Capricorn Energy Reports Strong H1 2025 Results with Egypt Concession Breakthrough

Capricorn Energy H1 2025: solid delivery and a potential Egypt game‑changer

Capricorn Energy’s half-year update blends steady operations with a potentially transformative regulatory milestone in Egypt. Production is tracking slightly above the mid-point of guidance, costs are tight, and the company is inching closer to improved contract terms that could extend asset life to potentially 2045 and lift reserves. The flip side: receivables in Egypt remain chunky, revenue is lower year-on-year, and group profits were negative in H1 as corporate costs and depletion weighed.

Key numbers at a glance

Quick jargon check: boepd is barrels of oil equivalent per day. WI is Capricorn’s share of production before host government take. ARG refers to the Abu Roash G formation. 2P reserves are proven plus probable.

Egypt concession consolidation: why this matters now

The big strategic news is EGPC’s approval to consolidate eight of Capricorn’s 50% owned concessions into a single, integrated concession with improved commercial terms, a refreshed primary term and potential contract life to 2045. Parliamentary ratification is expected later in 2025. In exchange, Capricorn will make a modernisation payment in instalments (amount not disclosed).

Why this is important:

• Better economics – improved cost recovery and profit share should raise project returns and support higher investment levels.
• More running room – a larger, continuous footprint enables economic field extensions and new developments that were constrained by legacy licence boundaries and expiries.
• Reserves uplift – independent auditor GLJ’s preliminary work aligns with management’s expectation of converting up to approximately 20 mmboe (working interest) of resources to 2P reserves in the current year on ratification. That is material versus the existing base.

In plain English: if Parliament signs this off, Capricorn’s Egypt assets become more valuable and more drillable under one modern contract, which should support production growth and extend field life.

Production, wells and what’s planned for H2

H1 WI production averaged 20,342 boepd, 43% liquids, slightly above the mid-point of 2025 guidance (17,000-21,000 boepd). Year-to-date to 31 August, production averaged 19,994 boepd with 42% liquids – reaffirming guidance.

Operations prioritised meeting exploration commitments (postponed from 2024), with three exploration wells drilled across NUMB, WEF and SEH. Hydrocarbons were encountered in all three; two are being tested for commerciality with results due in September. The WEF well will not be tested due to sub-commercial volumes.

Development activity steps up now. A fourth rig came in April and the fleet is now focused on development in the Badr El Din (BED) area, targeting liquids. Seven development wells were drilled in H1; 15 more are forecast for H2 to hit the 22-well 2025 plan. Operating costs remain lean at $5.1/boe on a WI basis.

Revenue and earnings: lower top line, Egypt profitable, group loss

Revenue came in at $59.7m (oil $44.3m at $73.6/bbl; gas $15.1m at $3/mscf). Lower revenue year-on-year reflected reduced entitlement volumes and prices. Cost of sales were $18.4m, and depletion – the accounting charge for producing reserves – was $37.8m.

Segmentally, Egypt generated a $9m profit, but group continuing operations posted a $6.5m loss due to $12.6m of administrative expenses, $1.7m expected credit loss on revenue receivable, and net finance costs. There were no discontinued gains in H1 (vs a $23.2m gain in 2024 related to historic UK asset disposals).

Cash flow, debt and those receivables

Cash is stable and debt is coming down. Group cash at 30 June was $96m, including $11.9m of restricted cash. Borrowings in Egypt were $63.3m after $36.5m of repayments in the half. Net cash after debt was $32m, helped by a $50m Senegal contingent consideration receipt.

Egypt operating cash inflow was $35m. The Achilles’ heel remains receivables: $172m at 30 June after an expected credit loss adjustment. Collections are improving though: $61m was received in H1, and post-period collections of $37m reduced total receivables to $160m by 31 August. EGPC’s guidance points to at least $90m of payments in H2 2025, including a $50m bullet in October under the plan.

It is worth noting Capricorn has waivers in place for events of default on its Egypt facilities. Lenders have been rolling these forward in line with the repayment schedule. The facilities are non-recourse beyond the Egypt subsidiary, which limits risk to the wider group if something went seriously wrong in-country, but investors should still track the waiver status and collections closely.

Capex, guidance and M&A appetite

Full year net capital expenditure is now forecast at $75-85m, slightly trimmed due to scheduling and savings. Operating costs are guided within $5-7/boe. FY25 production guidance of 17,000-21,000 boepd is reiterated.

Beyond Egypt, the team continues to evaluate M&A in the UK North Sea and MENA, with an emphasis on cash flow accretion and strategic fit. Nothing is announced yet.

Legal and commercial odds and ends

• UK North Sea contingent payment: Capricorn is pursuing recovery of a defaulted $29.5m owed by Waldorf Production UK Plc after a High Court decision refused Waldorf’s restructuring plan. Given Waldorf’s financial position, management does not expect to recover the full amount.
• Senegal tax assessment: the company continues to dispute two assessments linked to the sale of Sangomar to Woodside Energy. No provision has been booked. Proceedings include action in the High Court of Dakar and a request for arbitration.

The bull case vs the bear case

Why the update is encouraging

• Operational discipline: production is bang in line with guidance, costs are low at $5.1/boe, and the development programme is weighted to liquids.
• Regulatory catalyst: parliamentary ratification of the integrated concession could unlock up to approximately 20 mmboe of 2P reserves and extend asset life – a meaningful value driver.
• Cash discipline: $36.5m of debt repaid, $35m Egypt operating cash inflow, and collections trending better post period.

What could trip the story up

• Receivables risk: $172m at mid-year (down to $160m by 31 August) is still high. Execution relies on EGPC payments keeping pace with stepped-up investment.
• Earnings sensitivity: H1 showed a group loss of $6.5m on lower revenue and high depletion, underscoring sensitivity to volumes and realised pricing.
• Financing nuance: continued reliance on lender waivers in Egypt is not ideal, even if facilities are non-recourse to the wider group.
• External uncertainties: outcome of the Senegal tax dispute and recovery from Waldorf remain uncertain.

What I’ll be watching next

• Parliamentary ratification of the integrated concession in 2025 and the follow-on Competent Person’s Report quantifying any reserves uplift.
• Test results from the NUMB and SEH exploration wells and how quickly any discoveries can be tied in.
• H2 collections from EGPC – at least $90m is expected, including the October bullet – and the trend in receivables by year end.
• Delivery of the 15 BED development wells and any impact on liquids mix and cash margins.
• Any concrete progress on UK North Sea or MENA M&A that fits the cash flow growth brief.

Bottom line

Capricorn’s H1 shows a business doing the basics well while lining up a structural upgrade to its Egypt portfolio. If Parliament ratifies the integrated concession and EGPC payments continue to land as planned, the company has a clear path to higher reserves, greater development optionality and stronger cash generation. Until then, keep an eye on receivables, lender waivers and the H2 drilling cadence. It is a pragmatic, execution-heavy story with a potentially valuable catalyst within sight.