CCUS in Nigeria: Carbon Capture Potential from Niger Delta Gas Fields

The case for carbon capture, utilization, and storage in Nigeria is structurally stronger than the public conversation suggests. The International Energy Agency's most recent Net Zero by 2050 roadmap projects that CCUS will need to capture and store roughly 7.6 gigatonnes of CO₂ per year by 2050 — a 200-fold expansion from current capacity. The Global CCS Institute's annual status report tracks a project pipeline that is finally moving from feasibility studies into engineering, with more than 50 projects taking final investment decisions in the last three years. What is conspicuously absent from that pipeline is West Africa.

The absence is not geological. The Niger Delta has — by virtually any benchmark the CCUS literature uses — the kind of subsurface that the global storage portfolio is desperately short of. Declining gas fields with proven reservoir-seal pairs. Hundreds of kilometres of existing pipeline infrastructure. Decades of seismic data. An operator base with the engineering depth to drill, complete, and monitor wells in challenging environments. What is missing is the policy framework — and that, as we will argue, is fixable on a timeline that matters.

Why the Niger Delta geology is genuinely exceptional

CCUS at scale requires three things from the subsurface: storage capacity (large pore volume in a reservoir that can accept supercritical CO₂), seal integrity (a caprock that will hold the CO₂ on geological timescales), and injectivity (the rock has to actually accept fluid at a useful rate without fracturing). The Niger Delta delivers on all three with margin to spare. The Agbada Formation, the primary hydrocarbon-bearing sequence across the basin, is composed of interbedded sandstones and shales — the same architecture that has hosted the basin's gas production for sixty years, and the same architecture that the IPCC Special Report on Carbon Dioxide Capture and Storage identifies as ideal for long-term CO₂ sequestration.

The storage capacity numbers are large enough that they require careful framing to be useful. Independent estimates from academic groups and from the Nigerian Energy Transition Plan technical annexes place the theoretical storage potential at 30 gigatonnes or more — equivalent to roughly a century of Nigeria's current annual emissions. The practical, near-term storage capacity available in declining gas fields is much smaller, on the order of a few hundred megatonnes initially, but it is also exactly the right size for the first wave of capture projects: large enough to be economically meaningful, small enough to be characterised and consented in a project-by-project framework.

Depleted gas reservoirs vs. saline aquifers — and why the Delta has both

Global CCUS practice splits storage into two categories. Depleted hydrocarbon reservoirs — wells from which gas or oil has been produced — are attractive because the geology is already characterised, the wells are already drilled, and the existing seal has, by definition, held hydrocarbons for millions of years. Saline aquifers — porous rocks filled with brine — are attractive because they are vast (orders of magnitude more capacity than depleted fields globally) but the characterisation burden is enormous. The Niger Delta has both at scale. Initial deployment should target depleted gas fields. Long-term capacity is in the underlying aquifer system, and the seismic data needed to characterise it has been collected — over decades — by operators for unrelated reasons.

The North Sea precedent — Equinor's Sleipner project has been injecting CO₂ into the Utsira saline aquifer since 1996, with consistent monitoring data showing the plume behaving exactly as the reservoir models predicted — is the clearest indication that this is a solvable engineering problem in basin types comparable to the Niger Delta. The Norwegian Petroleum Directorate's CO₂ Storage Atlas is a model for the kind of pre-competitive subsurface characterisation that the Niger Delta now needs. Producing an equivalent atlas for the Delta is, in our estimate, a 24-month effort at modest cost relative to the size of the prize.

The Niger Delta has the geology of Sleipner and the operator base of the Gulf of Mexico. What is missing is not capability — it is a policy framework that lets operators invest in characterisation work whose payoff is denominated in storage tonnes, not barrels.

What the policy framework needs to do

The structural problem is that Nigerian petroleum law was written for hydrocarbon production. It does not — yet — recognise CO₂ storage as a class of mineral right, does not specify how subsurface pore space is allocated, does not address long-term liability for stored CO₂, and does not provide a permitting pathway for injection wells whose purpose is storage rather than enhanced oil recovery. Each of these gaps is solvable. None of them is solved.

The UK CCUS Cluster Sequencing Process and the US EPA Class VI well permitting framework are the two most mature regulatory templates available. They are not perfect — both have been criticised for slow permit cycles — but they are operational, and they provide a documented model that the Nigerian Petroleum Industry Act regulatory regime could adapt with relatively minor primary-legislation changes. The lift is not technical. The lift is political.

The economic case — and the carbon credit market

Without a price on carbon — explicit or implicit — CCUS does not pencil out anywhere. The cost of capture-plus-transport-plus-storage for a Niger Delta gas-processing facility is, on current technology, in the range of USD 60–110 per tonne of CO₂. The EU Carbon Border Adjustment Mechanism, now in its definitive phase, will price embedded carbon in imports at the prevailing EU ETS carbon price — currently around EUR 70/tonne. That is, finally, in the range that makes Nigerian CCUS economically viable for hydrocarbon producers selling into European markets.

The same logic applies to the Voluntary Carbon Market, where the Core Carbon Principles published by the Integrity Council are converging on a standard that high-quality CCUS credits should be able to clear. The 2024 VCM Market Report from Ecosystem Marketplace shows that engineered removals — of which CCUS is the canonical example — already trade at a premium to nature-based credits, on the basis that the additionality, permanence, and measurability arguments are substantially stronger. For Nigerian operators with existing gas processing, the unit economics of capture-plus-storage start to clear once the credit price reaches USD 75/tonne. That threshold is no longer hypothetical.

What needs to happen in the next 24 months

Three things define whether Nigerian CCUS reaches first commercial injection by 2030 or by 2040. First, the policy gap needs closing. The Nigerian Energy Transition Plan commits to CCUS as a pillar of the 2050 net-zero pathway but does not yet have the implementing regulations or permitting infrastructure to support project development. The required legislative changes are modest in scope; the obstacle is bandwidth, not complexity. We expect — and advocate for — a CCUS-specific implementing regulation under the PIA within the next 24 months.

Second, the subsurface characterisation work needs to start at a pre-competitive level. The Norwegian model — government-funded, operator-contributed, openly published — is exactly the right template. The data exists, scattered across operator vaults from forty years of exploration. Pulling it into a unified national CO₂ storage atlas requires coordination, not new science. Hwodye Energy is participating in pre-competitive workstreams of this kind through our Energy Transition research portfolio, and we welcome operators and ministries interested in formalising the effort.

Third, the operator base that currently produces hydrocarbons in the Delta needs to start treating CCUS not as a side-project but as a portfolio-level capital allocation question. The skills that produced gas from these fields — seismic interpretation, drilling, completion, reservoir surveillance — are the same skills the storage phase requires. The institutional knowledge is on the ground. The question, for the operators reading this, is whether the next decade of capital allocation reflects the structural change in the energy economy or fights it. If you operate in the Niger Delta and want to engage with Hwodye Energy on CCUS-screening analytics or pre-competitive characterisation work, we are open to that conversation.