The two subsea tie-back projects will deliver additional production. (Image source: TotalEnergies)

TotalEnergies has begun production from the Begonia and Clov Phase 3 offshore projects, leveraging ullage in the Pazflor and Clov floating production, storage and offloading units (FPSO) to add a total of 60,000 barrels a day of new production

These two subsea tie-back projects deliver additional production leveraging available capacity on existing FPSO’s and as such have low marginal costs and low carbon intensities.

TotalEnergies is an Operator with a 30% interest in Begonia, which is the first inter-block development on Block 17/06 in Angola. A project made possible thanks to good cooperation between the Angolan concession holder Agencia Nacional de Petróleo, Gás e Biocombustíveis (ANPG), the partners of the block 17/06, Sonangol E&P (30%), SSI (27,5%), ETU Energias (7.5%), Falcon Oil (5%), and the partners of block 17 also operated by TotalEnergies.

Located 150 kilometers off the Angolan coast, Begonia is a 30,000 barrels per day project consisting of five wells subsea tied back to the Pazflor FPSO.

With a 38% interest, TotalEnergies is also the Operator of Clov Phase 3, continued upsides on Block 17. The company has announced the first oil from the development, in agreement with ANPG and its partners Equinor (22,16%), ExxonMobil (19%), Azule Energy (15.84%) and Sonangol E&P (5%).

Located 140 kilometers from the Angolan coast, Clov Phase 3 is a 30,000 barrels per day project consisting of four wells subsea tie-back to the Clov FPSO.

“TotalEnergies, operator of Block 17 and 17/06, continues to actively deliver its low-cost and low-emissions developments to grow its upstream production by more than 3% in 2025,” said Nicolas Terraz, president exploration and production at TotalEnergies. “With Begonia and Clov Phase 3, we are leveraging available production capacity in existing FPSOs of Block 17 (Pazflor and Clov) while reducing costs and emissions.”

“Good news for the country, as those two First Oils will help Angola maintain its production levels above 1 million barrel per day. Begonia is the first project between Blocks in Angola with a significant component of Local Content and Clov 3 is a great achievement resulting from intense work between the concessionaire and the B17 contractor group, operated by TotalEnergies. Projects like these are extremely important as they prove the innovative spirit and dynamism of the oil sector in Angola,” said Paulino Jeronimo, chairman of the Board of Directors of the National Agency for Petroleum, Gas and Biofuels.

Capricorn forecasts the drilling of 10 development wells for H2 2025.

Capricorn has announced its half-year results

Randy Neely, chief executive, Capricorn PLC said, “Capricorn enters the second half of 2025 having made material progress in its strategic priorities, underpinned by financial discipline and driven by a focused team who have set out a clear path to creating shareholder value. EGPC board approval of the renewed concession terms marked a pivotal milestone in the evolution of our Egyptian business and, anticipating the conclusion of customary parliamentary ratification expected later this year, momentum has never been stronger to achieve increased reserves and value improvements to our Western Desert assets.

"With a payment plan agreed with the Egyptian General Petroleum Corporation (EGPC), we have continued to invest in the asset base, actively working with EGPC to ensure that the timely payment of receivables is able to support the increasing investment programme.

"Growing cash flow through diversification and expanding our operations remains a key strategic priority, and we continue to actively evaluate strategic investment and partnership opportunities in the region alongside accretive opportunities in the UK North Sea.”

WI production for H1 2025 in the Western Desert averaged approximately 20,000 boepd (43% liquids), tracking slightly above the mid-point of the full year guidance range for 2025 of 17,000 – 21,000 boepd. The recent receipt of a payment plan from EGPC, along with payments consistent with that plan, is expected to resolve recent issues that have been impacting timely provision of oil field supplies and services in support of production at the Operator, Bapetco. Capricorn continues to work with the Operator to prioritise opportunities to add production, from reinstating high-graded shut-in wells, to identifying additional perforation opportunities and optimising the development well sequence.

In the first half of 2025, development drilling activity was limited by the need to fulfil outstanding exploration commitments, postponed from 2024 and backed by a parent company guarantee. In April, a fourth rig was brought into the fleet to accelerate the completion of these exploration commitments, and from August the entire fleet is expected to be allocated to development activity. Three exploration wells have been drilled with one each on the North Um Baraka, West El Fayoum and South East Horus concessions. All three wells encountered hydrocarbons and are currently under analysis in anticipation of testing to evaluate commerciality.

In the second half of 2025, Capricorn forecasts the drilling of 10 development wells, all focused on the Badr El Din area, targeting liquids. This work programme is expected to be attributed against the commitments that the Company will be required to fulfil as part of the recently agreed integrated concession agreement.

