Bonga North boost for TechnipFMC. (Image source: Adobe Stock)

Nigeria’s Bonga North deepwater project featured prominently as French engineering group TechnipFMC posted a robust set of Q4 2024 results

The company announced back in December that it had secured work on the deepwater project, worth between US$250mn and US$500mn, which is being put together by a local unit of Shell.

The contract — awarded by Shell Nigeria Exploration and Production Company Limited — will see TechnipFMC supply Subsea 2.0 production systems for the Bonga North development, with work covering the design and manufacture of subsea tree systems, manifolds, jumpers, controls and other services.

But the company also highlighted “higher activity” generally in Africa behind the success of its subsea division during the quarterly period.

It saw the company’s total order backlog reach US$14.4bn, an increase of 9% on a year earlier, with full-year orders worth US$10.4bn. The company said it anticipates a similar order book for 2025.

Doug Pferdehirt, chair and chief executive of TechnipFMC, called it “another year of tremendous success” for the group.

TechnipFMC also reported strong growth across the Middle East region.

“We have secured US$20.2bn of subsea orders over the past two years, and our strong market visibility gives us confidence we will exceed US$10bn of inbound in the current year — delivering on our guidance of US$30bn over the three-years ending 2025,” he said.

Pferdehirt also said that the outlook for further subsea work was positive, a potential nod to the wave of offshore projects in Africa currently in the planning, in areas ranging from Tanzania and Mozambique to Namibia.

“We are also experiencing increased visibility into the pipeline of longer-term opportunities, supported by a growing list of named projects that extends beyond the historical planning horizon, giving us even greater confidence that activity will remain robust through the end of the decade.”

Other frontier provinces have provided opportunity as well, with TechnipFMC landing US$1bn worth of work on the GranMorgu project, the first oil and gas development offshore Suriname.

Shell’s Bonga North development off Nigeria will be a subsea tie-back to the Bonga floating production storage and offloading (FPSO) facility, located in block OML 118, in water depths over 1,000 metres.

It includes drilling, completing and starting up 16 wells (eight production wells and eight water injection wells), modifications to the existing FPSO and the installation of new subsea hardware tied back to the facility.

Bonga North currently has an estimated recoverable resource volume of more than 300 million barrels of oil equivalent (boe) and will reach a peak production of 110,000 barrels of oil a day, with first oil anticipated by the end of the decade.

Read more: 

TechnipFMC's Subsea 2.0 to support Shell's Bonga North offshore Nigeria

SNEPCO reaches FID on Bonga North offshore Nigeria

Bonga field offshore Nigeria undergoes well completion with Optime's ROCS

Namibia's offshore has become hot property. (Image source: Adobe Stock)

Portuguese energy company Galp Energia has discovered more oil and gas at Namibia’s Mopane field

The company reported this week that it had found significant presence of light oil and gas condensate in a fifth well, Mpane-3X, in Namibia's offshore Mopane field in block PEL83.

Galp's Mopane offshore discovery was initially estimated to hold at least 10bn barrels of oil and gas, opening up Nambia’s Orange Basin as a new frontier with global potential. The Portuguese company is operator of the offshore concession area with an 80% equity stakeholding, alongside its partners NAMCOR, the National Petroleum Corporation of Namibia, and Custos Energy, an independent firm, each with 10%.

The Mopane-3X well was spudded on 2 January and has now been successfully drilled, cored and logged, the group said in a statement. Located 18 km from the first Mopane-1X well, the latest drilling targeted two stacked prospects, AVO-10 & AVO-13, and a deeper sand, in the southeast region of the Mopane complex, at around 1,200 metres water depth.

“Preliminary data confirm light oil and gas-condensate significant columns across AVO-10, and light oil columns on AVO-13 and on the deeper sand, in high-quality sandstones,” it noted. “The reservoirs log measures confirm good porosities, high pressures and high permeabilities. Initial fluid samples show low oil viscosity and minimum CO2 and H2S concentrations. Samples were sent for lab testing.”

Galp Energia also added that Mopane-3X showed higher-than-estimated pressures, and that these preliminary results “unlock further exploration and appraisal opportunities in the southeast region of Mopane.” 

All acquired data will now be integrated into its reservoir model to support the planning of potential further activity. A proprietary 3D seismic acquisition campaign is also on track to be completed in Q1 2025, with the processing of the information to follow thereafter.

Knowledge Katti, chairman and CEO of Custos Energy, added that it marked another safe and successful drilling on what is rapidly becoming a world-class asset.

“These additional discoveries in an entirely new section of Mopane further demonstrate the scale and quality of the complex. An emerging clarity on the multi-phase potential of Mopane is underpinned by this world class asset,” he said. “We are uniquely positioned at the heart of this hydrocarbon province.”

At the end of 2024, Galp Energia announced the findings of the previous well, Mopane-2A, also in PEL83, which found a hydrocarbon column of gas-condensate in AVO-3 with a thin net pay in the reservoir sweet spot. The well also discovered a hydrocarbon column of light oil in a smaller reservoir, AVO-4. 

