Eni’s Higher Payout Combines Stronger Operations With a Restructured Approach to Funding Growth

Eni’s 23 October results turn a stronger energy market and higher production into additional shareholder distributions. The group declared a €1.3 billion extraordinary dividend and raised its 2026 buyback program to €3.8 billion from €3.4 billion. Its annual adjusted operating cash-flow forecast rose 10%, to €16.5 billion from July’s €15 billion.

Higher output and improved refining profits support the decision. Eni has also brought outside capital into its businesses and moved Plenitude, its renewable-power and retail-energy operation, to joint control. These arrangements preserve funding capacity for expansion while returning more cash to shareholders. Their economic cost is sharing future earnings and cash flows, so the lower net-debt figure needs to be assessed alongside the interests Eni retains and the cash those investments can distribute.

Production and refining support the cash-flow upgrade

Eni (Euronext Milan: ENI) earns money from producing oil and gas, supplying and trading gas, refining fuels and operating energy-transition businesses. Its upstream operations remain the principal earnings source; Enilive makes and markets fuels, including biofuels, while Plenitude combines renewable electricity and retail energy services. Reconciled third-quarter figures show upstream pro forma adjusted operating profit of €4.63 billion, up 76% from €2.64 billion in the third quarter of 2025. Upstream contributed approximately 77% of the €5.99 billion group total, by AER’s calculation.

The pro forma measure combines adjusted operating profit from subsidiaries with Eni’s share of operating profit from major joint ventures and associates. It excludes inventory effects and specified special items, and includes investment earnings that sit outside consolidated operating profit. This provides a broader view of the operating portfolio, although earnings from a partly owned business reach Eni as cash only when distributed.

Third-quarter hydrocarbon production reached 1.83 million barrels of oil equivalent per day, up approximately 4% from the third quarter of 2025. After adjusting for portfolio transactions and price effects, underlying production grew 7% year over year. Project ramp-ups and the first full quarter of its Searah venture in Southeast Asia supported volumes. The pricing environment also helped: Brent averaged $97 a barrel in the third quarter of 2026, compared with $69.07 in the third quarter of 2025. Higher production therefore explains only part of the earnings improvement. Management’s prepared remarks show that gas marketing and refining contributed as crude prices eased from the second quarter.

Refining generated €727 million of pro forma adjusted operating profit, compared with €135 million a year earlier. Improved plant availability allowed Eni to capture wider margins between refined-product prices and crude costs. Those conditions strengthen current cash generation, but part of the increase depends on favorable market spreads continuing. The new production adds physical output to the earnings base; the margin uplift remains exposed to changes in product supply and demand.

Cash generation supports the payout alongside portfolio funding

The full financial release reports third-quarter net cash from operating activities of €4.36 billion, up from €3.08 billion a year earlier. Eni’s free-cash-flow measure, after capital spending, acquisitions and other investing items, rose to €2.78 billion from €2.01 billion. That provided room for €1.90 billion of dividends and share repurchases, before lease repayments and other financing movements.

The year-to-date comparison is less strong. Nine-month free cash flow was €3.65 billion, broadly unchanged from €3.70 billion in 2025, as improved operating cash and lower capital expenditure were offset by lower net disposal inflows and higher acquisition spending. Dividends to Eni shareholders and repurchases totaled €4.30 billion, exceeding that cash-flow measure by approximately €640 million before lease repayments and hybrid-bond interest. Portfolio funding and financing therefore remain relevant to the overall capital-allocation plan.

Actual nine-month operating cash flow was €10.06 billion, compared with €11.63 billion on the adjusted, pre-working-capital measure used in guidance. Working capital absorbed €1.34 billion; inventory, derivative and other adjustments explain the remainder of the difference. The annual cash-flow forecast must still be translated into cash after investment and financing obligations before assessing the room for additional returns.

Plenitude gains capital while Eni shares control and future economics

Plenitude combines renewable generation, electricity and gas supply to customers, and electric-vehicle charging. Its ownership reorganization involved €1.56 billion of new equity: €1.08 billion subscribed by Ares-managed funds and €480 million by Eni. The money goes into Plenitude to support its business. Eni’s ownership falls from approximately 70% to 65.03%, alongside Ares at 26.24% and Energy Infrastructure Partners at 8.73%.

