The report showed that Discos recorded a collection efficiency of 79.59 per cent during the month, indicating that approximately N50.3 billion of billed revenue remained uncollected.

The March factsheet also revealed a decline in billing efficiency despite an increase in energy supplied to the distribution companies.

According to the data, the Discos received energy valued at N293.76 billion during the period, representing a 6.02 per cent increase compared to February 2026. However, total energy billed stood at N246.43 billion, up by only 1.71 per cent from the previous month.

As a result, industry-wide billing efficiency fell to 83.89 per cent from the preceding month, a decline of 3.55 percentage points, the fact sheet showed.

NERC’s data further showed that while total billings rose marginally, actual revenue collection weakened. Revenue collected by the Discos stood at N196.13 billion, representing a slight decline of 0.28 per cent compared to February.

Besides, the collection efficiency, which measures the proportion of billed revenue recovered by operators, also declined by 1.58 percentage points to 79.59 per cent. Despite the challenges in billing and collections, overall revenue recovery performance improved slightly during the month.

The regulator reported that the average allowed tariff across the industry stood at N124.30 per kilowatt-hour, while actual collections averaged N100.75 per kilowatt-hour. This translated to a revenue recovery efficiency of 81.05 per cent, up by 0.38 percentage points from February.

A breakdown of the performance of individual Discos showed significant variations across the industry. For instance, Ikeja Electric emerged as the strongest performer in revenue collection and recovery.

The utility recorded total billings of N41.82 billion and collected N40.30 billion, translating to a collection efficiency of 96.38 per cent. It also posted the highest revenue recovery efficiency of 99.30 per cent.

Eko Disco followed closely with a revenue recovery rate of 95.73 per cent after collecting N33.89 billion from billings of N38.65 billion. Benin Disco also recorded strong performance, achieving a collection efficiency of 90.97 per cent and a revenue recovery rate of 85.18 per cent.

In terms of billing efficiency, Eko Disco led the industry with 92.30 per cent, followed by Port Harcourt Disco at 90.36 per cent and Ikeja Disco at 87.76 per cent.

On the other hand, Kaduna Disco recorded the weakest revenue recovery performance among the distribution companies. The utility collected only N4.66 billion from billings of N12.10 billion, resulting in a collection efficiency of 38.54 per cent and a revenue recovery rate of 35.65 per cent.

In the same vein, Jos Disco also struggled, posting a collection efficiency of 57.94 per cent and a revenue recovery rate of 53.53 per cent after collecting N6.74 billion from N11.63 billion billed.

Yola Disco recorded the lowest billing efficiency in the industry at 58.68 per cent, meaning it billed significantly less energy relative to what it received.

Other operators posted mixed results. Abuja Disco recorded a revenue recovery rate of 81.09 per cent, Enugu 81.79 per cent, Kano 76.09 per cent, Ibadan 71.65 per cent and Yola 58.58 per cent.

Source: ThisDay.

This was revealed by the Nigerian Electricity Regulatory Commission (NERC), even as inefficiencies across the electricity value chain led to losses exceeding N300bn during the period.

This was contained in the commission’s 2025 fourth-quarter report, which also highlighted declining remittances, high distribution losses, grid instability, and a marginal drop in available generation capacity.

According to the report, total invoices issued by generation companies for electricity produced in the quarter amounted to N804.93bn. However, due to non-cost-reflective tariffs, the government absorbed 52.30 per cent of the cost.

The commission stated,

“It is important to note that due to the absence of cost-reflective tariffs across all DisCos, the government incurred a subsidy obligation of N418.79bn; this represents a N39.96bn (-8.71 per cent) reduction in FGN subsidy compared to 2025/Q3.”

The report added that the subsidy covered more than half of generation costs, leaving distribution companies to pay only N386.13bn.

“The government subsidy accounted for 52.30 per cent of the total GenCo invoice, which is a 6.60pp decrease compared to 2025/Q3,” the commission noted.

Despite the intervention, the sector recorded significant commercial losses. While the total value of electricity supplied to distribution companies stood at N969.19bn, only N795.06bn was billed to customers.