Read more: 

Mopane records good hydrocarbons presence yet again

Second campaign follows positive results from Mopane

Custos Energy acknowledges Namibia's PEL83 potential

Nigeria's independents are flourishing. (Image source: Adobe Stock)

Nigerian independent oil and gas producer Heirs Energies has revealed that its production now surpasses more than 50,000 barrels per day (bpd)

The company — which refers to itself as Africa’s fastest-growing indigenous integrated energy company — has seen its production more than double from 21,000 bpd in just four years.

Hosting its inaugural Petroleum Industry Leadership Dialogue at the Transcorp Hilton Abuja recently, its founder and chairman Tony Elumelu paid tribute to the catalytic role the current government has played in reinvigorating the independent oil and gas sector.

“Production growth, ambitious and sustained, is our shared national mission,” he told delegates at the event.

“As an investor, not just in resources, but in Nigeria’s power production and distribution sectors, all of us need to come together to ensure Nigerians get the benefits of our resources. As we build Africa’s largest integrated energy business, innovation and collaboration are central to our execution.”

Elumelu also set out his company’s vision of transforming Africa’s energy landscape through indigenous leadership, coupled with sustainable development.

Heirs Energies chief executive, Osa Igiehon, illustrated how the company had successfully grown its footprint in Nigeria’s onshore sector.

“Our success at Heirs Energies demonstrates what’s possible in Nigeria’s onshore sector, through our brownfield excellence strategy, robust security measures and genuine community partnership,” he said.

“By tripling our producing wells to over 100, we’ve shown how indigenous operators can efficiently unlock value while ensuring sustainable development of host communities.”

Speaking at the forum, Minister of State for Petroleum Resources (Oil), Sen. Heineken Lokpobiri, announced that Nigeria’s total oil production stood at 1.8 million bpd in January 2025.

The target is to grow this to 2.5 million bpd during 2025, he added.

He also reaffirmed the administration’s ‘drill or drop’ policy to accelerate production growth and further encourage the development of the independent sector.

Other speakers at the event highlighted how a series of Presidential Executive Orders had radically reshaped the operating environment for the independents and catalysed industry growth.

Indigenous oil and gas firms are now responsible for more than 60% of Nigeria’s crude output with the indigenisation programme delivering a “bold new chapter” in the country’s natural resources development, delegates heard.

Ademola Adeyemi-Bero, chief executive at First E&P, another independent, and also OPEC Board of Governors chairman for Nigeria, cited his own company’s achievement of reaching 57,000 bpd from previously untapped fields.

Gbenga Komolafe, chief executive of the Nigerian Upstream Petroleum Regulatory Commission (NUPRC) highlighted a surge in active drilling rigs to 38, with projections to reach 50 by March 2025.

Read more: 

Eni to sell NAOC Ltd to Oando plc

Chappal acquires 10 interests in Total's Nigeria assets

San Leon aiming increased production from OML 18 onshore Nigeria

With this acquisition, UEG's current production will reach 39,000 boepd. (Image source: Adobe Stock)

To further expand its footprint in Egypt since Kuwait Energy acquisition in 2019, United Energy Group has signed a sale and purchase agreement with Apex International Energy LP to acquire its entire upstream assets via United Energy (MENA) Limited

A significant producer in the Western Desert of Egypt, Apex's area of operations spanned beyond 3,500 sq km, including eight onshore concessions. Its gross production count for 2024 stands at 11,000 barrels of oil equivalent per day (boepd). 

Apex had acquired six of these concessions in 2023 from IEOC Production, a unit of Eni. It included IEOC’s interests in the Ras Qattara, West El Razzak, East Kanayis, and the West Abu Gharadig concessions. The company had made the acquisition to see its first gas production, and become a front runner in the booming Egyptian natural gas industry. 

With this acquisition, UEG's current production count of 22,000 boepd will shoot up to 39,000 boepd, adding to its existing interests in five concessions. Besides production optimisation, this move also highlights the company's focus on asset integration to have greater control over field development before exploration. Enhanced oil recovery with strong technical support will be the company's watchword to chase growth potential in its Egyptian acreage. The acquisition will allow UEG to advance regional integration to solidify its global energy supply chain, which will also benefit Egypt's energy industry.

With the merger agreements now approved by the Egyptian Cabinet, UEG is looking forward to better fiscal terms, increased investment, greater economic potential and long-term value creation. 

Extensive deepwater data from PGS

Egypt continues to be a coveted exploration spot globally, especially to harness its gas resources. Last year, geoscience data provider PGS had released 3D seismic data over the deepwater area between the Nile delta and the Herodotus Basin as part of its EGY23 Merneith & Luxor survey. 

Acquired with Ramform vessels and GeoStreamer broadband technology, the 6,175 sq km EGY23 Merneith & Luxor survey draws on the expertise of PGS's partners the Egyptian Natural Gas Holding Company (EGAS). The GeoStreamer-acquired data covers both low and high-frequency information that can make a huge difference in interpreting structures and analysing rock property. 

The survey cracked into an underexplored and unlicensed deepwater area and extracted 3D data from the region, marking a significant upgrade from the currently available 2D data.

A Messinian evaporite layer of variable thickness extends across most of the area. The survey is tied to the Kiwi-1 well, one of the few wells in this deepwater area, and primary targets are likely to be presalt Oligo-Miocene structures with clastic reservoirs.