The Nigerian lens on October's energy story
₦729 Billion Starts Moving,
Energy Inflation Doubles,
and Losses Fall Two Points
NBET began settling ₦729 billion owed to generators and gas suppliers. In the same month energy inflation more than doubled to 10.85% and outages hit Lagos and Abuja. Distribution losses fell to 36.23%, which is progress, and still 19.31 points above the regulator's own target.
Money Moved, Service Did Not
Three developments defined October, and the third undercuts the first two.
The Nigerian Bulk Electricity Trading company started disbursing against legacy debt to generation companies and gas suppliers on 9 October (Nairametrics). It is the first substantial movement on sector arrears in months.
The National Bureau of Statistics put September energy inflation at 10.85%, more than double the prior reading (via Nairametrics, 15 October). Nigeria also recorded the world's largest diesel price increase this year at 82.7%.
Outages hit parts of both cities in mid-October, with distributors pointing upstream to grid shortfall rather than to their own networks (Nairametrics, 19 October).
Rank them plainly. The arrears settlement is the most consequential, because unpaid generators cannot buy gas, and gas supply is the binding constraint on how much power the grid can carry at all.
GenCos generate electricity. TCN moves it across the country on high-voltage lines. DisCos deliver it to your meter and collect your money. NERC is the federal regulator, though about 15 states now regulate their own markets.
Nigeria has 13,625 MW of generating plant on paper and delivers roughly 4,300 MW. It is a 13-lane motorway with four lanes open.
Do not re-budget on the arrears payment. Energy inflation at 10.85% and diesel up 82.7% are the numbers that hit your next quarter. Price backup fuel into contracts now rather than absorbing it later.
Sequencing matters more than size. Paying arrears without fixing gas supply buys one quarter of goodwill. The order is gas contracts, then generation availability, then tariff, then collection.
Reprice distribution risk downward, slightly. Collection at 81.06% is the second consecutive quarterly improvement. The northern distributors remain uninvestable on these numbers, and the Lagos pair are not.
October paid old bills and delivered no new electricity. That is not nothing, because the arrears were blocking gas purchases. It is not reform either.
One metric settles whether this was a turning point. Watch whether generation available to the grid rises above 5,000 MW on a sustained monthly average before the end of Q1 2027. If it does not, the ₦729 billion cleared a balance sheet and nothing else.
What Nigerian Reporting Carried in October
Seven stories from the Nigerian desk, ranked by consequence rather than by date. The regulator publicly questioning a World Bank allocation leads.
NERC chairman Musiliu Oseni told the Nigeria Energy Exhibition in Lagos that half the $750 million DARES fund should move from off-grid rural electrification to transmission and distribution bottlenecks serving industrial centres. DARES targets 17.5 million people through 1,350 mini-grids (ThisDay).
A regulator publicly asking a lender to redirect an approved programme is unusual. It is the most consequential thing said in Nigerian power this month.
Oseni's supporting number is stark. Lagos needs 1,300 to 1,400 MW on a normal day and receives about 700 MW, which he attributes to transmission tripping rather than to distribution.
Source: ThisDay →Algerian foreign minister Ahmed Attaf told Sergey Lavrov in Moscow on 27 October, the day before the Russia-Africa summit, that Algeria is negotiating to bring Russian companies into the Trans-Saharan Gas Pipeline and that the parties are adding final touches to an agreement.
No company has been named, no contract has been signed, and Sonatrach had announced nothing as of 2 November. Gazprom held similar talks in 2008 and 2009 that produced no participation. Treat this as a stated negotiation, not a deal.
The pipeline itself is real and moving. It runs 4,128 km from Warri through Niger to Hassi R'Mel, carrying 20 to 30 billion cubic metres a year at an estimated $10 to $13 billion.
NNPC and Sonatrach hold 90% of the operating company between them, with Niger's government on 10%.
At the same event, the Manufacturers Association of Nigeria said more than 30% of members have already moved off-grid and a further 25% plan to.
Members spent over ₦1.3 trillion on self-generated energy in 2025. MAN put the Band A tariff rise at ₦68 to ₦209 a kilowatt hour, above 230% (ThisDay).
