Three July developments, and the gap between building things and running them
A pipeline six years late got finished. A regulator and eleven distribution companies went to war over money. And the most interesting energy business in the country signed a deal that routes around the grid entirely.
Oilserv completed its 303 km section of the Ajaokuta-Kaduna-Kano gas pipeline in mid-July, taking the 614 km, $2.8 billion project past 90% completion (Billionaires Africa).
First gas is targeted for Abuja. The pipeline can move more than 2.2 billion cubic feet a day, aimed at the thermal plants in Kaduna, Kano, and the FCT that have been starved of fuel.
We flagged AKK in Issue 05 as a medium-confidence watch item. It landed.
NERC's Order No. 2026/062 took effect on 1 July, requiring DisCos to ring-fence 70% of surplus operating revenue for capital expenditure. Those carrying market debt face a harder split: 35% CapEx, 25% NBET, 25% Market Operator, 15% retained.
The Association of Nigerian Electricity Distributors rejected it within two weeks as regulatory overreach (BusinessDay). State regulators pushed back separately (Nairametrics).
MOPO signed a $75 million agreement with the Rural Electrification Agency to scale battery rental nationwide, with a pilot launching in December (Bloomberg). The Octopus Energy-backed company has completed over 32 million rentals across six African countries.
Why this matters
AKK will not change your generator bill in 2026. If it delivers gas on schedule, northern thermal plants gain fuel through 2027, which is when supply reliability might improve in Kano, Kaduna, and the FCT. Plan on the current position, not the announcement.
The CapEx Order is the month's most consequential decision, not the pipeline. It determines whether distribution networks get rebuilt or simply refinanced. If it survives challenge, it becomes the template for forcing investment the market has declined to make voluntarily.
Regulatory risk in Nigerian distribution just rose. A regulator willing to direct how private operators allocate revenue is a different counterparty than one setting tariffs. Price that into any DisCo-adjacent position. Assets that bypass DisCos entirely, like MOPO's, now carry a structural advantage.
Nigeria is better at building infrastructure than at running the commercial system that pays for it. AKK is a genuine achievement after six years and multiple missed deadlines. It also arrives in a market where two thirds of existing plant sits idle and collection efficiency is falling. More gas into a system that cannot bill for what it already delivers moves the constraint rather than removing it.
Watch the CapEx Order, not the pipeline.
Nigeria is paid for one megawatt in every five and a half it built
The Pulse reports the same chain every month, because the individual numbers only mean something in sequence. Capacity becomes availability, availability becomes dispatch, dispatch becomes a bill, and a bill becomes cash. Each stage leaks, and the leaks multiply.
The cascade, stage by stage
ATC&C = 1 − (billing efficiency × collection efficiency), billing efficiency is (1 − 0.3744) ÷ 0.7895 = 79.24%. That figure is not published anywhere, and it is the one that matters most.
Two leaks of almost identical size
Energy delivered that becomes a bill
Bills issued that become cash
The other 37.44% is ATC&C loss
This is the finding worth carrying forward. Roughly 21% of energy is never billed, and roughly 21% of what is billed is never paid. Two failures of near-identical size, in different parts of the business, run by different teams.
They compound rather than add. Fixing collection alone takes recovery from 62.6% to 79.2% at best, and the metering half of the problem is untouched. The sector debates tariffs and collection constantly. The unbilled half attracts far less attention and is worth the same money.
Each of these numbers gets reported on its own, and on its own each one looks survivable. In sequence they are not. A megawatt has to clear five gates to earn anything, and Nigeria clears about 18.6% of them.
It also identifies which repair is worth most. Restoring gas supply attacks a 68.5% loss. Every downstream fix competes for a share of a much smaller remainder.
Stage one: why gas sets the ceiling
Put the two together and the ceiling is visible. Gas carries 78% of generation while arriving at 43% of what plants need, so the fuel that dominates the mix is the fuel in shortest supply. Availability cannot exceed what the gas allows.
Hydro does not diversify this. Kainji, Jebba and Shiroro sit on the same river system, so a dry season weakens hydro and gas-fired output at once rather than offsetting.
