinct commercial product line in economic substance. Cumulative equity resources discovered since 2014 are approximately 11 billion boe. Organic reserve replacement was 167% in FY2025 with a target of more than 140% over 2026–2030.

Global Gas & LNG Portfolio and Power

Wholesale natural gas. FY2025 worldwide gas sales of 43.72 bcm (21.00 bcm Italy, 22.72 bcm outside Italy). 1H 2026 sales of 24.65 bcm, of which 13.29 bcm in Italy and 9.59 bcm in the rest of Europe. Customers are Italian and European utilities, industrials, hub counterparties and importers.

LNG. FY2025 LNG sales of 12.1 mmtonnes, up from 9.8 in FY2024. New long-term sale contracts totalling 1.2 MTPA signed in Thailand and Turkey during 2025. In May 2026 three long-term purchase agreements were signed covering approximately 2 MTPA from the Searah-operated South Hub and North Hub projects in Indonesia, supplied via the existing Bontang plant. Stated ambition is a contracted LNG portfolio exceeding 20 MTPA by 2030. In June 2026 Eni booked 2 bcm/year of regasification capacity at the Ravenna terminal for ten years.

Thermoelectric power (EniPower). 20.53 TWh produced in FY2025; 9.23 TWh in 1H 2026, down 7% on planned maintenance. Power sales in the open market of 27.57 TWh in FY2025.

Commodity trading (new). The July 2026 agreement with Mercuria establishes an equally owned, independently operated and unconsolidated global trading joint venture spanning oil, biofuels, gas, LNG and associated logistics and infrastructure rights, with international trading hubs.

Enilive (Transition Businesses)

HVOlution and HVO diesel. Produced via the proprietary Ecofining™ process, commercialised since 2014, converting waste, residues and renewable feedstocks into hydrotreated vegetable oil diesel. FY2025 biorefining capacity 1.65 mmtonnes/year, with sold biofuel production of 925 ktonnes and average biorefinery utilisation of 78%. At 30 June 2026, capacity of 2.1 MTPA net to Enilive with a further 1.5 MTPA under construction. Named validation events: MSC Cruises completed marine engine testing in May 2026 confirming performance parity with conventional marine fuels; BMW Group signed in July 2026 to power Italian corporate fleets with Enilive HVO diesel; BWT Alpine Formula One Team adopted HVOlution for European-round logistics vehicles from September 2026.

Sustainable aviation fuel (SAF). Optionality for more than 2 million tonnes of the 5 Mt 2030 biofuel capacity target to be SAF.

Bio-gasoline (development). A Feasibility Agreement with PETRONAS signed 7 September 2026 at the Italian Grand Prix to evaluate high-performance bio-gasoline from the Ecofining process, initially for motorsport and subsequently for commercial products.

Biorefineries. Venice/Porto Marghera (Italy, converted 2014, undergoing configuration enhancement with a planned 1H 2026 shutdown); Gela (Italy); Chalmette (United States); Livorno (Italy, under conversion); Sannazzaro (Italy, launched); Priolo (Italy, via a dedicated special purpose vehicle, to be complemented by a post-consumer plastics recycling plant using proprietary technology); Daesan/Seosan (South Korea); Pengerang (Malaysia, a JV with Petronas and Euglena designed for 650 ktonnes/year of renewable feedstock, construction begun).

Mobility retail. 5,294 service stations in Europe at FY2025 year end with 7.81 mmtonnes of retail petroleum product sales. In July 2026 Enilive Deutschland signed a binding agreement with Prax to acquire 100% of OIL! Tankstellen, adding approximately 320 service stations across Germany, Denmark, Austria and Switzerland, subject to regulatory approval. Retail sales reached 2.11 mmtonnes in 2Q 2026, up 7%.