“The naira value of the total energy offtake by all DisCos in 2025/Q4 was N969.19bn, and the total energy billed was N795.06bn, which translates to a billing efficiency of 82.03 per cent.

The billing efficiency of 82.03 per cent recorded during the quarter represents a decrease of 0.66pp compared to 2025/Q3 (82.69 per cent). At an aggregate level, DisCos cumulatively recorded billing losses of N174.12bn in 2025/Q4,” the report said.

In addition, high aggregate technical, commercial, and collection losses further weakened sector finances.

“The weighted average ATC&C loss across all DisCos in 2025/Q4 was 34.9 per cent, translating to a cumulative revenue loss of N139.19bn across all DisCos,” the report noted.

Combined, the billing losses of N174.12bn and ATC&C revenue losses of N139.19bn indicate inefficiency-driven losses of over N300bn during the quarter. The report also showed that distribution companies received 7,991.22GWh of electricity but billed customers for only 6,614.57GWh, indicating persistent energy accounting inefficiencies.

“Although the total energy received by all DisCos in 2025/Q4 was 7,991.22GWh, the energy billed to end-use customers was only 6,614.57GWh,” it stated.

Collection performance also declined compared to the previous quarter. Market remittances to upstream participants also weakened. DisCos were required to remit N471.66bn but paid only N437.27bn, leaving an outstanding balance of N34.39bn.

This translates to a remittance performance of 92.71 per cent in 2025/Q4 compared to the 95.21 per cent recorded in 2025/Q3.

On operational performance, the commission said available generation capacity averaged 5,400.38 megawatts, representing a slight decline from the third quarter, with several plants recording reduced output.

Seventeen power plants recorded decreases in available generation capacities in 2025/Q4 relative to 2025/Q3, it said.

However, energy generation improved during the quarter. Average hourly generation increased to 4,452.71MWh/h, resulting in total generation of 9,831.58GWh.

“The average hourly generation of the grid-connected power plants increased by 273.56MWh/h (+6.55 per cent),” the report stated.

Grid stability concerns also persisted. System frequency and voltage levels fell outside prescribed operating limits.

“In 2025/Q4, the average lower daily (49.38Hz) and average upper daily (50.65Hz) system frequencies were outside the normal operating limits,” the commission said.

The report stated that there was one incident of system disturbance on the national grid in 2025/Q4. A partial collapse of the grid occurred on December 29. The commission warned that the current subsidy regime exposes government finances to uncertainty.

“The current open-ended subsidy regime leaves the FGN exposed to indeterminate subsidy obligation,” it stated, citing generation cost variations and supply mix as key drivers.

The report added that the Q4 subsidy declined partly due to increased energy allocation to premium customers on Band A feeders. “The key driver of this reduction is the increase in energy allocated to Band A customers from 40 per cent to 45 per cent,” the commission said.

(Source: Punch)

The regulatory body mandated that the full disbursement of these outstanding reimbursements must be completed within a 12-month window, effective from March 1, 2026.

The MAP Reimbursement Mechanism

Under the MAP scheme, electricity consumers are permitted to pay upfront for the procurement and installation of meters to avoid estimated billing. According to NERC regulations, these costs are meant to be refunded by the DisCos through energy credits (units) over time.

However, NERC observed that the pace of these refunds has been unacceptably slow, leaving billions of naira in consumer credit trapped with the power distributors.

Order No: NERC/2026/025, which amends the previous 2023 order on the reimbursement of meter costs, was signed by the NERC Chairman, Musiliu Oseni, and the Commissioner, Legal, Licensing & Compliance at NERC, Dafe Akpeneye, on February 27, 2026.

NERC stated that, as of December 31, 2025, DisCos had failed to reimburse customers for meters procured under the MAP framework, leaving an outstanding N20.33bn.

“In February 2026, the commission reviewed the level of compliance of DisCos with the expected reimbursement to customers who have paid for meters under the MAP framework.

The review highlighted that DisCos have an outstanding amount of N20.33bn to reimburse customers for meters procured under the MAP framework as at 31 December 2025,” the order stated.

