- Tullow’s Operational Revival Confronts Stubborn US$1.4bn Debt Challenge
Tullow Oil delivered a sharp improvement in production, revenue and operating cash flow during the first half of 2026, but heavy refinancing costs and an elevated tax charge pushed the Ghana-focused producer deeper into loss and underscored the continuing fragility of its balance-sheet recovery.
Group working-interest production increased by nearly 8% to 43,700 barrels of oil equivalent a day during the six months to June, from 40,600 barrels a day in the corresponding period of 2025.
Revenue rose approximately 21% to US$496m, supported by higher production and a realised oil price before hedging of US$95 a barrel, compared with US$71.40 a year earlier.
Gross profit climbed 67% to US$276m, while underlying operating cash flow increased to US$222m from US$34m.
Yet Tullow reported a loss after tax of US$101m, widening from US$80m in the first half of 2025. Net financing costs rose to US$230m from US$139m as the company absorbed the cost of extending maturities on a debt structure that had become increasingly difficult to refinance.
The results present two contrasting versions of Tullow.
Operationally, the company is performing more strongly than it has for several years. Financially, much of the value created by higher production and stronger oil prices continues to be absorbed by debt, financing costs, taxation and capital expenditure.
Ian Perks, Tullow’s chief executive, said the company had delivered “outstanding operational performance” and expected full-year production to finish at the upper end of its guidance.
“With realised oil prices before hedging of US$95 a barrel, we have significantly upgraded free cash flow expectations,” he said.
Tullow expects 2026 production to be at the upper end of its guidance range of 34,000 to 42,000 barrels of oil equivalent a day.
The apparent contradiction between first-half production of 43,700 barrels a day and full-year guidance capped at 42,000 reflects the likelihood of lower average production during the second half, including the natural decline of wells and the timing of new-well contributions.
Tullow’s improved performance was overwhelmingly driven by Ghana.
Combined net oil production from the Jubilee and TEN fields averaged 35,700 barrels a day during the first half. Jubilee produced 70,800 barrels a day on a gross basis, of which Tullow’s working-interest share was 27,600 barrels.
TEN produced a gross average of 14,800 barrels a day, with 8,100 barrels attributable to Tullow.
The Jubilee floating production, storage and offloading vessel achieved uptime of more than 99%, following reliability work undertaken during the field’s scheduled shutdown in 2025.
Six new Jubilee production wells were brought onstream under the 2025-2026 drilling programme. The final water-injection well was completed in September.
Production was also supported by dual-riser operations, riser-based gas lift and optimisation of existing wells. Several older wells declined more slowly than the company had expected.
The performance is significant because Tullow’s financial restructuring ultimately depends on the continued reliability of a relatively concentrated asset base. Following disposals in Gabon and Kenya and its exit from Côte d’Ivoire’s Espoir field, Ghana has become the company’s defining operational and financial centre.
This concentration creates efficiency, but it also increases exposure to technical disruptions, reservoir performance and relations with the Ghanaian state.
Tullow benefited substantially from the stronger oil-price environment, but its hedge book limited some of the upside.
Its realised oil price before hedging increased to US$95 a barrel. After hedging, the price fell to US$86.30.
Hedge settlements reduced first-half revenue by US$47m, compared with a US$10m reduction a year earlier.
The hedge portfolio performs an important balance-sheet function. It protects cash flow when oil prices fall and supports the company’s ability to fund drilling and meet debt obligations. But during periods of elevated prices, the same protection transfers part of the upside to hedge counterparties.
At June 30, Tullow had downside protection over about 60% of production implied by the midpoint of its second-half guidance, with a weighted average floor of approximately US$58 a barrel. About 30% of forecast production entitlements was capped at a weighted average ceiling of about US$76.
The difference between Tullow’s pre-hedging and post-hedging prices illustrates the trade-off. The company has sacrificed some exposure to high oil prices in exchange for protection against the price collapse that its leveraged balance sheet would struggle to absorb.
Tullow generated free cash flow of US$4m during the first half, compared with a US$188m outflow a year earlier.
The US$192m improvement was substantial, reflecting stronger operating cash flow, lower operating costs, proceeds from the Kenya disposal and reduced cash financing costs.
But the final figure remained modest relative to revenue and oil-price conditions.