Set that ₦1.3 trillion against the ₦1.37 trillion this page calculates is lost annually to ATC&C.
Nigerian industry now spends roughly as much escaping the grid as the grid loses in uncollected value. Two halves of one problem, and the creditworthy customers are the ones leaving.
Source: ThisDay / MAN →
Available capacity averaged 5,038 MW in September, up 5.89% on the month, while average generation fell 0.30% to 4,089 MW. The weakest load factors were Okpai at 68% and Odukpani at 70%. A transmission tower collapsed in Nasarawa State on 7 October (Vanguard).
Availability rising while generation falls is the signature of a dispatch and fuel constraint, not a plant constraint. About 949 MW sat available and unused on average, which is more capacity than Enugu and Yola distribute between them.
Source: Vanguard →Distributor complaint units logged 92,407 complaints in Q2 2026, taking the half-year total to 184,024. Metering, billing and service interruptions were the most common.
Output fell 37.17% in a single day to 3,885.72 MW, against a peak of 5,330 MW in August and September (NISO via Vanguard).
The complaints number is the one to keep. It is the only published measure of service quality that comes from customers rather than from the companies being measured, and metering sits at the top of it while roughly 5.1 million customers remain unmetered.
Source: Vanguard →Shell agreed to sell its entire interest in Shell Nigeria Gas, which runs domestic gas distribution, to the Nigerian company Vaaris Energy (Nairametrics).
Domestic gas distribution is the least visible link in the power chain and one of the most important, because thermal plants receive roughly 43% of the gas they need.
A transfer from a major to a local independent repeats this month's upstream pattern. It also moves counterparty risk onto a balance sheet facing less external reporting.
Source: Nairametrics →Governor Babajide Sanwo-Olu set a target of 3,000 MW of electricity supply for Lagos by March 2027 (Nairametrics). Lagos regulates its own market through LASERC under the 2023 Electricity Act.
Read it against NERC's own number from the same month. Oseni put Lagos demand at 1,300 to 1,400 MW, with about 700 MW arriving.
A target of 3,000 MW is more than four times current delivery and roughly double stated demand, with no published build schedule. Marked as a projection.
Source: Nairametrics →Two numbers from the same Lagos conference tell the month's story. Manufacturers spent ₦1.3 trillion leaving the grid in 2025, and the regulator wants half of a $750 million access fund redirected to the transmission that would keep them on it.
If the World Bank agrees to resplit DARES before the next facility review, Nigeria will have conceded that industrial supply quality now outranks rural access in its own regulator's priorities. Watch whether the REA or the World Bank responds publicly.
The System in Numbers
Capacity on paper against capacity on the grid, MW
Sources: NERC installed capacity and TCN wheeling reference figures; NISO September 2026 availability and generation via Vanguard. Bars scaled against installed capacity.
Available capacity rose 5.89% in September while generation fell 0.30%. About 949 MW of available plant went unused on average, which is a dispatch and fuel question rather than a capacity one.
Gas required against gas delivered, million standard cubic feet a day
Source: NERC reference figures for thermal plant gas requirement and delivery.
Thermal plants receive roughly 43% of the gas they need. This single ratio explains most of the gap between installed and available capacity.
Generation mix
Source: NERC reference figures for the Nigerian generation mix.
A grid this gas-weighted inherits every gas supply failure directly. Installed solar stands at roughly 1,019 MW against a 2050 target of 209,000 MW.
ATC&C losses by distributor, Q2 2026, against each company's own target
Source: NERC Q2 2026 report, reported via Leadership. Bars scaled against Kaduna, the worst performer. Dashed line marks the 16.92% national MYTO target.