The commission explained that the order is intended to prevent repeated delays in reimbursements, optimise customer notification, and strengthen sector credibility and confidence.

In the new order, the commission stated that all reimbursements to customers for meters procured under the MAP framework shall be fully automated on customer accounts, saying,

“DisCos shall ensure that the total cost of a MAP meter is recognised as credit on the customer’s account upon activation of the meter and disbursed automatically as monthly credits over the approved amortisation period.”

DisCos were also instructed that meter reimbursement credits cannot be offset against customer legacy debt.

“DisCos shall not offset meter reimbursement credits against customer legacy debts; the items must be treated separately,” the order stated.

For prepaid customers, DisCos must automatically generate monthly tokens representing the reimbursement, while for postpaid customers, the reimbursement must appear as a distinct credit on their bills.

NERC said,

“For customers with prepaid meters, no later than the 4th day of every month, the DisCo’s billing system will automatically generate a token with an energy value equivalent to the monthly reimbursement which the customer is due to receive over the 120-month amortisation period based on the prevailing tariff for the customer.

“For post-paid customers, the monthly reimbursement of the cost of a MAP meter shall appear as a distinct credit line item which is expected to be subtracted from the customer’s total payable for the month.”

To recover the N20.33bn arrears, DisCos are to accelerate repayment over 12 months. The order noted that prepaid customers will receive two tokens per month, while postpaid customers will see two reimbursement line items on their bills.

“To recover the sum of N20.33bn that was not reimbursed to customers as at 31 December 2025, DisCos shall accelerate the rate of recovery for the affected customers over a 12-month period commencing from 1 March 2026,” the order said.

NERC also mandated monthly reporting and a dedicated complaints channel for affected customers.

“All DisCos shall file monthly reports with the Commission detailing the total monetary value of the reimbursement to customers through energy credit, in accordance with the template approved by the Commission.

According to the latest quarterly report by the Nigerian Electricity Regulatory Commission (NERC), three of Nigeria’s West African neighbours; Togo, Benin and Niger Republic, now owe Nigerian power companies a combined N25.36 billion (about $17.8 million) for electricity already supplied.

Across the third quarter of 2025, the Market Operator invoiced these international bilateral customers a total of $18.69 million for energy consumed under existing cross-border power agreements.

But only $7.125 million was remitted, leaving an unpaid balance of $11.56 million within the period. When combined with unresolved debts from prior quarters, the total outstanding amount has grown to over $17.8 million, roughly N25.36bn at current exchange rates.

The three entities identified in the report are Compagnie Énergie Électrique du Togo, Société Béninoise d’Énergie Électrique of Benin, and Société Nigérienne d’Électricité of Niger, all of whom purchase power from Nigerian generation companies (GenCos) through bilateral deals.

While international customers under-performed, domestic bilateral customers displayed a relatively stronger payment discipline.

NERC noted that local buyers settled N3.19bn of an invoiced N3.64bn, equivalent to roughly 87.6% remittance performance, markedly higher than their international counterparts.

The report highlights a persistent issue for Nigeria’s power markets: international remittances remain significantly lower, with only about 38% of invoiced value collected in the most recent quarter.

The ongoing non-payment by regional consumers adds fiscal strain on Nigeria’s already under-capitalised power sector, coming at a time when the government and regulators are pushing reforms to shore up investment, improve operational efficiency, and reduce sector debt.

The figures reflect broader challenges in cross-border electricity trade, a key component of the West African Power Pool (WAPP) initiative, and raise questions about enforcement mechanisms in bilateral energy agreements.

As Nigeria continues to rely on regional power exports, stakeholders say improved compliance and timely payment from international off-takers will be crucial to stabilise revenue flows and support long-term sector sustainability.

This was disclosed in a statement by Mr. Bayo Onanuga, Special Adviser to the President on Information and Strategy.

The reconstituted Board of the Commission is as follows:

Dr. Mulisiu Olalekan Oseni has been appointed chairman of NERC. Dr. Oseni began his service at the Commission as a Commissioner in January 2017 and was later appointed vice chairman.