Free cash flow was calculated after US$64m of cash interest payments and US$70m of one-off refinancing transaction costs. Capital expenditure increased to US$134m from US$103m.
The first-half number therefore understates the cash-generation potential of the operating business after the exceptional refinancing costs. But it also demonstrates how little room Tullow possessed before restructuring its debt.
The company has raised its full-year free cash flow forecast to between US$170m and US$250m under oil-price scenarios ranging from US$70 to US$100 a barrel.
That guidance implies a much stronger second half, supported by eight planned cargoes, higher production and the completion of historic gas-receivable payments by Ghana.
Tullow expects to lift 14 cargoes during 2026, 11 from Jubilee and three from TEN. Six were delivered during the first half, leaving eight planned for the remainder of the year.
Tullow completed a major refinancing in April to address the maturity of US$1.285bn of senior secured notes due in May 2026.
The company repaid US$100m of the existing notes and issued US$1.185bn of new senior secured notes due in 2028. It also issued US$423m of junior secured notes to Glencore, maturing in 2030, and established a US$100m cargo-prepayment facility.
The refinancing removed an immediate maturity threat but came at a considerable price.
Tullow incurred US$62mn of debt-arrangement fees that were expensed through the income statement and recognised a further US$24mn loss on the extinguishment of borrowings. Total one-off cash refinancing costs were US$70m.
Credit-rating agencies treated the transaction as a distressed exchange. S&P lowered Tullow to default when the transaction was completed before upgrading it to CCC+ with a stable outlook. Fitch also assigned a CCC+ rating, while Moody’s placed the company at Caa3.
These ratings indicate that refinancing risk has not disappeared. It has been postponed and restructured.
Net debt stood at US$1.398bn at June 30, down from US$1.640bn a year earlier but up from US$1.353bn at the end of December 2025.
The year-on-year decline shows progress. The increase during the first six months of 2026, however, demonstrates the impact of refinancing costs and declining cash balances.
Cash gearing improved to 1.9 times net debt to EBITDAX from 2.1 times a year earlier, while liquidity headroom increased to more than US$250mn.
The new 2028 notes carry an additional strategic condition. Unless Tullow enters a legally binding asset sale agreement by September 30, 2027, their maturity and that of the cargo-prepayment facility will be brought forward to May 15, 2028.
That provision suggests the company’s creditors expect asset monetisation, refinancing or another material balance-sheet intervention before maturity.
Tullow reported that 2P reserves increased from 100.2m barrels of oil equivalent at the end of 2025 to 121.7m barrels at June 2026, producing a reserves-replacement ratio of about 380%.
The increase strengthens the commercial case for continued investment in the portfolio. But it should not be interpreted as the discovery of 21.5m barrels of entirely new oil during the half year.
The additions largely reflected the extension of Ghanaian petroleum agreements to 2040, approval of development-drilling commitments, maturation of the Teak gas project and positive revisions to well performance.
Licence tenure and project approvals can convert previously contingent or inaccessible resources into booked reserves. This creates genuine economic value, but it is distinct from exploration success.
Mr Perks said the company was building on the momentum of its latest drilling campaign and saw the potential for further reserve growth before the end of 2026.
“We are increasingly confident in our ability to unlock the full value of our assets and deliver material cash flow,” he said.
Tullow’s first-half results demonstrate that its operating recovery has become credible.
Production exceeded expectations, FPSO reliability improved, Ghanaian operating costs fell and historic gas receivables were recovered. The extension of the Jubilee and TEN petroleum agreements to 2040 also provides greater visibility for future investment.
But the financial recovery is less complete.
Tullow remains heavily leveraged, retains speculative-grade credit ratings and depends on a narrow asset base. Its free cash flow is highly sensitive to production, oil prices, hedging and the timing of cargo liftings.
Management’s going-concern assessment assumes average oil prices of US$73 a barrel in 2026 and US$71 in 2027 under its base case. Its severe but plausible low case assumes US$68 and US$66 respectively, alongside a 10% production decline and a 5% increase in operating costs.
The company says it retains sufficient headroom under both scenarios.
The more immediate question is not whether Tullow can continue operating. It is whether the company can convert operational gains into debt reduction quickly enough to approach 2028 from a position of strength.
The first half of 2026 provided evidence that Jubilee and TEN can generate the production and cash flow required.
It also showed how much of that cash flow is already spoken for.