AKK targets the 929 mmscfd shortfall directly. If the pipeline delivers, stage one of the cascade should move and availability should climb above 31%.
If gas arrives and availability does not move, the constraint was never really gas, and a decade of sector explanation needs rewriting. That makes AKK the most informative thing to watch in Nigerian power, whichever way it resolves.
Stage one has been getting worse, not better. Availability ran at 40% in October and 31% in April, so the top of the cascade narrowed by a quarter over seven months. Every downstream efficiency gain in that period was working against a shrinking input.
Stages four and five: the same regulator, twice the performance
| DisCo | Collection efficiency, Q1 2026 |
|---|---|
| Ikeja | 90.00% |
| Eko | 89.64% |
| Benin | 85.16% |
| Port Harcourt | 81.22% |
| Abuja | 80.90% |
| National average | 78.95% |
| Kaduna | 45.81% |
The spread carries more information than the average. Ikeja collects roughly twice as efficiently as Kaduna under the same regulator, the same tariff methodology, and the same wholesale market.
If every DisCo collected at Ikeja's 90.00%, Q1 revenue would have been ₦681.2bn rather than ₦597.6bn. That is ₦83.7bn in a single quarter, from operational practice alone, with no tariff increase and no new generation.
Annualised, it approaches ₦335bn. For comparison, Series 2 of the Presidential Power Sector Debt Reduction Programme raised ₦729bn. Roughly half of that borrowing is sitting inside the DisCos as a performance gap.
That reframes the CapEx Order standoff. NERC is arguing with the DisCos about how surplus revenue gets spent, while the larger number is the revenue that never arrives.
The cascade in context
Normalised per person, Vietnam has roughly 42 times Nigeria's available electricity. Ghana, with a population one seventh the size, dispatches more power in absolute terms.
Nigeria's 19.5 W per person is the number after the cascade has run. Measured on installed capacity it would be 62 W.
That second figure makes the country look merely poor rather than structurally broken. The difference between the two is the subject of this page.
Nigeria has 11 Distribution Companies. They buy electricity in bulk from the national grid and deliver it to homes and businesses in their territory, functioning as regional electricity retailers.
They own stages four and five of the cascade, which is where roughly 37% of the value disappears.
Read the stages together and the sector's own framing looks misdirected. Availability ticked up to 31% while collection slipped to 78.95%, and both movements are rounding errors against a chain that converts 18.6% of built capacity into cash. The most useful number this quarter is one nobody published: billing efficiency at 79.2%, which says the unbilled problem is the same size as the uncollected one and receives a fraction of the attention. Gas remains the largest single loss, and AKK is the live test of whether it is the binding one. But even a fully fuelled fleet still hands its output to a commercial chain that loses 37% of the value, and no instrument currently in force changes that.
If Q2 collection falls below 78%, the CapEx Order becomes unenforceable in practice, because there will be no surplus revenue left to ring-fence.
Nigeria added 803 MW of solar last year. The 2050 plan needs 209,000 MW.
That is not a gap in ambition. It is a gap in arithmetic, and no amount of policy enthusiasm closes it at the current rate.
Total installed solar sits at roughly 1,019 MW (Global Solar Council). The Energy Transition Plan targets 30% renewables by 2030, 82% by 2050, and net zero by 2060, with solar carrying most of the load.
At 2025's build rate, reaching it takes roughly two centuries.
Closing that gap requires sustained annual deployment 30 to 40 times the 2025 rate, every year for a quarter century. Nigeria has never sustained that rate in any energy technology.
Ten plants out of 28 produced 81% of output in April (AllAfrica). Wind remains frozen at 6 MW. Transmission carries roughly double what generation delivers, so the binding constraint is upstream of the wires.
Five questions an analyst asks
Partly, and only in the north. AKK feeds thermal plants in Kaduna, Kano, and the FCT. Plants in the south-west and Niger Delta draw from different infrastructure and stay exposed to the same feeder-pipeline vandalism. Expect a regional improvement, not a national one.
Yes. TCN wheeling capacity of 8,800 MW is roughly double current dispatch. The system has headroom for available generation to double before transmission becomes the constraint. That is a rare piece of good news in Nigerian power.
