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Most African economies are net importers of fuel and fertiliser.

The war involving Iran has moved from a geopolitical story to a supply chain shock -- and fast

At the centre of it all is the Strait of Hormuz. In normal times, roughly a quarter of global seaborne oil flows through that narrow channel. Today, it’s partially blocked, militarised and unpredictable. That matters more than most people realise, especially in Africa.

This is not just an oil story. Yes, oil is the headline. The International Energy Agency is already calling this the largest disruption in oil market history, with up to 30% of global oil flows affected. Prices are responding accordingly. Analysts are openly discussing US$150-US$200 per barrel scenarios if disruption persists into the next four to eight weeks.

But stopping at oil is missing the real risk. Because Hormuz doesn’t just move fuel. It moves, fertiliser, petrochemicals, plastics inputs and liquefied natural gas. And that’s where Africa gets hit hardest.

Across East and southern Africa, dependence on Middle Eastern supply chains is structural, not optional. Countries like Kenya, Tanzania, Ethiopia and Zambia are already implementing emergency measures, including subsidies and reserve releases. In parts of East Africa, over 50% of fertiliser imports come via these routes and globally, up to one-third of fertiliser trade moves through Hormuz.

And prices are moving fast; Urea prices are already up by 50% since the conflict began and fertiliser shortages are expected to impact planting cycles within weeks. That translates directly into higher food prices, lower yields and increased inflation. In economies where food already dominates household spend, that’s not a marginal issue. It’s systemic.

Fuel price shock hits logistics immediately

Diesel is the bloodstream of African logistics. As oil spikes, transport costs rise almost instantly. We can expect higher road freight tariffs, airline and shipping surcharges and margin compression across FMCG and retail

Shipping delays compound the problem

Major shipping lines have already rerouted vessels around the Cape of Good Hope, adding weeks to transit times. That means longer lead times, working capital pressure and more stockouts.

Fertiliser becomes the sleeper crisis

This is the one most executives will underestimate. Miss a planting window, and the impact shows up months later in food inflation, social pressure and currency weakness. 

Secondary shortages begin to emerge and this is where it gets messy:

Plastics (packaging constraints)
Chemicals (manufacturing inputs)
Even pharmaceuticals

The supply chain doesn’t break in one place—it ripples. The brutal reality is that Africa is a price taker. Most African economies are net importers of fuel and fertiliser and are highly exposed to global shipping routes which means there is very little control, only response.

The difference between businesses that weather this disruption and those that don't will not be found in strategy decks. it will be found in the decisions made over the next two to four weeks. Lock in supply now, even at uncomfortable prices, because in volatile markets availability will always beat price.

Selectively build buffer stock across fuel, critical imported inputs, and high-margin SKUs. Working capital will sting, but stockouts will cost more. It is important to reroute early, explore alternative ports, different origin countries, and split shipments before the options narrow.

Reset contractual expectations with both customers and suppliers without delay, because what was considered late last month is fast becoming the new normal. Run at least three disruption scenario -- two weeks, six weeks, three months -- and tie each directly to pricing, inventory policy and customer communications. Finally, watch fertiliser and food input prices closely: even if the business sits outside agriculture, its customers do not, and the ripple effects on patterns are coming regardless. The window to act is open. It will not stay that way.

This is not a distant war -- it is a supply chain event with immediate commercial consequences. Should the Strait of Hormuz remain unstable for another month, Africa will not simply absorb higher prices; it will contend with slower trade, tighter margins, and rising food insecurity. The uncomfortable truth is that the businesses which act early will appear paranoid today -- and exceptionally well-positioned in 30 days.

The article has been written by Ronald Mlalazi, president, Africa Supply Chain Confederation

The BED facility will undergo maintenance shutdowns twice in 2026.

Liquids-rich development drilling and the ongoing waterflood programme in the Badr El Din (BED) concession has resulted in increased production levels from Egypt for Capricorn Energy's 2025 report at 20,024 barrels of oil equivalent per day, surpassing the year's guidance of 17000-21000 bopd

The new guidance for 2026 is hence set at 18000-22000 boepd, also driven by a forecast to generate 43% liquids. A four-rig drilling programme has been put in place throughout the year with a special focus on the liquids-rich area. It will also include activities on the gas-prone Bahariya target which was found last year. Operating costs for the year are anticipated around US$5-7 barrels of oil equivalent. The US$217mn collected from Egypt in 2025 will cover the funding for the sustainably designed drilling plan.

The BED facility will undergo maintenance shutdowns twice in the year.

The Egyptian General Petroleum Corporation and the Egyptian Cabinet have approved the merged concession agreement, with formal ratification expected within the first half of 2026.

"2025 was a year of significant operational, strategic and financial progress for Capricorn, marked by a number of milestones across our Egypt operations.