Every distributor missed its own target. The four worst are all northern, and Kaduna loses more than two thirds of the value entering its network.
| DisCo | ATC&C actual | Own target | Gap, points |
|---|---|---|---|
| Kaduna | 67.70% | 18.18% | 49.52 |
| Jos | 61.30% | 20.80% | 40.50 |
| Kano | 60.43% | 17.45% | 42.98 |
| Yola | 54.04% | 29.00% | 25.04 |
| Ibadan | 40.03% | 17.50% | 22.53 |
| Enugu | 36.80% | 18.08% | 18.72 |
| Benin | 33.84% | 17.23% | 16.61 |
| Abuja | 32.31% | 16.97% | 15.34 |
| Port Harcourt | 29.60% | 16.67% | 12.93 |
| Ikeja | 25.12% | 13.54% | 11.58 |
| Eko | 21.00% | 14.19% | 6.81 |
| National | 36.23% | 16.92% | 19.31 |
Losses fell 1.21 points and collection rose 2.11 points quarter on quarter. Both move the right way. Neither changes the structure, because the four northern distributors losing more than half their value are the same four as last quarter.
Watch one thing. Whether Kaduna, Kano, Jos or Yola posts a single quarter below 50% ATC&C before the end of 2027.
2060 Target Check
Nigeria's net zero target is 2060. The solar component requires installed capacity to reach 209,000 MW by 2050, from roughly 1,019 MW today. That is a multiple of about 205.
In 2025 Nigeria added 803 MW of solar, its strongest year. Hold that rate and 2050 arrives with about 21,000 MW, around a tenth of target.
Solar: today, the current trajectory, and the 2050 target, MW
Sources: NERC and TCL reference figures for installed solar and the 2050 target. The trajectory figure is TCL's calculation, holding the 2025 addition rate of 803 MW a year flat to 2050.
The gap is not a funding gap of some percentage. It is an order of magnitude, and it will not close through annual increments.
Five questions an analyst asks
- Is 209,000 MW a plan or an aspiration? No published annual build schedule supports it.
- Who connects it? TCN wheels about 8,800 MW today. The target implies a transmission system more than twenty times larger.
- What does it cost, and in whose currency? Modules are dollar-denominated, revenue is naira.
- Does it count distributed solar? The roughly 5.1 million unmetered customers are invisible to any registry that would record it.
- Which institution owns delivery? No single body is accountable for the 2050 figure.
Counterarguments and concerns
The fair objection is that targets are directional and nobody expects linear delivery. Distributed solar also scales without grid connection, so transmission need not constrain all of it.
Both points hold. Neither produces a build rate anywhere near 8,000 MW a year, which is what the target requires from here.
Treat 209,000 MW as a statement of ambition, not a pipeline. The checkable number is the annual addition. If Nigeria does not clear 2,000 MW added in a single year before 2030, the 2050 figure stops being a target and becomes a label.
Three Things Worth Doing This Month
Each one is checkable this week. None needs a new tariff order.
Band A customers pay a cost-reflective tariff for a promised 20 hours a day. If supply falls below the band commitment, the distributor owes a reclassification.
Lagos regulates its own market. LASERC established complaint panels in October, and LASCOPA resolved 528 complaints against Ikeja Electric in the same month.
This month's Deep Dive models the switch. Petrol generator power costs many times the Band B tariff, so the payback turns on how many hours a day the generator runs.
Who Is Executing
Six named actors moved in October. Each entry states the checkable follow-through rather than the announcement.
Began disbursing against ₦729 billion owed to generation companies and gas suppliers on 9 October. The checkable follow-through is whether gas deliveries rise in Q1 2027.
Signed with Siemens Energy for three generator transformers on 24 October, after a sharp first-half revenue decline. A reliability investment made from a weakened position.
Secured $200 million for a 100 MW solar project on 9 October. Sub-national procurement is now a real route to capacity under the 2023 Electricity Act.
Construction began on 16 MW of mini-grids, with 1 MW of solar commissioned in Gombe on 18 October. Commissioned capacity is the number that counts here, not the start of construction.
Established complaint resolution panels in October. Lagos is one of roughly 15 states operating outside NERC's jurisdiction under the 2023 Act.
Cleared the final $100 million of ExxonMobil acquisition debt and announced 157 billion cubic feet of gas on 29 October. Domestic gas is the supply side of the power problem.