Plenitude (Transition Businesses)

Renewable generation. 5.8 GW installed at FY2025 year end (up 41% year on year), 6.0 GW at 30 June 2026, targeting 6.5 GW at end-2026 and around 15 GW by 2030. Renewable output 5.6 TWh in FY2025 and 4.0 TWh in 1H 2026 (up 48%). Named assets include the Renopool photovoltaic complex in Spain (330 MW total, Plenitude's largest globally, second 200 MW plant started June 2026), Villarino PV (Spain, 220 MW, >400 GWh/year expected), and Kazakhstan's first large-scale hybrid plant (first industrial electricity from a 120 MW gas-fired unit in July 2026, to be integrated with solar and wind).

Retail energy supply. 10.0 million customer points at FY2025; 10.8 million at 30 June 2026 following the April 2026 completion of the acquisition of 100% of Acea Energia S.p.A. and 50% of Umbria Energy S.p.A. Retail and business power sales of 10.33 TWh in 1H 2026 (up 15%); gas sales of 2.92 bcm (down 5%). 2030 target of 15 million customers.

E-mobility. 22,800 charging points at FY2025, 23,200 at 30 June 2026. Network development at ALDI retail locations across Italy targeting more than 100 stores.

Corporate PPAs. Example disclosed June 2026: a 15-year power purchase agreement with automotive components manufacturer STAT, under which Plenitude builds an 890 kWp photovoltaic plant to supply its production facilities.

Refining, Chemicals and Sites in Transformation

Refining. FY2025 throughputs on own account of 24.94 mmtonnes at 80% average utilisation. 1H 2026 throughputs of 10.10 mmtonnes at 70% utilisation, with non-Italian throughputs down 35% year on year in 2Q owing to product unavailability connected to the closure of the Strait of Hormuz. Italian refineries include Sannazzaro, Taranto, Milazzo (joint venture) and Livorno (converting). The Standard Eni Refining Margin (SERM), Eni's proprietary benchmark, averaged $9.1/bbl in 1H 2026 against $4.3/bbl in 1H 2025.

Chemicals (Versalis). Polymers, elastomers, intermediates and styrenics. FY2025 production of 4,105 ktonnes at 49% average plant utilisation, down from 5,685 ktonnes in FY2024 following permanent closure of the Brindisi and Priolo crackers. 1H 2026 sales of 1.26 mmtonnes, down 17%. Versalis also holds proprietary chemical recycling technology now being deployed at Priolo. A partnership with Lummus Technology covers process technology commercialisation.

Sites in transformation. Restructuring, decommissioning and environmental remediation at closed hubs, reported as a distinct sub-segment from 2026 with a 1H 2026 proforma adjusted loss of €143 million.

Eni Industrial Evolution / battery manufacturing. A May 2026 agreement with FIB (Seri Industrial Group) for an integrated lithium-iron-phosphate (LFP) battery supply chain — cells, modules, stationary storage and e-mobility systems, and longer term recycling and cathode active materials. Eni Industrial Evolution took a 30% stake in a new FIB-controlled company. Construction of an LFP manufacturing facility began at the Brindisi hub in July 2026, primarily for stationary storage supporting renewable generation.

Eni Rewind and other services

Eni Rewind is the group's environmental remediation and circular-economy company, operating at 13 sites of national priority and more than 100 of regional priority in Italy, managing groundwater treatment plants, waste recovery and site revalorisation, and increasingly selling services to third parties. Its proprietary E-Hyrec® technology selectively removes hydrocarbons from groundwater. In June 2026 Eni and Hera inaugurated the Environmental Hub at Ravenna in the reclaimed Ca' Ponticelle area.

Eni CCUS Holding

A dedicated satellite company holding the Liverpool Bay and Bacton CCS projects (United Kingdom), the L10-CCS project (Netherlands), a right to acquire Eni's 50% Ravenna CCS interest in Italy, and an option to include further projects. GIP acquired 49.99% in December 2025. In May 2026 Eni CCUS Holding secured a financing facility of more than £500 million from a pool of 13 international lenders.