This is the real question. At 78.95% collection and 37.44% ATC&C losses, roughly a third of any additional electricity delivered generates no revenue. More supply into an unfixed commercial chain increases the sector's losses in absolute terms.
Not at current metering levels. The rule permits generation up to 100 kW on simple registration, with no licence required. Without bidirectional meters and a settlement mechanism, surplus power has no price and no buyer.
The same 2026 Mini-Grid Regulations raise isolated mini-grids from 1 MW to 5 MW and interconnected mini-grids to 10 MW. That ceiling increase matters more than the 100 kW rule, because it lets a single mini-grid serve an industrial cluster rather than a village.
Metering, then tariffs, then supply, in that order. The 5,000 installers being trained from 220,000 applicants is the most consequential programme in the sector precisely because it is the precondition for everything downstream.
Counterarguments and concerns
Completion is not commissioning, and commissioning is not throughput. The pipeline can move 2.2 bcf/d, but that depends on upstream gas being produced, processed, and contracted. Nigeria's constraint has often been commercial rather than physical.
A debt-carrying DisCo retaining 15% of surplus revenue for operations is running thin. The DisCos' argument that this could impair service delivery is not obviously wrong, and NERC has not published modelling to rebut it.
15 states now regulate their own markets under the Electricity Act 2023. Tariff-setting authority over grid-connected assets is contested and will likely reach the courts. Investors face two regulators with different answers.
Assets that bypass the DisCo billing relationship carry a structural advantage in Nigeria right now. MOPO's battery rental, captive solar, and Eligible Customer bilateral contracts all avoid the point where a third of value leaks. Underwrite the commercial chain, not the megawatts.
The 2060 target is not failing on capital or ambition. It is failing on the sequence. Metering enables billing, billing enables cost-reflective tariffs, tariffs enable investment, investment enables supply. Nigeria has repeatedly attempted step four before step one.
Nigeria will not hit its 2050 solar target, and continuing to publish it unrevised costs the ETP credibility with the investors it needs.
A stated target of 20,000 to 30,000 MW by 2040, backed by a metering and tariff sequence, would be more useful than 209,000 MW backed by nothing. Watch whether the next ETP revision adjusts the number or defends it.
Three things you can do without waiting for policy
You cannot fix the grid. You can cut what you spend on energy and reduce your dependence on diesel.
At diesel around ₦1,600 to ₦1,800 per litre, a 5 kVA generator running 10 hours daily costs roughly ₦490,000 a month in fuel alone. A properly sized solar-plus-battery system typically pays back in 2 to 3 years.
Confirm your DisCo's metering position before sizing a system around export revenue.
Saves ₦200,000 to ₦400,000/monthLEDs use 70 to 80% less electricity. Twenty traditional bulbs running 8 hours daily draw about 2.4 kWh. The same lighting in LED draws under 0.5 kWh. Every kilowatt-hour saved while running on a generator is money straight back. Start with whatever runs longest.
Cuts lighting costs by up to 80%Air conditioning is typically 40 to 60% of electricity use in Nigerian offices and homes. Each 1°C on the set-point changes energy use by roughly 6%, so 18°C to 24°C cuts consumption around 36%.
On generator power that is ₦15,000 to ₦30,000 a month for a medium office. A ceiling fan at 24°C delivers the same comfort for far less.
Cuts AC costs by up to 36%
Nine entities moving Nigeria's energy picture in July
A pattern runs through most of them: private capital entering through side doors, because the front door does not work.
Completed its section of the 614 km corridor in mid-July, six years after conception and after missed deadlines in 2023 and Q4 2025. Capacity exceeds 2.2 bcf/d, targeting northern thermal plants and the Kaduna and Kano fertiliser industries.
Battery rental at national scale. Over 32 million rentals across six African countries, roughly 1 million a month, with 300% year-on-year revenue growth.
Batteries charged at solar hubs, rented per swap, no contract or deposit. The model skips generation, transmission, and distribution, and with them every point where the system leaks revenue.