Announced, Energised, Commissioned
Nigeria announces more electrification programmes than it completes. This tracker measures verified commissioning or disbursement. It never counts announcements.
Commissioned means formally handed over, with capacity stated and independently reported. It fills the bar solid.
Energised means power is flowing but delivery is not formal, or capacity is unstated. It renders hatched and is excluded from the headline percentage. Announced gets no bar at all.
One programme moved in October, and it moved at the announcement stage.
If NBET's settlement is confirmed received by a named generator before the end of Q1 2027, the arrears programme becomes the first here to convert a target into a disbursement. If it is not, it joins the others.
The Money That Never Arrives
"Can we determine NERC's annual loss to ATC&C?"
Thank you for asking. For every ₦100 of electricity entering Nigeria's distribution network, only ₦64 is collected. On Q2 2026 figures that is ₦1.37 trillion a year generated, delivered and never converted to revenue. Last quarter it was ₦63, so it improved by one naira.
Think of Nigeria's grid as a water pipe. The country pumps ₦947 billion worth of electricity into it every quarter.
By the time it reaches the tap, ₦343 billion has leaked through holes, been tapped illegally, or reached customers whose meters are broken or missing.
NERC's own plan allows for some leakage: 16.92%, the cost of running any distribution network. The actual rate is 36.23%. That gap of 19.31 points, roughly ₦731 billion a year, is what the sector should be recovering and is not.
Where the money goes, ₦ billion per quarter
Source: derived by TCL from NERC Q2 2026 figures (billed ₦744.67bn, collected ₦603.64bn, ATC&C 36.23%, collection efficiency 81.06%). Bar widths are percentages of the energy input value.
Two separate failures, and they need different fixes. ₦201.9 billion never reaches a bill, which is a metering and theft problem. A further ₦141.0 billion is billed and not paid, which is a collection problem.
| DisCo | Collection efficiency | Change from Q1 |
|---|---|---|
| Benin | 92.68% | Highest reported |
| Ikeja | 92.20% | Second |
| Eko | 89.39% | Third |
| Kano | 47.74% | Lowest reported |
| National | 81.06% | Up 2.11 points |
Partial table. NERC's Q2 2026 collection breakdown was reported for the top three and the lowest performer only. Kaduna and Jos are named among the weakest without published figures. The full eleven-company table returns when the complete factsheet is available.
NERC publishes ATC&C and collection efficiency. Billing efficiency and the energy input value are derived.
Cross-checks pass. 1 less billing efficiency times collection efficiency returns 36.23%, matching the published ATC&C. The derived quarterly loss of ₦342.94bn matches energy input value less revenue collected to within ₦0.01bn.
Caveat, printed every issue. This annualises a single quarter. ATC&C varies seasonally, and a proper annual figure requires all four quarters.
The market deficit reported in NERC summaries is what distributors owed and could not remit. It measures a different thing and must never be conflated with this figure.
If the MYTO target of 16.92% were met, the sector would recover an additional ₦731 billion a year. That is close to twice the ₦321 billion spent on subsidy in the same quarter, and every point of improvement is worth about ₦37.9 billion annually.
The metric that tracks reform here is not installed capacity or a generation record. It is whether the ₦36 that disappears from every ₦100 keeps shrinking.
Three Paths to End-2027
One lever decides which path holds. It is gas, not tariff.
| Scenario | Probability | What happens | Marker |
|---|---|---|---|
| Arrears unlock gas | 35% | The ₦729bn settlement reaches generators, gas deliveries rise above 900 mmscfd, and available generation clears 5,000 MW on a sustained basis. | A named GenCo confirms funds received |
| Grinding improvement | 45% | Collection continues improving one to two points a quarter, ATC&C drifts toward 33%, generation stays near 4,300 MW, and subsidy persists above ₦300bn a quarter. | Q4 2026 collection between 82% and 84% |
| Cost shock dominates | 20% | Energy inflation above 10% and diesel costs push industrial customers further off-grid, the creditworthy load base shrinks, and collection stalls despite tariff policy holding. | Band A customer numbers fall quarter on quarter |
Probabilities are TCL's editorial judgement, not a model output. They are published so they can be marked against outcomes in later issues.