His appointment as chairman took effect from December 1, 2025, and will run until the completion of his 10-year tenure at the Commission, in line with the provisions of the Electricity Act, 2023.

Dr. Yusuf Ali has been designated vice chairman of the Commission. He was first appointed as a Commissioner in February 2022.

His appointment as Vice Chairman took effect from December 1, 2025, and will subsist until the end of his first term.

Mr. Nathan Rogers Shatti continues his service as Commissioner, marking his second term in office. He was first appointed in January 2017.

Mr. Dafe Akpeneye is also serving a second term as Commissioner, having been initially appointed in January 2017.

Mrs. Aisha Mahmud Kanti Bello is serving her second term as Commissioner, following her initial appointment in December 2020.

Dr. Chidi Ike continues his service as Commissioner, serving his first term after being appointed in February 2022.

Dr. Fouad Animashaun has been appointed as Commissioner, effective December 2025. Dr. Animashaun is an energy economist with extensive experience in Nigeria’s power sector and most recently served as Executive Commissioner and Chief Executive Officer of the Lagos State Electricity Regulatory Commission.

President Tinubu has charged the reconstituted Board to deepen and consolidate the ongoing transformation of Nigeria’s power sector, in strict alignment with the letter and spirit of the Electricity Act, 2023.

The President reaffirmed the Federal Government’s commitment to strengthening regulatory oversight, improving efficiency and transparency, and advancing reforms that will deliver reliable and sustainable electricity supply to Nigerians.

This brings to a total of 15MW, the worth of power generation licenses issued by EERC since the successful completion of the transfer of regulatory oversight from the Nigerian Electricity Regulatory Commission to the agency on October 22, 2024, a feat it was the first state to achieve.

Speaking during the issuance of the license at the EERC office in Enugu, Thursday, Chijioke Okonkwo, the chairman and CEO of the agency, said the milestone reflected the growing confidence that private sector players and investors reposed in the Enugu State electricity sector and in the enabling environment created for electricity business to thrive.

“Tempo Power swiftly took advantage of this opportunity offered by the conducive investment climate in Enugu State, engaged an off-taker and successfully completed the application process for the generation license.

“Their project is a model of proactive engagement and strategic partnership, and the successful deployment of this 5MW power plant is a collective win for all of us. We are confident that as the market grows, Tempo Power will continue to scale up its capacity.

“We acknowledge that this transformation was initiated by the visionary leadership of Governor Peter Mbah through the articulation of the Enugu State Electricity Policy 2023 and the enactment of the Enugu State Electricity Law also in 2023.

“Since we successfully completed the transfer of regulatory oversight from the national regulator (NERC) to EERC on 22nd October 2024, we have issued interim licenses, including an interim distribution license to Mainpower Electricity Distribution Limited and a 10MW generation license to Fedikore Limited.

We have successfully resolved over 60 customer complaint issues and we are equally reviewing four license applications covering generation, electricity distribution and electricity retail,” he stated.

While recognising the arduous work ahead, the EERC Chairman reiterated the Commission’s commitment to working collaboratively with stakeholders – electricity providers, policymakers, financiers, and communities – to deliver reliable, accessible, and sustainable power across the State.

He, therefore, advised other would-be investors to emulate Tempo Power by taking advantage of the abundant energy sources in the state and increasingly business-friendly environment being created by the Mbah Administration.

“Enugu State is open for energy business. We invite investors and developers to harness the wealth of natural energy resources in the State. The enabling environment fostered by the Government has made investment decisions easier and more attractive.

“Enugu State has witnessed transformative improvements that support the electricity sector development, including major upgrades in access roads and infrastructure, enhanced security of lives and property, targeted socio-economic initiatives, among others. These developments form the bedrock for electricity investment and most will serve as anchor loads to extend electricity to our underserved and unserved communities across the State.

“Today, we celebrate with Tempo Power Solutions. And soon, we will also celebrate with other licensees whose applications are undergoing review – across generation, distribution, and retailing of electricity,” Okonkwo concluded.