Requires 70% of surplus operating revenue into ring-fenced CapEx accounts, or a 35/25/25/15 split for DisCos carrying market debt. Rejected within two weeks as regulatory overreach. NERC's position is that it corrects underinvestment the market declined to fix voluntarily.
A public-private partnership with MD Nwakamma Nigeria Limited and Chinese technical partners to manufacture panels and accessories domestically (Nairametrics). Import dependence inflates installed costs across West Africa. This is the first serious state-level attempt to attack that.
A 44:1 application ratio, which says as much about the labour market as the programme. Metering is the precondition for cost-reflective tariffs: without accurate measurement, DisCos cannot bill what they deliver and the subsidy stays a political estimate rather than an auditable figure.
The Renewable Energy Association of Nigeria was strategic partner to the country's first Solar & Storage Live, where the industry's own framing shifted from generation toward storage as equipment costs fall (ThisDay).
REAN pressed two points from the platform. Nigeria needs far more private investment to hit its renewable targets, and substandard imported solar needs removing through certification, installer competency standards, and enforcement (Vanguard). The association agreed closer collaboration with NERC in June.
REAN targets renewables at 40% of the national energy mix by 2030. The Energy Transition Plan says 30%. Two headline numbers, from two bodies that have just announced they are working together.
Guidelines on the Technical Audit of the Transmission System and Network Data Validation took effect 20 July (Daily Post).
Validated network data is the unglamorous precondition for knowing what the grid can carry. Nigeria has planned transmission investment for years against numbers nobody independently verified.
Oseni urged federal and state actors to end regulatory rivalries, warning that institutional competition could derail the Electricity Act 2023's gains (Guardian Nigeria).
A regulator publicly warning that regulators are the problem is unusual. It also lands in the same month NERC issued an order that state commissions and eleven DisCos all objected to.
The second tranche of the Presidential Power Sector Debt Reduction Programme, settling verified legacy debts to generation companies and gas suppliers (Nairametrics). The first coupon, due 14 July, was paid on time.
Two tracks are running in parallel and not converging. Public capital is repairing the existing system's balance sheet through the bond programme. Private capital is building around it. Nobody is funding the DisCo layer between them, which is where the losses sit.
The most telling fact this month is that the two most credible private deals, MOPO's $75 million and Abia's $145 million, both avoid the grid. When serious capital consistently routes around your central infrastructure, that is a market verdict on the infrastructure, not a coincidence.
If the CapEx Order fails and distribution stays unreformed, expect the next three deals to look the same.
Three ways the CapEx Order standoff resolves
The outcome sets distribution investment for the next 18 months. Probabilities are our assessment, not a market consensus.
| Variable | Order upheld · 45% | Negotiated revision · 40% | Order struck down · 15% |
|---|---|---|---|
| Regulatory outcome | NERC enforces 70% and 35% splits as issued. DisCos comply under protest. | Thresholds cut, phase-in extended, consultation reopened under Electricity Act provisions. | Courts or the Senate void the order on consultation grounds. |
| DisCo response | CapEx spending rises. Operating margins compress. Equity raises get harder. | Moderate CapEx uplift. Investor relations stabilise. | Status quo. Distribution networks continue to degrade. |
| ATC&C trajectory | Losses begin falling within 12 to 18 months. Below 30% by late 2027 is plausible. | Slower improvement. Losses around 33 to 35% through 2027. | Losses hold near 37% or drift higher. |
| Investment signal | Regulatory risk repriced upward, but direction of travel is clear. | Predictability preserved. Best outcome for new entrants. | Federal Government needs a new mechanism. ₦4trn programme recapitalises a leaking chain. |
The ₦159 billion that never arrived
DisCos billed ₦756.93 billion in Q1 and collected ₦597.56 billion. The difference is the sector's actual problem, and it grew.
Collection efficiency is the share of what a DisCo bills that it actually receives in cash. ATC&C losses combine electricity lost in the wires, electricity stolen, and electricity billed but never paid for.
A cost-reflective tariff is one set high enough to cover the full cost of supply plus a regulated return.
Collection efficiency fell from 79.36% in Q4 2025. Losses run at more than double the MYTO target, producing a cumulative revenue loss of roughly ₦140.6 billion over the quarter (The Whistler).