Grid and Tariff Economics
Tariff policy is frozen while arrears stand, which leaves collection as the only lever still moving. The federal government spent ₦321.26 billion on subsidy in Q2 2026 while distributors collected ₦603.64 billion.
Put those side by side. Subsidy equals more than half of what the entire distribution sector collected from customers.
A cost-reflective tariff is one where the customer pays what it costs to generate, move and deliver the electricity, with a regulated return. Where the tariff sits below that, somebody covers the difference. In Nigeria that somebody is the federal budget.
Raising a national tariff raises the amount billed. It does not raise the share collected, and on Q2 figures ₦141 billion of what was billed went unpaid.
About 15 states now regulate their own electricity markets under the 2023 Electricity Act, Lagos among them through LASERC. Any analysis that treats NERC rules as nationwide is already wrong.
Collection, not tariff, is the live variable until arrears clear. If national collection passes 85% before the end of 2027 the subsidy case weakens on its own. If it stalls near 81%, a tariff rise simply increases the unpaid balance.
The Oil Price Is Paying the Budget and Taxing the Customer
Brent rose 13% in October and traded above $111 on 22 October as attacks on Middle East shipping escalated (Nairametrics). Nigeria held OPEC quota at 1.53 million barrels a day for a fifth month.
For a net exporter that is revenue. For the same country's electricity customers it is cost, and the two arrive in different accounts.
The same shock, two directions
Sources: Nairametrics reporting on October Brent movement, NBS September energy inflation, and reported diesel price change. Compared by TCL.
The diesel figure is the world's largest recorded increase this year. Every business running backup generation absorbed it.
The World Bank now forecasts Brent averaging $79 in 2027, with $105 under its adverse scenario. An exporter budgeting on this year's windfall is budgeting across a $26 spread.
Oil revenue is funding a power sector whose customers are being priced off the grid by the same barrel.
If the World Bank baseline holds, the 2027 budget loses the windfall while energy inflation persists. Treat this revenue as temporary and spend it on gas supply, the one input that converts into delivered electricity.
This Month's Correction
This one recurs every issue. It is worth correcting again.
Nigeria's electricity problem is a generation problem. Build more power stations and the lights come on.
Nigeria has 13,625 MW of plant and generated an average of 4,089 MW in September. Thermal plants receive roughly 43% of the gas they need and distributors lose 36.23% of the value reaching them. Adding plant to that system adds idle plant.
Checkable Between Now and Q1 2027
Confidence is TCL's judgement. The basis column states what it rests on.
| Signal | Confidence | Basis |
|---|---|---|
| NERC October operational factsheet | High | Publishes roughly 8 to 10 days after month-end, so around 10 November |
| A named GenCo confirms NBET funds received | Medium | Settlement begun 9 October. Receipt is normally reported by the recipient, not the payer |
| Q3 2026 collection efficiency above 83% | Medium | Two consecutive quarterly improvements, 78.95% then 81.06% |
| Lagos reaching 3,000 MW by March 2027 | Low | A state target with no published build schedule. Marked as a projection |
| Full eleven-company collection table | Medium | Q2 breakdown was partially reported. The complete factsheet should carry all eleven |
| Gas delivery above 900 mmscfd | Low | The test of whether arrears settlement reaches the fuel chain |
| A start date for Nigeria's 1,037 km pipeline section | Low | Algeria began building in June 2026 and Niger is expected in early 2027. Nigeria has announced nothing |
| Sonatrach or NNPC naming a Russian partner | Low | Algeria's foreign minister described negotiations on 27 October. No company named and no contract signed |
How Nigeria's electricity system actually works
The grid runs at about 31% of installed capacity. No prior knowledge assumed.
1. The chain, from fuel to your socket
Electricity reaches a Nigerian socket through six steps. A failure at any one of them produces the same result at the plug.
Four categories of loss sit along that chain. Fuel shortfall stops generation before it starts, and Nigerian thermal plants get about 43% of the gas they need.
