Q1 showed that the North Sea could carry DNO while Kurdistan was constrained.
Q2 went one step further.
DNO generated USD 760.5 million of revenue, USD 525.7 million of EBITDA and USD 289.5 million of free cash flow while recording no sales revenue from Kurdistan. Net debt fell from USD 790 million to USD 552.9 million.
That is probably the cleanest demonstration yet of what the Sval acquisition changed.
Three years ago, losing Kurdistan for an entire quarter would have defined DNO’s results. This time, the North Sea not only absorbed the shock – it delivered record second-quarter revenue and allowed DNO to materially reduce debt at the same time.
MD Chris Spencer summed it up:
“We have actually paid down $220 million of debt in a quarter with zero production from Kurdistan. Who would have thought that three years ago for DNO?”
There were still weak spots. Costs were somewhat elevated, the original 100,000 bpd year-end ambition for Tawke and Peshkabir has effectively been pushed out, and the next quarters will carry significantly higher North Sea tax payments.
But the direction remains constructive.
North Sea guidance is up, two new tiebacks came onstream ahead of schedule, Kurdistan production has restarted, and DNO enters H2 with more producing barrels and more projects progressing towards first oil.
Headline numbers: record revenue, strong cash conversion
North Sea: guidance raised as the portfolio keeps delivering
The NCS growth machine: another turn of the wheel
Kurdistan: restarted, but the 100,000 bpd target slips
Pricing and exports: certainty still has a value
Genel: the process now matters for capital allocation
Cash flow, balance sheet and dividends
What the Q&A told us
Analyst comments
Final thoughts
The headline figures were strong.
Revenue increased 21% quarter-on-quarter to USD 760.5 million. EBITDA rose to USD 525.7 million from USD 430.2 million, operating profit reached USD 439.0 million and net profit increased to USD 83.4 million. Free cash flow almost doubled to USD 289.5 million.
The striking part is where the revenue came from.
All USD 760.5 million was generated in the North Sea. Kurdistan contributed zero revenue after production remained suspended for almost the entire quarter.
Commodity prices helped considerably. DNO realised USD 115.1/boe for North Sea oil, USD 89.5/boe for gas and USD 100.7/boe across the North Sea portfolio, up from USD 81.7/boe in Q1.
DNO’s limited hedging meant most of that upside flowed through.
Chairman Bijan put it more colourfully in the Q&A:
“The North Sea operations were hitting on all 12 cylinders… So the North Sea carried the quarter for us.”
There was some cost noise.
North Sea lifting costs increased from USD 11.9/boe to USD 12.5/boe, mainly because of lower production and somewhat higher costs across several fields. Kurdistan still incurred costs while almost no barrels were produced, including front-loaded workover activity. Exploration expenses also jumped to USD 43.4 million, partly because Heisenberg was expensed.
That makes the quarter somewhat less spectacular beneath the revenue headline.
But it does not change the larger point.
DNO produced strong cash flow while one of its two main operating regions was effectively absent.
North Sea production averaged 84,912 boepd, down from 88,647 boepd in Q1.
The decline needs context.
Q1 benefited from Nova allocation and redelivery volumes, while Q2 included substantial seasonal maintenance and unplanned downtime at Norne and Tambar East. Despite that, production remained stronger than DNO had expected.
Two developments also came onstream ahead of schedule.
Symra, where DNO holds 20%, is expected to contribute around 5,000 boepd net at plateau. Dvalin North, with a 10% interest, adds another roughly 3,000 boepd.
With most seasonal maintenance now behind it, DNO raised full-year North Sea production guidance from 82,000 to 85,000 boepd.
DNO is simultaneously bringing on new tiebacks, sanctioning additional projects and reshaping its hub exposure.
Management would not give formal 2027 guidance in the Q&A, but Spencer reiterated the longer-term target:
“We’re standing by our ambition for 100,000 BOE/D by 2030. I personally am confident that we will achieve that target.”
After another guidance increase, that ambition looks increasingly credible.
In the Q1 summary, we described DNO’s North Sea model as a loop: acquire or discover resources, concentrate around hubs, accelerate sanction, tie them back and turn them into production and cash flow.
Q2 provided another turn of that wheel.
The company agreed a multi-asset transaction with Vår Energi that will give it a 5% interest in the Gjøa hub and Gjøa Nord discovery, while reducing its Nova interest from 45% to 40%, transferring Ringhorne Nord and receiving USD 17.5 million post-tax in cash.
Owning part of the host infrastructure matters because DNO increasingly has satellites feeding into Gjøa.
During Q2, the partnerships approved the Ofelia, Cerisa and Gjøa Nord tiebacks. DNO also completed the acquisition that increased its Vega interest to 8.8%.
Spencer made the strategic logic explicit:
“This is… very much the model.”
The Q&A added another useful detail.
Three additional subsea projects – Cerisa, Ofelia and Gjøa Nord – were sanctioned during Q2, while Kjøttkake remains the one additional FID expected before year-end.
There is exploration depth too. The Carmen appraisal leaves gross recoverable resources estimated at 21–107 MMboe, alongside the Atlantis and Afrodite positions acquired in the Equinor swap.
The NCS story is therefore becoming more diversified across multiple fields.