The subsidy is falling for the wrong reason
Spending fell 14%. NERC attributes the decline to lower electricity offtake by DisCos, not improved tariff recovery (Vanguard).
A subsidy that shrinks because less power moved is not a reform result. It is a demand result wearing a reform badge.
Roughly 45% of the market now sits on cost-reflective tariffs linked to service bands. Customers in Bands B through E, receiving 16 hours of supply or less, face rising bills as subsidies phase out.
Nigeria is measuring subsidy reduction as an outcome when it is an input. The useful metric is subsidy per kilowatt-hour actually delivered and paid for. On that basis Q1 shows no improvement at all, and the headline decline is misleading.
Collection efficiency going backwards while the CapEx Order demands ring-fenced surplus revenue is a direct contradiction the sector has not acknowledged. You cannot ring-fence a surplus that is shrinking.
If Q2 collection lands below 78%, NERC will be enforcing an order against companies with nothing left to allocate, and the standoff resolves itself by arithmetic rather than by law.
Six multi-year programmes, and what actually moved
Nigeria announces more electrification programmes than it completes. This tracker carries month to month, so a target set in one issue can be checked against delivery in the next. Progress is measured against verified commissioning or disbursement, not against announcements.
First, the capacity figures do not reconcile: AfDB states 36.5 MW across eight universities, while REA's own programme page lists solar at 11 MW and gas at 8.5 MW, totalling 19.5 MW. Second, the word "activation" is doing heavy lifting.
UNIPORT's announcement describes a test-run, not a commissioning, and omits the capacity. Where a programme reports milestones in language that cannot be audited, we count the conservative reading and say so.
Read the tracker as one picture and a pattern appears. The programmes moving fastest are the ones settling balance sheets, not the ones building infrastructure. The debt programme is 30.8% mobilised. EEP Phase III has confirmed one commissioning of eight and is already past its original Q4 2025 target, while Phase IV has been announced over the top of it. Nigeria is better at approving programmes than sequencing them.
Watch whether Phase IV reaches financial close before Phase III finishes, because if it does, the same delivery capacity is being asked to do twice the work.
AKK lands after six years. Now the harder part.
Completing a pipeline is an engineering problem, and Nigeria has just solved one. Filling it, and billing for the electricity it enables, are different problems entirely.
The 614 km Ajaokuta-Kaduna-Kano corridor was conceived in 2008 and has missed delivery targets in 2023 and Q4 2025. Oilserv's completion of its 303 km section in mid-July puts the $2.8 billion project past 90%, with first gas targeted for Abuja.
Capacity exceeds 2.2 bcf/d. Against a national thermal shortfall of roughly 929 mmscfd, that is more than enough gas on paper to close the gap.
On paper.
Gas shortages create a counterintuitive climate problem. When the grid fails, households and businesses switch to diesel, which emits roughly 2.7 kg of CO2 per litre and more per kilowatt-hour than gas-fired grid power.
Nigeria's estimated 90 million generators are among the largest untracked emission sources in sub-Saharan Africa. Fixing grid gas supply is an emissions intervention as much as an economic one.
AKK removes the excuse, which is more useful than it sounds. For a decade, gas supply has been the answer to why Nigerian plants sit idle.
If gas arrives through 2027 and availability stays near 31%, attention moves to maintenance backlogs, contracting, and the commercial chain, where it should have been. Watch first-gas date and northern plant availability together. If one moves without the other, the constraint was never really gas.
The lithium plant is real. The value chain is not yet.
Nigeria commissioned West Africa's largest lithium processing facility this month. It is a genuine policy result and a useful test of what beneficiation rules actually deliver.
President Tinubu, represented by Vice President Kashim Shettima, commissioned the Diamond New Energy plant at Endo in Nasarawa State in early July. The facility carries a $250 million price tag and processes 6,000 tonnes of ore a day, roughly 3 million tonnes a year.
Operators report more than 1,000 direct jobs and over 2,000 indirect. Nasarawa State Governor Abdullahi Sule pitched the state's proximity to the Federal Capital Territory as part of the draw.