"In May we received approval from the Egyptian General Petroleum Corporation (EGPC) to consolidate eight of our existing Egyptian concession agreements into a single, merged concession agreement, unlocking significant fiscal and operational benefits which should allow us to extract additional value from our existing portfolio. The new agreement, anticipated to receive parliamentary ratification in H1 2026, secures access to an additional development lease area and two open exploration areas adjacent to our existing acreage. These additions supported a 20.2 mmboe increase of working interest (WI) 2P reserves (certified at year end), enhancing future development potential. The improved fiscal terms will drive increased investment and cash flow across a range of oil prices and at $80 per bbl our netback improves from $18 to $23 per boe. Furthermore, it includes a 60% increase in gas pricing for incremental volumes from both existing fields and new discoveries.

"Operations in Egypt delivered full year production of 20,024 boepd, exceeding the midpoint of 2025 guidance, supported by liquids-rich development drilling and the ongoing waterflood programme in the Badr El Din (BED) concession.

"Despite a volatile macroeconomic environment and fluctuating commodity prices, we collected $217m from Egypt, reducing the Company’s accounts receivable to $86m.

"Capricorn’s progress in 2025 provides a robust platform to build a cash-generative business. A key priority for 2026 will be accelerating development activities in the merged concession area.

"Our strategic priorities for the coming year are to maximise value from our Egyptian assets through disciplined investment, prioritise shareholder value, and continue to explore value-accretive opportunities, primarily in Egypt, with a secondary focus in the UK North Sea and the broader MENA region," said Randy Neely, the chief executive of Capricorn Energy.

The company's outlook in Egypt for 2026 is set around 1,200 to 1,450 bopd,.

An energy operator in Egypt, Pharos Energy, has recorded around 1,303 barrels of oil equivalent from the region for the year ended 31 December 2025 

The company's outlook in Egypt for 2026 is set around 1,200 to 1,450 bopd, as Group working interest production guidance increased from 2025 to 5,200 - 6,400 boepd net. 

The company has also secured approval in September from EGPC Executive Board for the consolidated Concession Agreement with improved fiscal terms. The consolidated Concession Agreement comes with a committed work programme under which two wells are included and multiple targets have been identified. This follows the completion of 3D seismic data processing and interpretation from North Beni Suef (NBS).

A second rig has been contracted for North Beni Suef work, alongside a seperate rig for El Fayum. A work programme with a planned budget for six wells have been approved with preparations for implementation underway, and drilling of first well is set to begin shortly.

Parliamentary ratification of the consolidated Concession Agreement expected later in 2026; 5 October 2025 retroactive date applies.

"In Egypt, we were pleased to receive approval from EGPC for the consolidation of our two existing concessions, delivering an immediate uplift in value with 20-year lease extensions and improved fiscal terms. I am delighted that our receivable balance is now at its lowest level since December 2021 at $6.1m, due to the $20 million payment received from EGPC in December, doubling our year end cash balance," said Katherine Roe, chief executive officer, Pharos Energy. 

 

Africa's LNG ambitions are being tested by global turbulence.

Africa’s oil and gas sector is entering a period of accelerated transformation 

The continent’s upstream potential, midstream ambitions and downstream vulnerabilities are all being reshaped by a global environment defined by geopolitical tensions, shipping disruptions, sanctions and shifting investment flows. These pressures are forcing African producers, national oil companies (NOCs), and policymakers to rethink strategy, timelines and risk management.

While Africa remains central to global energy security, the path forward is no longer linear. The continent’s energy landscape is evolving — and the pace of change is being set as much by global turbulence as by domestic policy choices.

New frontiers, new pressures

Africa’s upstream sector is experiencing both renewal and recalibration.

New frontiers are emerging as Namibia’s offshore discoveries continue to attract global attention. Ivory Coast's Baleine field is reshaping West Africa’s exploration map, and Uganda’s Lake Albert development is progressing toward first oil.

Traditional producers, however, are facing structural pressures. Nigeria continues to struggle with pipeline insecurity and feedgas constraints. Angola is restructuring Sonangol and revising its licensing strategy. Mature basins across North Africa require reinvestment to maintain output.

Geopolitical tensions have also altered investor behaviour. Sanctions, supply chain delays and financing constraints have made upstream investment more cautious, with international oil companies (IOCs) prioritising lower risk and faster cycle assets. This trend is visible in the shift toward short‑cycle offshore projects in West and southern Africa, and the cautious approach to long‑led developments in East and southern Africa. This has elevated the role of African NOCs, many of which are undergoing commercialisation reforms to attract capital and improve operational efficiency.

Regional integration challenges

Africa’s midstream infrastructure — pipelines, storage, and transport networks — is increasingly exposed to global and regional disruptions.

Pipeline vulnerabilities remain a major constraint. The Niger–Benin pipeline has faced security and political uncertainty. Nigeria’s pipeline network continues to suffer from vandalism and theft. Chad-Cameroon pipeline operations have been affected by governance disputes.

Meanwhile, regional midstream ambitions are advancing but unevenly. The East African Crude Oil Pipeline (EACOP) remains a flagship project but faces financing and environmental scrutiny even as it progresses. The West African Gas Pipeline continues to struggle with reliability issues. The TransSaharan Gas Pipeline remains aspirational amid security concerns.