It is a portfolio of producing hubs, short-cycle satellites and discovered resources being pushed towards cash flow.
That is exactly what DNO needs if it wants to sustain – rather than merely reach – 100,000 boepd.
Kurdistan was almost absent from the Q2 numbers.
Net production averaged just 273 boepd, compared with 39,600 boepd in Q1. Tawke restarted on 28 June and Peshkabir followed on 11 July.
The important development is therefore what happened after quarter-end.
DNO is again producing, drilling and carrying out workovers. A second third-party rig is being mobilised, while management expects Tawke licence production to stabilise around pre-shutdown levels if security conditions allow.
But the tone has changed from Q1.
Back then, DNO was preparing for stepped-up production and still had its eight-well campaign pointing towards 100,000 bpd gross by year-end.
That is no longer a realistic base case.
Asked directly about the target, Bijan explained that the shutdown had delayed drilling, created additional workover requirements and left the programme behind schedule:
“I think you should assume… that our goals will not be met.”
That is a negative versus the position three months ago.
It is also mainly a timing issue rather than a change in DNO’s view of the resource.
The company is still investing. Management said it has its own rig working on shallow wells and workovers, another larger rig drilling at Peshkabir, a second large rig engaged and is looking for another.
The problem is security.
Management said it has recently been close to shutting down again and reviews conditions continuously. Bijan’s description probably captures the situation best:
“We have one foot on the accelerator… and one foot always on the brake.”
For now, investors should think pre-shutdown production first, further growth later.
The commercial picture has improved somewhat.
DNO is currently selling its Kurdistan entitlement oil at prices in the mid-to-upper USD 30s per barrel, compared with around USD 31 before the shutdown.
That is better.
It is still nowhere near international pricing.
And that distinction remains central to the investment case.
In our recent Genel analysis, the biggest swing in acquisition economics came not from modest changes in production, but from how Tawke barrels are monetised. At discounted domestic pricing, the incremental cash return is relatively modest. At international pricing with full PSC entitlement, the economics change dramatically.
Q2 did not change that conclusion.
DNO continues to pursue export access, but management remains unwilling to trade payment certainty for a headline price unless the payment mechanism is credible.
Current local sales are effectively prepaid.
Spencer said:
“We’ve been insisting on being paid internationally before we deliver the oil. So at least we have complete payment surety for our oil.”
That explains why DNO has not simply followed other producers into the available export structure.
Higher pricing is attractive.
A new receivables problem is not.
Bijan reiterated that access to Ceyhan remains the aspiration, but gave no timetable. In the meantime, prepaid domestic sales allow DNO to recover costs quickly and reinvest without relying on future government payments.
This is where the North Sea changes the bargaining position.
DNO no longer needs Kurdistan cash badly enough to accept unattractive terms.
It can afford to wait.
There was necessarily little new information on Genel during the call.
Takeover rules prevented management from taking questions on the process.
The official position remains that DNO approached Genel with a non-binding proposal of 69p per share, Genel’s board rejected it, and DNO has until 4 September to announce a firm intention to bid or walk away, unless the deadline is extended.
The Q2 numbers nevertheless add something important.
Funding capacity is not the main issue.
DNO ended June with roughly USD 550 million of cash, USD 553 million of net debt and generated USD 290 million of free cash flow during the quarter.
The real question is price and what DNO ultimately buys.
As discussed in the recent watchlist updates, standalone Genel offers a particularly clean strategic fit because DNO already operates Tawke. Capricorn potentially adds a third material production region in Egypt and additional cash flow, but also introduces debt, development commitments and collection risk.
Q2 does not alter that assessment.
It does strengthen DNO’s hand.
The company can afford to be patient and price-disciplined.
This may be the most interesting part for many shareholders and NHG readers.
DNO generated USD 289.5 million of free cash flow in Q2 and USD 435.3 million in the first half. Net debt fell by USD 237 million during the quarter to USD 552.9 million.
Yet the quarterly dividend stayed at NOK 0.375 per share.
We think the unchanged dividend says more about timing than capacity.
DNO has now demonstrated that the North Sea can fund investment, service the balance sheet and support distributions even with almost no Kurdistan contribution. The current payout already looks conservative relative to the cash generation of the enlarged company.
There are caveats.
Q2 benefited from working capital, and CFO Birgitte Wendelbo Johansen cautioned that North Sea tax instalments will rise materially in the second half, with around USD 320 million expected in H2.
Capex is also running at a meaningful level: USD 202.4 million in Q2, of which USD 188.8 million was spent in the North Sea.
Still, our view is that DNO should already be in a position to raise the dividend.
It did so after Q2 in both 2024 and 2025, including while absorbing the much larger Sval transaction.
The difference this time is that there is an active Genel process.
A higher dividend immediately before potentially committing several hundred million dollars to another acquisition would reduce flexibility for little strategic benefit.
Without the Genel process, we would have expected at least a modest increase now. With it, the next step has probably been delayed by at least one quarter.
That is our interpretation – not guidance from DNO.
If the process ends without a transaction, the case for a higher payout becomes harder to ignore.
If DNO acquires Genel, the timing will depend on the final price, the Capricorn outcome and how aggressively management wants to refinance or deleverage afterwards.
The Q&A sharpened several parts of the investment case.
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