Transmission limits cap what can move. Technical losses are the physics of pushing electricity through wires. Commercial losses are theft, unmetered consumption and unpaid bills.
Nigeria has 13,625 MW of generating plant and delivers roughly 4,300 MW. It is a 13-lane motorway with four lanes open. Building a fourteenth lane does not help while nine stay closed.
Every Nigerian power debate eventually returns to generation capacity because it is the easiest number to announce. The chain says the constraint sits in fuel supply and distribution. Watch those two and ignore capacity headlines.
2. Six concepts every Nigerian should understand
The share of installed capacity actually available to run. Nigeria sits near 31%. Availability is readiness, not output.
Aggregate technical, commercial and collection losses. For every ₦100 of electricity entering the network, ₦64 is collected. The national rate is 36.23%.
Of what is billed, how much is paid. For every ₦100 billed, ₦81 is collected. This is a narrower measure than ATC&C and the two are often confused.
A price covering generation, transmission, distribution and a regulated return. Below that level, the federal budget covers the difference.
How steadily a plant runs against its maximum. A high load factor on a small available capacity still produces little electricity.
A small generation and distribution system serving a community independently of the national grid. Usually solar with battery storage.
3. Scale, and what it means per person
Absolute capacity figures mean little without a denominator. Two comparisons make the Nigerian position legible.
Installed against available capacity, watts per person
TCL calculation from NERC installed capacity of 13,625 MW and NISO average September 2026 generation of 4,089 MW, against an assumed population of 230 million. The population figure is an assumption and the result moves with it.
Eighteen watts per person is less than a single light bulb running continuously. That is the honest description of what the grid delivers.
On price, Africa recorded an average of $0.141 per kilowatt hour for residential customers and $0.134 for business in Q3 2026 (Nairametrics, 14 October). Nigerian tariffs sit below cost-recovery, which is why subsidy persists.
4. Policy tracker
| Instrument | Status | What it does |
|---|---|---|
| Electricity Act 2023 | In force | Allows states to regulate their own electricity markets. About 15 have taken it up. |
| NERC Net Billing Regulations 2026 | In force | Applies only to commercial and industrial systems of 50 kWp to 1.5 MWp. Compensation is billing credits, not cash. |
| Presidential Power Sector Debt Reduction | Disbursing | ₦4 trillion target. NBET began settling ₦729 billion on 9 October 2026. |
| National metering programme | Pre-disbursement | Roughly 5.1 million customers remain unmetered and billed on estimate. |
| Tariff review | Frozen | Held while sector arrears stand. Collection is the only lever still moving. |
| Net zero by 2060 | Announced | Requires solar to reach 209,000 MW by 2050, from about 1,019 MW today. |
5. Essential reading
6. Frequently asked questions
Three reasons compound. Thermal plants receive about 43% of the gas they need, transmission wheels roughly 8,800 MW, and some plant is out of service. Capacity on paper is not capacity on the grid.
Band A customers pay a cost-reflective tariff for a committed 20 hours of supply a day. It costs more per unit and delivers more hours. If supply falls short of the commitment, the distributor owes a reclassification.
Only if you are a commercial or industrial customer with a system between 50 kWp and 1.5 MWp. Compensation is billing credits, not cash. Residential systems are not covered.
LASERC, the Lagos State Electricity Regulatory Commission, not NERC. About 15 states have taken regulation of their own markets under the 2023 Electricity Act.
Roughly 5.1 million customers have no meter. Estimated billing is the consequence, and it is also why distributors cannot prove a collection rate to a lender.
It depends on load. This month's Deep Dive finds a Nigerian household on the minimum wage can afford 23.3 kWh a month at the recorded mini-grid tariff, against a modelled break-even of 119.9 kWh.
7. What this desk covers
Generation, transmission, distribution and the gas chain that feeds them.
Arrears, subsidy, tariff economics and who carries sector credit risk.
NERC, state regulators under the 2023 Act, and the instruments actually in force.
Named operators, their execution record, and what they deliver against what they announce.
What a warming climate does to hydro, demand and network resilience.
The 2060 target, the solar trajectory, and the distance between them.