In his remark, Mr Collins Kalabare, the executive director of Tempo Power, commended Mbah for setting the pace in what states could do to solve Nigeria’s energy problem, and the EERC for running a professional and transparent system where investors do not need to know anybody to get things done fast.

“I must appreciate the EERC for the professional, business-minded and openness of their processes and operations. The process is seamless and you do not need to know anybody.

“EERC is indeed working according to the vision and speed of Gov Peter Mbah, who we have learnt is in a hurry to develop and make Enugu State’s economy grow and uplift the general status of residents and businesses.

“As a reputable and responsible company, we will be offering uninterrupted electricity supply, cost reflective tariff and electricity supply meant to add value to commercial and residential concerns as well as grow businesses and general economy of the state,” Kalabari said.

In a ceremony to mark the takeover at the NERC headquarters in Abuja, Sanusi Garba, the NERC Chairman expressed his delight that KSERC officials twinned with NERC and gained regulatory knowledge from staff members of NERC.

He assured that NERC will keep an open door to assist KSERC in their information need to support their seamless operation.

In his remarks, Engr. Ibrahim Abdulwaris, the chairman of KSERC, commended NERC for the support and twinning sessions during the transfer period.

He noted that KSERC will leverage the relationship towards more collaborations with NERC.

NERC is empowered by the Electricity Act 2023 to transfer oversight of the electricity market to states that apply for such and duly meet the requirements.

So far, NERC has issued orders of transfer of oversight of the electricity market to ten states. While some have fully taken charge, the others have up till July 2025 to fully take over the oversight in their respective states.

According to the Multi-Year Tariff Order released by the Nigerian Electricity Regulatory Commission on Sunday, the government incurred N178.03bn electricity subsidy in January despite minimal cash backing.

This subsidy payment, a Punch Newspaper report shows, comes despite low allocations in the budget to cover the mounting electricity costs.

The N178.03bn is a decrease of 10.1 per cent or N19.88bn when compared to the N197.91bn that was shouldered by the government on behalf of electricity consumers in the previous month.

The regulatory commission stated that the subsidy was calculated after a review of key tariff indices which showed that the weighted average cost-reflective tariff dropped to N116.75 per kilowatts from N213.85 per kilowatts in December 2024.

NERC explained that the exchange rate was pegged at N1,556 to the dollar, an increase in inflation to 34.60 per cent, and changes in available generation capacity and cost necessitated the minor review.

On wholesale gas-to-power prices, “The review maintains the benchmark gas-to-power price of $2.42/MMBTU based on the established benchmark price of gas-to-power by the Nigerian Midstream and Downstream Petroleum Regulatory Authority.”

The commission maintained that the “approved tariffs shall remain in force subject to monthly adjustment of pass-through indices including inflation rate, NGN/dollar exchange rate and gas-to-power prices.”

While the reduction in the January subsidy cost might seem like a positive development, it highlights the larger issue of the financial sustainability of Nigeria’s power sector.

As of now, the government continues to bear the lion’s share of electricity subsidies, with plans to phase out these subsidies through tariff adjustments to reflect the true cost of power generation, transmission, and distribution.

The January 2025 subsidy breakdown indicates varying subsidy costs across the country’s distribution companies.

Consumers under the Abuja Distribution Company emerged as the largest beneficiary of the subsidy, receiving N28.38bn. This was closely followed by Ikeja Disco, which was allocated N27.2bn. Consumers under the Eko Distribution Company (Eko Disco) benefited from a N22.88bn subsidy.

Other regional Discos received significant amounts as well, with the Kaduna Disco receiving N14.13bn, Jos Disco N11.84bn, and the Enugu Disco N15.38bn. The Benin Disco was allocated N15.75bn, while the Yobe Disco was allocated N7.77bn. Meanwhile, the Port Harcourt Disco received N14.59bn, and Ibadan Disco was allocated a substantial N24.03bn.

Meanwhile, a document sighted by our correspondent on Monday showed that last year, only N450bn was cash-backed out of the incurred subsidy cost of N2.37tn in 2024, leaving an outstanding of N1.92tn.