Technology and supercomputing

HPC7, launched June 2026, with capacity above 861 PFlops/s, ranked 6th in the TOP500 global list, second in Europe, and described by Eni as the world's most powerful high-performance computer for industrial use. It succeeds HPC6 and underpins seismic imaging, reservoir modelling, molecular simulation and fusion research. Clean Sea is Eni's proprietary underwater robotic system for marine ecosystem monitoring and offshore infrastructure inspection; a strategic agreement with Fincantieri signed June 2026 covers its development and dissemination, including CCS applications.

Pricing models are not disclosed for individual products; Eni does not publish list pricing, and revenue is realised at market-linked or contract-negotiated prices in all segments.

All figures in € million unless the row label states otherwise. FY2020–FY2022 figures are drawn from the Annual Report 2022 key figures; FY2023–FY2025 from the Annual Report 2025 key figures. Where a definition changed between reports it is noted below the relevant table.

Income statement

Zero entries in the proforma adjusted EBIT row indicate that the measure was not presented on that basis in the FY2021 and FY2022 annual reports; it is not a nil result. Eni introduced proforma adjusted EBIT to capture the growing contribution of equity-accounted satellites.

Margin analysis (%)

Gross profit and EBITDA are not presented as line items in Eni's IFRS income statement or in the key-figures tables; Eni's cost structure is reported as "purchases, services and other," payroll, and DD&A. A gross-margin series on Eni's own definitions is therefore not publicly disclosed. Third-party data services compute a trailing gross margin of approximately 20.6%, but this is a derived figure not sourced from Eni's filings and should not be treated as company-reported. Adjusted EBITDA is likewise not a headline Eni metric at group level, though it is disclosed for Enilive and Plenitude; Eni instead publishes a Net Debt/EBITDA adjusted ratio.

Revenue compound annual growth rate. Sales from operations grew from €76,575 million in FY2021 to €82,151 million in FY2025, a four-year CAGR of 1.8%. This flat trajectory conceals extreme intra-period volatility: the FY2022 peak of €132,512 million was 73% above FY2021 on the European gas price shock, and the subsequent three years represent a sustained normalisation, with FY2025 sales 38% below FY2022. Revenue is a poor proxy for Eni's economics; commodity price pass-through dominates it. The more informative series is proforma adjusted EBIT, which fell 31% from FY2023 to FY2025, and adjusted CFFO, which fell 24% over the same span.

Balance sheet

Debt composition at FY2025 year end and FY2024 comparison (€ million)

FY2025 cash includes €142 million held at held-for-sale subsidiaries at third-party banks, subsequently moved into group cash pooling in early 2026.

Interim balance sheet movement, FY2025 to 1H 2026 (€ million)

The €4.5 billion collapse in intangible assets and the €10.5 billion increase in assets held for sale between December 2025 and June 2026 are almost entirely the reclassification of Plenitude (€9.6 billion) as a discontinued operation, plus €2.2 billion of held-for-sale E&P properties. The €4.6 billion increase in equity-accounted investments reflects initial recognition of the Searah joint venture at a value exceeding the book value of contributed assets — the source of a €2,088 million net gain on business combination recorded in 2Q 2026 special items.

Goodwill is not separately broken out in the summarised balance sheet presentations reviewed; the intangible assets line (€6,022 million at FY2025, €1,532 million at 30 June 2026 post-reclassification) is the relevant aggregate.

Cash flow

Zero entries indicate the measure was not presented on a comparable basis in the source report for that year, not a nil value. Eni changed its headline cash-flow metric between the two reporting cycles, and the FY2022 capital expenditure figure includes reverse factoring operations, making it not strictly comparable to later years.

FY2025 free cash flow was €5.37 billion, funding €4.98 billion of dividends and buybacks and a €2.79 billion reduction in net borrowings before leases. For 1H 2026, net cash from operating activities was €5,697 million and adjusted cash flow before working capital at replacement cost was €7,347 million, with organic capex of €3,710 million and free cash flow of €873 million. The gap between the two operating-cash measures — €1,516 million of working capital absorption in 1H 2026 — reflects inventory build at rising commodity prices.