The plant did not appear by accident. Abuja banned raw lithium ore exports in 2022, then extended the ban in 2023 to unprocessed nickel, chromium, manganese and tantalite, exempting only firms that build processing capacity in country.
Solid Minerals Minister Dele Alake framed the commissioning as vindication of that policy. His stated destination is a full chain: batteries, electric vehicles, phones and solar panels made in Nigeria.
Now the part that is harder to say at a ribbon cutting.
The plant was built by the Chinese firms Juling and Canmax, operating through Diamond New Energy, and the same partnership runs a second facility in Ogun State. The structure is the one found across the continent: Chinese capital, Chinese technology, intermediate output.
The output specification has not been made public. Whether Endo yields battery-grade lithium chemicals or a concentrate bound for Chinese cell makers is the difference between an industrial policy and a shorter export route, and it is not currently on the record.
Mineral processing is electricity-intensive, and Nigeria's constraint is electricity. A plant running 6,000 tonnes of ore a day needs firm supply that the grid does not reliably provide at 4,286 MW available capacity.
Watch how Endo is powered. If the answer is captive generation, the plant is a demonstration that industrial investment now routes around the grid rather than waiting for it. That is the same conclusion the off-grid operators reached, arriving from the opposite direction.
Nigeria did the thing most resource economies never do, which is write a rule and then hold it long enough for capital to respond. Four years from export ban to commissioned plant is fast by any standard, and the jobs are real. Be careful what is being claimed, though. Beneficiation moves where value is added, not who captures it, and on ownership this plant looks like the DRC rather than a departure from it.
Two things to watch by Issue 08: whether the output specification is published, and whether any Nigerian firm takes an equity position in the next facility. Until one of those moves, the country has bought a shorter export route at $250 million, not a value chain.
Does Nigeria have enough capacity if only the grid worked better?
"Nigeria has 13,625 MW installed. Fix the grid management problem and everyone gets 24/7 electricity."
Common in political speeches and on social media. It implies the hardware exists and only management is failing.
13,625 MW is nameplate capacity: what plants could produce with unlimited gas, full maintenance, and perfect conditions. Actual available generation is about 4,286 MW, because gas covers roughly 43% of thermal requirement, many plants sit in maintenance arrears, and some were never fully commissioned.
Fix every management problem overnight and gas supply would still cap output well below nameplate. 13,625 MW is what Nigeria paid to build. 4,286 MW is what it can currently use.
Seven signals that move the picture by Issue 07
| Signal | Confidence | Basis |
|---|---|---|
| Oilserv completes AKK section | High | Announced mid-July, multiple sources |
| NERC CapEx Order in force | High | Order published, effective 1 July |
| ₦729bn Series 2 bond launched | High | Launched 21 July, first coupon paid |
| AKK first gas delivered to Abuja | Medium | Target credible, six-year delay history |
| CapEx Order survives challenge | Medium | DisCos and state regulators both opposing |
| Q2 collection efficiency direction | Medium | Q1 fell to 78.95%. Trend unclear |
| Federal-state jurisdiction resolved | Low | 15 state regulators, no coordination framework |
Completion is not commissioning. Track NNPC notices through Q3. Slippage past Q4 pushes relief into dry-season peak demand, when it is least useful.
Whether ANED files formally, and whether state regulators join. The single most consequential regulatory question in Nigerian power this year.
Q1 fell to 78.95% from 79.36%. A second consecutive decline would make the CapEx Order unenforceable in practice.
Whether the $75 million REA agreement produces connections on schedule. The clearest test of whether bypassing the grid scales in Nigeria.
September 2026 target. Nigeria has a long record of announced manufacturing that never breaks ground.
Seven of eight universities still to commission against an original Q4 2025 target. Whether Phase IV reaches financial close before Phase III completes is the tell on delivery capacity.
412 mini-grid RFPs issued, no awards yet reported. The largest mini-grid procurement in Nigerian history by project count.
Whether REAN's push for certification, installer competency standards, and removal of substandard imports produces an actual regulatory instrument, or stays an industry position paper.
Senate handling through Q3 determines whether federal and state tariff authority gets clarified or litigated.