“Total subsidy in 2024 stood at N2.37tn. Without the tariff review approved by Mr President on April 24, the subsidy would have risen to N3.2tn, 11.64 per cent of the 2024 total federal budget. Less than N450bn has been cash-backed from the N2.37tn tariff shortfall in 2024. Thus, N1.92tn is still outstanding.”

The government also disclosed a projected tariff shortfall of N2.36tn for 2025.

“At the currently allowed tariffs, the market faces a projected tariff shortfall of N2.36tn for 2025 with no anticipated funding for 2025 tariff shortfall,” the document added.

[Source: Punch]

NERC, the regulatory body with authority for the regulation of the electric power industry in Nigeria, therefore issued regulations on the procedure for tariff reviews.

The latest order, signed by Sanusi Garba, NERC chairman, stated that pursuant to the provisions of the Electricity Act 2023, the commission is obligated to review and approve a fair tariff to allow licensees to recover prudent costs and a reasonable return on capital invested in the business for the provision of electricity services.

It stated that Section 116(1) of the Act provides that activities in the generation, transmission, distribution, trading, supply, system operation, and electricity distribution franchising shall be subject to tariff regulation, saying Section 116(2) further provides for the commission to develop a tariff methodology that allows licensees operating efficiently to recover the full efficient costs of their business activities, plus a reasonable return on investments by shareholders.

“In exercise of the powers conferred in Section 116 of the Act, the commission has developed and adopted the Multi-Year Tariff Order Methodology as an incentive-based price regulation framework for the determination and projection of tariffs payable in the Nigerian Electricity Supply Industry,”

NERC stressed that the Multi-Year Tariff Order methodology provides for a major review of electricity tariffs every five years, during which all tariff assumptions are reviewed to ensure the industry’s viability and efficiency.

One year before the major tariff hike, the commission said it would issue a notice to all licensees about its intention while requesting them to submit applications for the review of tariffs supported with necessary documentation within 120 days of the notice.

“The commission shall, one year before the expiration of the major tariff review order in force or as may be considered necessary, issue a notice to all licensees about its intention to commence the process for a major review of the existing tariff. The notice shall be published in three national dailies and on the website of the commission.

“The Notice shall request for submission of applications for the review of tariffs supported with documentation that includes but not limited to audited financial statements, budgets, investment plans (in line with prevailing guidelines on Performance Improvement Plans), and proof of wide consultation with customers in the licensees’ service area concerning the proposed filing of the application for tariff review and any other information as deemed necessary by the commission,” the regulation stated.

The regulator said an initial review of the applications shall be completed and a consultation paper developed no later than 90 days after the deadline for the submission of the applications.

“The consultation paper developed by the commission shall outline the basis for the tariff review applications by the licensees including their proposals on capital investments, service improvements, new connections, loss reductions, reset of tariff assumptions if any, and possible impact on rates payable by the affected customers.

“The consultation paper shall be published on the commission’s website and public notices issued soliciting comments with a timeline of 21 days for submission by stakeholders. The commission shall within 90 days from the publication of the consultation paper review all comments and schedule and conclude a Rate Case Hearing, having regard to the stakeholders’ responses to the consultation paper,” the regulation stated.

It was stated that all comments and observations received from the public on the consultation paper and the Rate Case Hearing shall be examined and considered in the development of a draft tariff order for the consideration of the commission.

Upon due consideration of the outcomes of the general stakeholders’ presentation and the Rate Case Hearing, the commission said it shall consider and approve a Major Tariff Review Order within 30 days from the date of the Rate Case Hearing held at the commission.

“Any licensee whose tariffs have been reviewed shall communicate the outcome of the tariff review to its customers vide its website and other communication channels,” it said.

For monthly or minor reviews, the commission said it shall review the prevailing operating end-user tariffs and changes may be made thereto to account for changes in generation fuel costs, the Nigerian and United States inflation rates, United States dollar exchange rate to the naira, and average generation availability relative to the preceding month.

The commission also stated that it may, at its discretion, conduct a minor review of end-user tariffs at other short periods but no longer than six months.