Buybacks: FY2025 repurchases totalled approximately €1.8 billion, raised 20% from the €1.5 billion announced at the Capital Markets Update. In 1H 2026, share repurchases of €0.9 billion were executed; by 17 July 2026 approximately 39 million shares had been bought for €860 million under the new programme; by 26 August 2026 treasury holdings had reached 4.84% of capital.

Ratios

The FY2025 gearing of 15% is the reported figure; on a proforma basis adjusting for agreed but uncompleted portfolio transactions, Eni reported 14%. Zero entries in the leverage row indicate the measure was not presented in that form in the source report for that year. Return on equity and return on assets are not among Eni's disclosed ratios; on reported FY2025 figures, net profit attributable of €2,608 million against average shareholders' equity implies a low single-digit ROE, but Eni does not publish this and it is not restated here as a company figure. Asset turnover and cash conversion cycle are likewise not publicly disclosed by Eni and are not estimated here.

Commentary on trends, inflections and drivers

The 2022 inflection and its unwinding. FY2022 was an outlier of a kind that distorts every trend line drawn through it. European gas prices at the Italian PSV averaged €1,294/kcm against €487 in FY2021, and adjusted operating profit more than doubled to €20,386 million. GGP alone delivered €2,063 million of adjusted operating profit. The subsequent three-year decline in group earnings is substantially a normalisation from that peak rather than deterioration in the underlying business — a point management has pressed repeatedly and which the operating data support.

The upstream volume-versus-price scissors. Between FY2022 and FY2025, production rose from 1,610 to 1,728 kboe/d, an increase of 7%, while E&P proforma adjusted EBIT fell from a peak to €11,163 million in FY2025. In FY2025 specifically, E&P earnings fell 14% despite 4% production growth, because crude prices declined 15% year on year in the fourth quarter and the euro appreciated 9% against the dollar. The 2026 reversal is equally instructive: 2Q 2026 E&P proforma adjusted EBIT of €4,769 million was 97% above the prior year on an 11% underlying volume increase and a 54% Brent increase, partially offset by a 3% adverse euro translation.

Reserve replacement is the genuine inflection. The organic reserve replacement ratio moved from 47% in FY2022 to 69% in FY2023, 124% in FY2024 and 167% in FY2025. Net proved reserves rose to 6,885 mmboe at FY2025 from 6,497 the year before, and the reserve life index extended to 10.9 years. Finding and development cost per boe fell from $26.3 (FY2023) to $17.0 (FY2025) on a three-year average basis. This is the single most important operational trend in the dossier: it is the basis for the 2026–2030 production growth guidance and for the argument that Eni's capital intensity can fall while volumes rise.

Chemicals as a structural drag. Refining and Chemicals delivered a combined proforma adjusted loss of €713 million in FY2024 and €689 million in FY2025. Versalis' losses narrowed to €65 million in 2Q 2026 from €184 million a year earlier following the Brindisi and Priolo closures, but management noted polyethylene spreads returned to unprofitable territory in July 2026. The improvement in 1H 2026 was partly a function of Middle East supply disruption tightening product markets — a temporary tailwind, not a structural repair.

Working capital and cost as an earnings lever. In FY2025 Eni delivered €4.0 billion of cash initiatives addressing working capital and €0.5 billion of cost reductions, and optimised capital expenditure to €8.5 billion against a €9.0 billion budget. Adjusted cash flow of €12.5 billion exceeded the plan target by €1.5 billion on a like-for-like scenario basis. This is self-help of a scale that materially changed the FY2025 outcome and is a genuine management achievement rather than a scenario effect.

Deteriorating interest coverage. Coverage fell from 17.5x in FY2023 to 8.7x in FY2024 and 6.1x in FY2025 — a threefold deterioration in two years, driven by lower earnings rather than higher debt (total finance debt actually fell from €30,348 million to €28,464 million). Net debt to adjusted EBITDA at 95.9% in FY2025 is above the 74.4% of FY2023. These ratios remain comfortable for an A3/A- credit but the direction of travel through 2025 was adverse; the 2026 earnings recovery should reverse it.