Capricorn has engaged its reserves auditor, GLJ, to evaluate the expected reserves and resources increment associated with the consolidation of eight of the Company's existing Egyptian concession agreements into a new, single integrated concession agreement, which was recently approved by the EGPC Board. The preliminary work undertaken aligns with Capricorn’s expectation of an initial conversion of WI resources to 2P reserves of up to approximately 20 mmboe in the current year, and the Company continues to expect the customary Parliamentary ratification of the new agreement later in 2025. Capricorn anticipates investing in the concession area under the new terms prior to formal ratification.

The MoU will advance regional energy development in sub-Saharan Africa.

The Mnazi Bay North Block in southern Tanzania will undergo a technical assessment so that it can be developed for exploration and production opportunities by FIRST Exploration & Petroleum Development Company and the Tanzania Petroleum Development Corporation

Both the companies have signed a memorandum of understanding (MoU) to officialise the plan as an advancement of regional energy development in sub-Saharan Africa.

The MoU signing ceremony took place at the TPDC Head Office in Dodoma, with senior executives from both organisations, representatives of the Government of Tanzania, and members of the media in attendance.

Ademola Adeyemi-Bero, Managing Director/CEO of FIRST E&P, said, "Our success in Nigeria, built on deep technical expertise, a high-performance team, and an entrepreneurial mindset, has positioned us to deploy our capabilities beyond our home market. We believe Tanzania holds world-class hydrocarbon resources and its strategic location positions it as a natural energy hub for the region. With the right investments and partnerships, Tanzania can play a pivotal role in improving energy access, enabling cross-border distribution, and driving regional energy security across Sub-Saharan Africa.”

"We are confident that this MoU marks not just the beginning of a project, but the start of a long-term, mutually beneficial relationship between FIRST E&P and the government and people of Tanzania. We extend our sincere appreciation to TPDC for their collaborative spirit, professionalism, and openness throughout this process," said Adeyemi-Bero.

“The Petroleum Act of 2015 empowers TPDC to develop blocks independently or in partnership with strategic collaborators. TPDC has since identified key blocks, including Mnazi Bay, and we are working in close coordination with Petroleum Upstream Regulatory Authority (PURA), the Ministry of Energy, and TPDC to progress development. This MoU marks a first-of-its-kind upstream initiative, and we look forward to commencing exploration and production activities. With FIRST E&P’s support, we believe Tanzania’s upstream sector will be significantly strengthened,” said Godluck Shirima, Commissioner for Petroleum and Gas, Ministry of Energy, Tanzania.

Mussa Makame, managing director, Tanzania Petroleum Development Corporation (TPDC) said, “The reality we must acknowledge as Africans is that many of our people still rely on biomass for energy -- an option that poses serious risks to both health and the environment. Transitioning to gas is a critical step toward ensuring energy security for our communities. Developing our reserves is, therefore, a national priority. It is even more encouraging when African companies collaborate to unlock these resources, as it allows us to harness and benefit from them right here on our own soil.”

PEL 79 sits adjacent to an emerging microregional dynamic focused on oil-weighted prospectivity. (Image source: Sintana Energy))

The Ministry of Industries, Mines and Energy for the Republic of Namibia has approved a second renewal exploration period with a 12-month extension for the petroleum exploration license 79 (PEL79) that includes blocks 2815 and 2915 located in Namibia's Orange Basin

The PEL 79  is operated by the National Petroleum Corporation of Namibia Ltd (Namcor) with a 67% interest, while Giraffe Energy Investments -- an entity in which Sintana maintains a 49% ownership interest -- owns a 33% share on the license.

Sitting inboard of licenses operated by BW Energy, Rhino Reosurces, and Shell, PEL 79 promises incredible prospects with an existing prospect inventory underpinned by more than 4760 km of 2D seismic, 1,137 sq km of 3D seismic and 1 well with gas shows intersecting the Kudu source rock.

To top that, PEL 79 sits adjacent to an emerging microregional dynamic focused on oil-weighted prospectivity.

Right outboard to the west of PEL79, the license operator, Rhino Resources, has drilled two wells, including the Capricornus-1X discovery well, that reflected a flow test exceeding 11,000 barrels per day of light oil with limited associated gas from a 38-metre net oil-bearing reservoir. The third quarter of the year will see the commencement of further drilling activity, targeting the Volans prospect, with up to two optional wells that could include appraisals.

BW Energy has acquired 4,600 sq km of new 3D seismic over PEL 3, located directly west of PEL 79, and has moved to initiate an exploration and appraisal campaign including drilling the Kharas well located northwest of Kudu during H2 2025.

“We appreciate the leadership by our joint venture partner NAMCOR to secure the extension for PEL 79. Extending our exposure during a period of significant offset activity positions us to fully realise the significant geologic, commercial, and strategic value of PEL 79,” said Robert Bose, chairman of Giraffe and chief executive officer of Sintana. “The potential for high impact progress on PEL 79 adds to the prospect for significant developments across our Namibian offshore portfolio. We expect material progress on all our licenses over the coming quarters,” he added.