Earlier, the special adviser to President Bola Tinubu on Energy, Olu Verheijen, has said there would be an electricity tariff review in a few months.

Verheijen said the current N200bn monthly electricity subsidy benefits only the wealthiest 25 per cent, leaving the poor masses in the dark.

She said the government would put in place a subsidy system that works for the masses.

“Today, the Federal Government spends over N200bn per month on electricity subsidies, but much of this support benefits the wealthiest 25 per cent of Nigerians rather than those who truly need assistance. To address this, the Federal Government is working towards a targeted subsidy system to ensure that low-income households receive the most support. This approach will make electricity more affordable and accessible for millions of hardworking families,” she stated.

This development, which makes Enugu the first state to commence the development of a sub-national electricity market in both Nigeria and Africa, also saw the EERC, issue licensees to Mainpower Electricity Distribution Limited, an EEDC subsidiary set up to take over electricity operations of EEDC in Enugu State effective midnight of Wednesday and the first Independent Power Project, IPP, in Enugu State, to Fedikore Limited, to build a  power plant with a nameplate capacity of 10MW.

This followed the enactment of the Enugu State Electricity Law, 2023, and the setting up of the EERC, which saw Enugu State emerge in April this year as the first state to be handed the regulatory power over its electricity market by NERC, but with a six-month transition period, which elapsed on Tuesday, thus effectively empowered to now fully exercise the constitutional right to develop its electricity sector across the value chain of generation, transmission, distribution, or retailing services, including Mini-Grid and Off-Grid electrification solutions.

In his address, Chijioke Okonkwo, the chairman of EERC, described the event as significant “as it marks the beginning of the development of sub-national electricity markets not only in Nigeria, or West Africa, but across the African continent.

“Today completes the six months transition for the transfer of regulatory authority from the national regulator, NERC, to the EERC, as stipulated in Section 230 of the Electricity Act 2023, and the consequential Order of NERC dated 22nd April 2024.

“Today, we now take on the monumental responsibility of regulating and guiding the electricity sector in Enugu State. This assumption of regulatory oversight is not just about the transfer of authority, but represents a shared vision for a more efficient, responsive, and innovative electricity market.

“NERC has laid a strong foundation, and we are confident that EERC will build on that legacy to bring about positive changes for the people of Enugu State and beyond, in line with Enugu’s realities.

“Our mission is clear: to ensure that Enugu has access to reliable, cost effective, and sustainable electricity while promoting fairness and innovation in the sector.

“We are here to enhance the quality of life for all residents, businesses, and stakeholders by creating an efficient regulatory environment that fosters growth and transparency,” Okonkwo stated.

The Chairman commended the Governor Peter Mbah Administration for zero political interference in the affairs of the Commission.

“I must say that we have enjoyed a tremendous level of independence from the state government activities and our own role. We have been established and supported to take off. However, we have also been given the authority and independence to develop the regulations and policies that we have put in place, not minding how they impact on the state government,” he concluded.

Speaking, Kester Enwereonu, a board member of Mainpower Electricity Distribution Ltd, assured the people of the state a better electricity experience in all ramifications.

“We are not just identifying with EERC as the pacesetter, Mainpower will also want to be the pacesetter. We are assuring you that in the coming weeks, months, and years, and with the regulatory structure that are now tailored to the needs and purposes of the state, we are going to have an improved service to the people of Enugu State,” he said.

On his part, Dr. Chukwueloka Umeh, the founder and MD/CEO of Fedikore Ltd, described what is happening in Enugu as revolutionary, expressing Fedikore’s joy to partner with EERC.

“The EERC has done a fantastic job in starting this revolution that is about to happen and we are pleased to be a part of it. Fedikore set up last year as the first IPP in Enugu State. We built 4mw plant at 9th Mile to supply power to the Enugu State Water Corporation here in Enugu. So, we are very committed to working with the state, especially given the leadership provided by both the government and the EERC so far. We believe that with the support of EERC, the state and with the partnership with Mainpower, we can do amazing things here to start the industrial revolution that we are talking about for many years. It is possible,” Umeh stated.