Despite retaining a majority stake and appointing five of nine directors, Eni now shares control with Ares. Certain decisions, including budgets and business plans, require support from an Ares-appointed director. This governance change is what permits deconsolidation: Plenitude’s assets and liabilities leave Eni’s consolidated balance sheet, and Eni instead records its investment using the equity method.

The results presentation explains how reporting changes from the fourth quarter. Eni will recognize its share of Plenitude’s profit through equity accounting, while reported operating cash flow will include dividends received from the investment. Cash retained by Plenitude for renewable capacity and other spending will remain inside that business. The funding benefit comes from outside capital supporting those investments; deconsolidation itself does not generate cash.

This structure can reduce demands on Eni’s balance sheet by giving Plenitude access to outside equity and its own financing. The economic exchange is a lower ownership percentage and shared decision-making. Its benefit depends on Plenitude earning attractive returns on that additional capital, while financing its growth without repeatedly requiring new contributions from Eni.

Lower net debt includes portfolio and financing effects

Net borrowings excluding leases fell from €9.53 billion at December 2025 to €6.70 billion at September. Management attributes approximately €2.75 billion of benefit to Plenitude’s deconsolidation. Eni also received about €1.75 billion from investors acquiring participation in future dividends from upstream infrastructure, exchanging part of a future cash stream for present funding. A roughly €990 million hybrid-bond issuance supplied additional capital classified as equity.

Within the changed accounting perimeter, Eni’s net-debt calculation offsets approximately €1.7 billion owed by Plenitude against gross financial debt. Those former intercompany loans become external financing receivables after deconsolidation; they remain subject to repayment and credit risk. Lower net borrowings thus reflect cash, financing assets and changes in the consolidation perimeter, alongside operating performance.

Reported gearing excluding leases was 10%, against Eni’s 10%–15% guided range. The 9% pro forma figure additionally allows for pending portfolio transactions, principally Indonesian asset sales. Gearing measures net borrowings as a share of net capital employed, using Eni’s definition excluding leases and related right-of-use assets. The lower ratio increases financial headroom, but continuing loan exposure and the future distributions relinquished to outside investors remain part of the economic cost of obtaining it.

The updated outlook links further returns to production and market margins

The latest guidance comparison raises production and cash-flow expectations while keeping gross capital expenditure unchanged. Within the transition businesses, stronger biofuel margins support a higher outlook for Enilive, while Plenitude’s forecast has weakened.

Plenitude’s third-quarter EBITDA fell 8% to €204 million from €221 million in the third quarter of 2025, as retail competition and conditions in some renewable markets offset generation growth. Its pro forma adjusted operating profit nevertheless rose 95% to €191 million from €98 million over the same period, helped by suspended depreciation associated with deconsolidation. That accounting benefit does not represent additional cash generation. Its contribution to Eni’s funding capacity will depend on operating cash generation, investment requirements and dividends remitted to Eni.

AER calculates that €16.5 billion of annual adjusted cash flow, less the €11.634 billion reported for nine months, requires approximately €4.87 billion in the fourth quarter. Plenitude’s move to dividend-based cash reporting makes remittances from investments relevant to that outcome. The cash-flow upgrade includes higher market assumptions: full-year Brent rises from $85 to $95 a barrel, European TTF gas from €50 to €55 per megawatt-hour, and Eni’s refining-margin benchmark from $14 to $18 a barrel. These are management’s planning assumptions, not current spot quotations. Production growth, market margins and dividends received from investments all influence delivery.

The €0.46-per-share special dividend is payable on 9 December for ordinary shares, in addition to the unchanged €1.10 ordinary-dividend plan. Purchases under the 2026 buyback program can continue through April 2027. The results support the higher payout through stronger operations and funding arrangements that reduce the capital Eni must supply alone. Sustaining production growth while converting earnings into cash would strengthen the capacity for further distributions. If refining margins normalize or Plenitude retains more cash for expansion, that capacity would narrow.