88 Energy highlights Damara Fold Belt potential after regional drilling success in Namibia

Date context: The update was published on 9 February 2026 and focuses on how fresh regional results are strengthening the exploration case for a major new geophysical survey over Petroleum Exploration Licence (PEL) 93 in Namibia’s Damara Fold Belt.

What’s the big news?

88 Energy Ltd (listed in London and Sydney) says recent exploration progress in Namibia’s Damara Fold Belt increases confidence in its planned high-resolution airborne magnetic and gravity survey on PEL 93. In plain terms: the company believes the region is “getting more interesting,” and better data should help it map where oil and gas traps could be hiding.

The survey is expected in Q1 2026. The goal is to sharpen the picture of underground structures—faults, folds, and basin shapes—that can control where hydrocarbons collect.

Where is PEL 93 and who is involved?

PEL 93 is an onshore exploration licence in Namibia’s broader Owambo Basin. 88 Energy holds a 20% interest in the licence, while Monitor Exploration operates the project.

Think of it like a team: the operator runs day-to-day technical work, and partners like 88 Energy share the costs and potential rewards based on their ownership percentage.

Why airborne magnetic and gravity surveys matter

Exploration doesn’t start with drilling. Drilling is expensive, and the underground is invisible unless you “see” it with different tools. Two of those tools are:

1) Magnetic surveys

These measure small changes in Earth’s magnetic field. Different rock types and structures cause different magnetic responses. This helps geologists map basement trends and large structural features that can influence basin development.

2) Gravity surveys

Gravity data measures tiny differences in gravitational pull caused by changes in rock density. This can highlight basin thickness, major faults, and structural highs and lows—key clues when hunting for structural traps.

Why “high-resolution” matters: Higher resolution generally means tighter line spacing and better sensors, which can reveal smaller features and reduce uncertainty. Better certainty helps a project move from “interesting idea” to “drill-ready target.”

How the new data will be used

According to the project update, the airborne results will be integrated with existing seismic and geophysical datasets. That integration step is important because no single dataset tells the full story:

• Seismic can image layers and structures in more detail but is typically more costly and covers smaller areas.
• Magnetic + gravity can cover very large areas efficiently and help interpret the broader structural framework.
• Combined interpretation helps define targets that make sense geologically and can be ranked for follow-up work.

The stated purpose is to support resource assessments and guide future exploration activity—including future drilling decisions.

What “prospect mapping” really means

Exploration teams often talk about “prospects” and “leads.” Here’s a simple way to understand them:

• Lead: A possible trap or idea that looks promising but still needs more work and data.
• Prospect: A more mature target with clearer boundaries, better risk understanding, and a stronger case for drilling.

Monitor Exploration’s message is that these new airborne datasets should materially improve prospect mapping and help mature targets toward drill-ready status.

Key target: “Lead 9” and what we know about it

PEL 93 reportedly hosts multiple mapped leads, including Lead 9. What makes Lead 9 notable in the update is that it’s described as a structural closure—a shape underground that can trap hydrocarbons—covering around 100 square kilometres.

That Lead 9 interpretation was supported by a 203-kilometre 2D seismic program completed in 2024. Seismic lines are like “slices” through the subsurface. When combined with other measurements, they can show whether rocks are folded in ways that create closures.

Why size can matter: In exploration, a larger closure can sometimes imply more potential space for hydrocarbons—if the other ingredients (source rock, reservoir, seal, timing) are also present. Size alone does not guarantee success, but it can justify more work.

Licence timing: extension to October 2026

Exploration licences come with deadlines. If a team doesn’t complete required work or move the project forward, they can lose the licence. The joint venture has secured an extension of PEL 93 to October 2026.

Why that helps:

• It provides breathing room to collect new airborne data in early 2026.
• It allows time to plan further seismic work if needed.
• It supports partner discussions without the pressure of an immediate expiry date.

The update also notes preparations for future seismic acquisition and discussions with potential farm-in partners (new partners that may help fund drilling in exchange for an interest in the licence).

Why the nearby ReconAfrica well matters

A major reason this story drew attention is the mention of results from a nearby well: Kavango West 1X, drilled on adjacent acreage by ReconAfrica.

According to the referenced update, ReconAfrica reported:

• 400 metres of gross hydrocarbon-bearing section
• 64 metres of net pay
• in the Otavi carbonate sequence

The well is on PEL 73 and sits within the same broader fold belt trend as PEL 93. Production testing was scheduled for Q1 2026.

Gross hydrocarbon-bearing vs. net pay: what’s the difference?

These terms can sound confusing, so here’s a quick guide:

• Gross hydrocarbon-bearing interval means the total thickness of rock where hydrocarbons are indicated (by shows, logs, or other evidence).
• Net pay is a smaller number: the portion of that rock that is interpreted to have better reservoir quality and hydrocarbons in a_toggle that could potentially flow or be produced economically.

It’s still early-stage until testing confirms deliverability, but such intervals are often viewed as encouraging signals for a broader petroleum system.