Geopolitical tensions have also disrupted traditional shipping routes. Some carriers have begun rerouting cargoes toward East African ports, including Kenya, as part of broader adjustments to avoid Red Sea insecurity. While still evolving, these shifts highlight Africa’s growing role as both a transit and destination market in a fragmented global logistics environment.

Refining gaps and market fragility

Africa’s downstream sector remains structurally vulnerable. The continent imports a significant share of its refined petroleum products, leaving domestic markets exposed to global price volatility and supply disruptions.

The closure of several South African refineries has increased import dependence. The Dangote Refinery in Nigeria is expected to reshape regional product flows once fully operational. Uganda, Angola and Senegal are pursuing new or upgraded refining capacity to reduce import reliance.

Global geopolitical tensions — including sanctions, shipping disruptions, and insurance volatility — have amplified downstream fragility. Countries with limited storage capacity or heavy reliance on imported diesel and petrol have faced periodic supply tightness and pricing pressure.

LNG opportunity under stress

Gas remains Africa’s most promising transition fuel, but the continent’s LNG ambitions are being tested by global turbulence. Mozambique LNG remains delayed due to security concerns and cost escalation. Senegal–Mauritania’s GTA project has experienced timeline adjustments. Tanzania’s LNG negotiations have regained momentum after years of stagnation. Nigeria LNG faces feed-gas constraints and maintenance backlogs.

Global shipping insecurity — particularly in the Red Sea and Suez Canal — has increased voyage times, insurance premiums and charter rates. Some LNG and petroleum cargoes have been rerouted around the Cape of Good Hope, adding significant cost and delay. These pressures complicate Africa’s efforts to position itself as a reliable LNG supplier in a competitive global market.

NOCs at a crossroads

National oil companies are becoming more central to Africa’s energy future as IOCs rebalance portfolios.

Nigerian National Petroleum Company Limited has taken major commercialisation efforts in Nigeria. Sonangol is restructuring and divesting asset in Angola. Ghana National Petroleum Corporation has expanded its role in Ghana’s upstream sector. ENH (Mozambique) and the National Hydrocarbons Corporation of Cameroon are navigating complex LNG and gas monetisation strategies.

NOCs are facing the dual challenge of delivering national energy security and revenue stability, and competing for capital in a world increasingly shaped by ESG pressures and geopolitical risk. Their ability to modernise governance, improve transparency and manage complex partnerships will determine the pace of Africa’s energy transformation.

The new risk landscape

Africa’s oil and gas sector must now operate within a risk environment defined by:

- Shipping insecurity and rerouting pressures

- Supplychain fragmentation and equipment delays

- Sanctions exposure affecting financing and trade

- Insurance volatility, including rising warrisk premiums

- EPC delays and cost overruns

- Contractual disputes, including force majeure and hardship claims

- Financing constraints as lenders reassess geopolitical risk

These risks are not temporary. They represent a structural shift in how global energy markets function — and African producers ought to adapt accordingly.

Shift in strategies

Africa remains central to global oil and gas supply, with vast reserves, growing domestic demand, and strategic geographic positioning. But the continent’s energy future will depend on its ability to navigate a world where geopolitical tensions, shipping disruptions and investment realignments are the new normal. This will require stronger regional cooperation, diversified supply chains, modernised NOCs, increased private sector involvement, resilient midstream infrastructure and flexible commercial strategies.

Africa’s energy landscape is evolving — and those who adapt early will shape the continent’s next chapter. 

The article has been written by Elijah Paul RukidiMpuuga, FCIArb (UK), founder and principal, Equitas Dispute Resolution Group

Sonangol is operator of Blocks 3/05 and 3/05A.

As part of a transaction process, Sonangol E&P has elected to participate in the acquisition of Etu Energia's interests in Blocks 3/05 and 3/05A offshore Angola 

This establishes Sonangol, Afentra and Etablissements Maurel & Prom SA's joint acquisition of Etu's 10% interest in Block 3/05 and 13.33% interest in Block 3/05A.

With Sonangol's participation -- which is also operator of the blocks -- Afentra's new sale and purchase agreement with Etu outlines the acquisition of 3.33% interest in Block 3/05 and a 3.66% interest in Block 3/05A.

The consolidated partnership of Sonangol E&P, Afentra and Maurel & Prom in Block 3/05 and 3/05A will accelerate the ongoing redevelopment programme that is beginning to unlock the full potential of the assets which will lead to sustained increases in both production and reserves over the coming years.

Afentra continues to pursue its disciplined approach to value creation, leveraging success-based transaction structures and a strong local partnership framework. The Company remains confident in the significant upside potential of Blocks 3/05 and 3/05A and looks forward to continued constructive engagement with all stakeholders.

Paul McDade, Chief Executive Officer of Afentra plc, said, "The evolution of the transaction structure to include Sonangol in the Etu acquisition is a welcome development and is a clear demonstration of the collaborative approach that has been achieved within the partnership. The joint acquisition further consolidates and aligns all parties as we work together to unlock the full potential of Blocks 3/05 and 3/05A. This transaction exemplifies Afentra's disciplined strategy of building a high-quality, cash-generative asset base in Africa in close partnership with host governments and local operators." 

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