Impairments. 1H 2026 carried €1,474 million of net impairment losses, of which €1,203 million in E&P, driven by reprioritisation of capital away from later phases of marginal properties and by downward reserve revisions. This is a portfolio-quality signal worth watching: capital discipline that concentrates spending on core projects necessarily writes down the tail.

Management guidance

For FY2026, Eni guides to adjusted CFFO of €15 billion on a Brent assumption of $85/bbl, SERM of $14/bbl, TTF at €50/MWh and EUR/USD at 1.16 — representing an underlying improvement of €0.7 billion beyond what the group's own sensitivities would imply. Gross capex is confirmed at €7 billion with net capex guided below €5 billion, down from prior guidance. Underlying oil and gas production growth is now around 5% against the initial 3–4% range. GGP proforma adjusted EBIT is guided above €1.4 billion, a 40% increase on the initial level. Enilive proforma adjusted EBITDA is revised to €1.3 billion from €1.1 billion; Plenitude confirmed at €1.3 billion. Year-end installed renewable capacity is targeted at 6.5 GW with biorefinery capacity of 2.1 MTPA plus 1.5 MTPA under construction. Proforma gearing is guided to the lower end of the 10–15% range, with reported gearing expected to converge by year end. The 2026 buyback stands at €3.4 billion, with a dividend of €1.10 per share and an extraordinary dividend expected to be defined in October.

Over 2026–2030: CFFO of approximately €17 billion by 2030, a 14% per-share CAGR, cumulative CFFO of about €71 billion at $70/bbl, free cash flow above €40 billion (above €45 billion including portfolio effects) equating to roughly 70% of the market capitalisation at the time of the plan's presentation, group ROACE of approximately 13%, gearing held at 10–15%, and distributions of 35–45% of CFFO.

Consensus growth expectations

A formal consensus growth series was not retrieved. The observable directional evidence is that sell-side targets have been rising — Morgan Stanley to €23.80 in September 2026 — while ratings remain split between Buy (Barclays, J.P. Morgan, Jefferies) and Hold (RBC, Berenberg). Third-party data services project EPS growth of approximately 46% over the forward period; this is a vendor estimate, not company guidance.

Bull case

One: the exploration engine is compounding and it is being rewarded in capital intensity, not just volume. Organic reserve replacement of 167% in FY2025, F&D cost per boe down to $17.0 from $26.3 two years earlier, and 900 mmboe discovered in a single year. This combination — replacing more than you produce while the marginal barrel gets cheaper — is what allows the 2026–2030 plan to cut average annual investment by €2 billion while guiding to 3–4% annual production growth. If it holds, Eni delivers growth from a shrinking capital base, which is precisely the formula for the ROACE progression from 7.6% to 13%.

Two: the satellite model is a repeatable value-realisation machine, not a one-off. Eni has now monetised transition assets (Enilive, Plenitude, Eni CCUS), an upstream regional platform (Searah), an upstream infrastructure portfolio (Ares/PIMCO, $2 billion), and a trading franchise (Mercuria) — six distinct structures in roughly two years, implying more than €23 billion of enterprise value in the transition businesses alone. Each transaction imports third-party capital at a valuation above Eni's own multiple and reduces consolidated gearing. The Plenitude deconsolidation alone removes approximately 3.5 percentage points of gearing while retaining 65% economics.

Three: the balance sheet is now a weapon rather than a constraint. Proforma gearing of 10% at 30 June 2026 is the lowest in the company's history, achieved while raising the buyback to €3.4 billion and the dividend 5%. Moody's has already upgraded to A3. With €0.11 billion of CFFO sensitivity per dollar of Brent and a distribution policy that returns 60% of upside up to $90/bbl and 100% above it, shareholders capture the commodity cycle with an option-like payoff and a downside protected by 10% leverage.