How “regional petroleum system” thinking boosts PEL 93

In oil and gas exploration, a single well does not automatically prove a whole region is commercial. But it can answer big questions, such as:

• Is there a working source rock? (Rocks that generated oil or gas)
• Is there migration? (Hydrocarbons moved into traps)
• Are there reservoir rocks? (Rocks that can hold fluids)
• Are there seals and traps? (Structures that keep hydrocarbons from escaping)

The update indicates Monitor Exploration believes those nearby results materially enhance regional potential and support the prospectivity of PEL 93. It also notes that structural trends interpreted at Kavango West may extend into PEL 93—meaning the same kinds of geological “shapes” could continue across the map.

What happens next in 2026?

Based on the project statements, the near-term roadmap looks like this:

Step 1: Airborne survey (Q1 2026)

The first big milestone is the planned magnetic and gravity survey. This should deliver an upgraded structural interpretation and help prioritize areas for more detailed work.

Step 2: Integration and target ranking

Once data is processed, the team can merge it with the 2D seismic, existing datasets, and basin models to refine leads and prospects. This phase often ends with a ranked shortlist of targets and recommendations for next steps.

Step 3: Potential follow-up seismic

If the airborne survey highlights new structural detail or confirms promising trends, the joint venture may acquire more seismic lines (or consider 3D seismic in focused areas, depending on cost and strategy).

Step 4: Farm-in discussions

Exploration drilling is expensive. Bringing in a partner can reduce funding pressure and share risk. A farm-in partner may fund seismic and/or drilling in exchange for a stake in the licence.

Step 5: Drill planning (if warranted)

If targets mature and funding aligns, drilling becomes the key value catalyst. But drilling should only come after the geology is mature enough to justify the cost and risk.

Why this matters to investors (and what to watch)

For market watchers, this update sits at the intersection of data-driven derisking and regional momentum. Investors typically follow exploration stories by asking:

• Is the project moving forward on a clear timeline? (Here, Q1 2026 is a concrete marker.)
• Are targets getting more “drillable”? (Better prospect mapping suggests progress.)
• Is there regional validation? (Nearby well results can be a confidence boost.)
• Is funding strategy realistic? (Farm-in discussions hint at a path forward.)

Key watch items in 2026:

• Confirmation that the airborne survey is completed on schedule and the quality of the final processed results
• Any updated maps, target outlines, or resource/volumetric commentary that can show how leads are evolving
• Progress on securing a farm-in partner, if pursued
• Updates on testing results from the nearby Kavango West 1X well, as these could influence regional sentiment

Risks and uncertainties (important to keep in mind)

Exploration is exciting, but it is also uncertain. Even with strong regional indicators, projects can face setbacks. Common exploration risks include:

• Geological risk: A structure may exist, but the right reservoir rock or seal might not.
• Data ambiguity: Early interpretations can change as higher-resolution datasets arrive.
• Operational risk: Surveys can be delayed by weather, logistics, permitting, or contractor scheduling.
• Funding risk: Markets can tighten, and farm-in discussions may take longer than expected.
• Regulatory and community factors: Onshore operations require ongoing compliance and stakeholder engagement.

That said, the planned work program—collecting more data before drilling—is a typical and sensible way to manage risk in frontier exploration settings.

FAQ: Quick answers about the 88 Energy Namibia update

1) What exactly did 88 Energy announce?

88 Energy said regional drilling success in Namibia’s Damara Fold Belt strengthens the case for a planned high-resolution airborne magnetic and gravity survey on PEL 93, where it holds a 20% interest.

2) When is the airborne survey planned?

The survey is scheduled for Q1 2026, aiming to refine mapping of structural features and improve the definition of drillable targets.

3) Who operates PEL 93?

Monitor Exploration is the operator of the licence, with 88 Energy as a partner holding 20%.

4) What is “Lead 9”?

Lead 9 is described as a mapped structural closure on PEL 93 with an approximate areal extent of around 100 km², identified following 203 km of 2D seismic completed in 2024.

5) Why are ReconAfrica’s Kavango West 1X results important here?

The nearby well results were presented as encouraging for the wider region because the well reported hydrocarbon-bearing intervals and net pay in the Otavi carbonates, and the structural trend may extend toward PEL 93. Testing was planned for Q1 2026.

6) What does the licence extension to October 2026 mean?

It gives the joint venture more time to complete technical work (like the airborne survey and potential future seismic), mature targets, and potentially bring in farm-in partners before moving to drilling decisions.

Bottom line

88 Energy’s Namibia update is mainly about building a stronger technical foundation for exploration on PEL 93. The planned airborne magnetic and gravity survey in Q1 2026 is a practical next step to improve target mapping and reduce uncertainty. The encouraging nearby Kavango West 1X results—plus the view that structural trends may carry into PEL 93—add a layer of regional optimism, but the story still depends on what the new data reveals and how quickly targets can be matured, funded, and eventually tested by drilling.

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