Bear case

One: the 2026 numbers are a commodity accident and the market is capitalising them. Brent averaged $104.52 in 2Q 2026 against a $62 budget assumption because the Strait of Hormuz closed. The share price has risen roughly 62% from its September 2025 low. Strip the price effect and the underlying picture is a company with 7.6% ROACE, 6.1x interest coverage, a chemicals business losing money every quarter, and revenue that has grown at 1.8% annually over four years. A Hormuz reopening and Brent reverting to the $70s removes roughly €3 billion of annual CFFO and, mechanically, most of the incremental buyback.

Two: the reported earnings do not support the adjusted narrative. FY2025 adjusted net profit of €4,989 million versus reported net profit attributable of €2,608 million — a gap of €2.4 billion, repeated in FY2024. In 1H 2026, €1,474 million of impairments were taken, €1,203 million in E&P, driven by reprioritising capital away from marginal properties and by downward reserve revisions. The same portfolio that produced a 167% reserve replacement ratio is simultaneously producing reserve write-downs on its tail. Meanwhile Plenitude's earnings in 1H 2026 flatter the group because depreciation stopped accruing in March pending deconsolidation. Investors are being asked to track a great deal of accounting motion.

Three: state control caps the strategic and valuation ceiling. The Ministry of Economy and Finance and CDP hold 33.09%, appointed six of nine directors on a slate that carried 51.38% of participating shareholders, and installed a Chair whose appointment required a public prime-ministerial intervention over her prior employer's severance. Shareholders approved a 23% CEO pay increase over an explicit ISS objection. Eni will always be, in part, an instrument of Italian energy policy. That constrains the multiple it can command relative to Shell or TotalEnergies regardless of operational delivery, and it means the 2029 succession will be a political decision rather than a board one.

Catalysts and monitorables for the next twelve months

Analyst verdict

Eni enters the second half of 2026 in the strongest financial condition of its corporate life, and the temptation is to attribute that to a windfall. That would be half wrong. The windfall is real — Brent at $104.52 in the second quarter against a $62 budget, refining margins at double the assumed level, both consequences of a Middle East crisis that closed the Strait of Hormuz — and it explains why the shares have risen roughly 62% from their September 2025 low and why the buyback has more than doubled from €1.5 billion to €3.4 billion. But the balance sheet that permits that distribution was rebuilt in 2025, a bad year, through €4 billion of cash initiatives, €0.5 billion of cost reductions, capex held €0.5 billion below budget, and €1.73 billion of portfolio proceeds in the fourth quarter alone. Gearing fell to 14% proforma before the oil price did anything helpful. That was management, not markets.

The genuine investment question is whether the exploration engine can carry the ROACE from 7.6% to the 13% the plan promises by 2030. The supporting evidence is strong: 167% organic reserve replacement, finding and development cost down 35% in two years, 11 billion boe discovered since 2014, and an execution cadence — six start-ups in 2025, Searah stood up in seven months, three FIDs in a single quarter — that few peers match. The contrary evidence sits in the same filings: €1.2 billion of E&P impairments in the first half of 2026 as capital was reprioritised away from marginal properties, a persistent €2.4 billion annual gap between adjusted and reported profit, and a chemicals business that is being closed rather than fixed.

The satellite model deserves more credit than it typically receives. It is not financial engineering for its own sake; it is a rational response to a genuine problem, which is that Eni's cost of equity is too high to fund renewables at renewable returns. Selling 20% of Plenitude to Ares at an implied €12 billion enterprise value, then deconsolidating at €13.1 billion, funds 15 GW of capacity with someone else's balance sheet while retaining 65% of the economics. Applied six times in two years, across transition, upstream, CCS and trading, it has become the defining feature of how Eni is run.

The ceiling is political. A 33.09% state holding, six of nine board seats from a government slate, a prime-ministerial intervention in the Chair's appointment, and a pay increase approved over ISS objection are not scandals — they are the operating conditions. They will keep Eni trading at a discount to Shell and TotalEnergies whatever the delivery, and they make the eventual succession to a 71-year-old CEO in his fifth term a political rather than a governance event. On current disclosure, the shares reflect a company executing well into a favourable cycle, with the cycle doing more of the work than the multiple implies.

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