## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## i \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # NERC©2025 # The Nigerian Electricity Regulatory Commission (NERC) quarterly report is prepared # in compliance with Section 56(3) of the Electricity Act 2023, which mandates the # Commission to submit quarterly reports of its activities to the President and the # National Assembly. The report analyses the state of the Nigerian Electricity Supply # Industry (NESI) covering the operational and commercial performance, regulatory # functions, as well as consumer affairs. The report is directed at a wide spectrum of # readers including energy economists, engineers, financial and market analysts, # potential investors, government officials and institutions, the private sector as well as # general readers. NERC quarterly report is freely available to stakeholders of the **NESI, government agencies and corporations. Individuals can also access any issue freely from the Commission’s Website: [www.nerc.gov.ng](http://www.nerc.gov.ng/)** # Please direct all inquiries, comments, and suggestions on the report to: # The Commissioner Planning, Research and Strategy Division # Nigerian Electricity Regulatory Commission Plot 1387, Cadastral Zone A00 # Central Business District P.M.B 136, Garki, Abuja # Nigeria NERC website: [www.nerc.gov.ng](http://www.nerc.gov.ng/) # Contact Centre: Tel: +234 (09) 462 1400, +234 (09) 462 1410 # Email: [info@nerc.gov.ng](mailto:info@nerc.gov.ng) ## ii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * # Table of Contents List of Tables.....iv List of Figures.....v List of Abbreviations.....vi 1.0 SUMMARY.....viii 2.0 STATE OF THE INDUSTRY.....2 2.1 Operational Performance.....2 2.1.1 Available generation capacity.....2 2.1.2 Plant availability factor.....3 2.1.3 Quarterly generation.....5 2.1.4 Generation load factor.....7 2.1.5 Generation mix.....8 2.2 Grid Performance.....10 2.2.1 Transmission loss factor.....10 2.2.2 Grid frequency.....11 2.2.3 Voltage fluctuation.....12 2.2.4 System collapse.....14 2.3 Commercial Performance.....15 2.3.1 Energy offtake performance.....15 2.3.2 Energy billed and billing efficiency.....17 2.3.3 Revenue and collection efficiency.....18 2.3.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss.....20 2.3.5 Market * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # List of Tables **Table 1: Plant Availability Factor (%) in 2024/Q3 vs. 2024/Q4 ... 4** **Table 2: Average Hourly Generation (MWh/h) in 2024/Q3 vs. 2024/Q4 ... 7** **Table 3: System Collapse in 2024/Q4 ... 14** **Table 4: DisCo energy offtake performance in 2024/Q3 vs. 2024/Q4 ... 17** **Table 5: Energy received and billing efficiency by DisCos in 2024/Q3 vs. 2024/Q4 ... 18** **Table 6: Revenue Collection Performance (%) of DisCos in 2024/Q3 vs. 2024/Q4 ... 19** **Table 7: ATC&C Loss (%) by DisCos in 2024/Q3 vs. 2024/Q4 ... 22** **Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q4 ... 24** **Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q4 ... 26** **Table 10: Invoices and Remittances of Other Customers in 2024/Q4 ... 27** **Table 11: Licences issued by the Commission in 2024/Q4 ... 35** **Table 12: Captive Generation Plants approved in 2024/Q4 ... 35** **Table 13: Mini-grid Permits and Registration Certificates issued in 2024/Q4 ... 36** **Table 14: Meter Service Providers certified in 2024/Q4 ... 37** **Table 15: Compliance and Enforcement Actions of the Commission in 2024/Q4 ... 39** **st** **Table 16: Metering Progress as of 31 December 2024 ... 44** **Table 17: Meter Deployment by DisCos in 2024/Q4 vs. 2024/Q3 ... 45** **Table 18: Complaints Received by DisCos in 2024/Q3 vs. 2024/Q4 ... 49** **Table 19: Appeals handled by Forum Offices in 2024/Q4 ... 51** **Table 20: Health and Safety (H&S) Reports in 2024/Q3 vs. 2024/Q4 ... 52** **Table 21: Causes of casualties recorded in 2024/Q4 ... 53** ## iv \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # List of Figures **Figure 1: Average Available Capacity (MW) in 2024/Q3 vs. 2024/Q4 ... 3** **Figure 2: Average Hourly Generation (MWh/h) in 2024/Q3 vs. 2024/Q4 ... 6** **Figure 3: Load Factor (%) in 2024/Q3 vs. 2024/Q4 ... 9** **Figure 4: Electricity Generated by Energy Sources (%) in 2024/Q3 vs. 2024/Q4 ... 9** **Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) Jul- Dec 2024.. 11** **Figure 6: Monthly System Frequency (Hz) from July-December 2024 ... 12** **Figure 7: Monthly System Voltage (kV) from July-December 2024 ... 13** **Figure 8: DisCos Remittance Performances to NBET in 2024/Q4 ... 25** **Figure 9: DisCos Remittance Performances to MO in 2024/Q4 ... 26** **Figure 10: Category of complaints received at the Commission’s CCU in 2024/Q4 ... 48** **Figure 11: Category of complaints received by DisCos in 2024/Q4 ... 50** **Figure 12: Category of Complaints Received by Forum Offices in 2024/Q4 ... 51** **Figure 13: Accident Report for 2024/Q4 ... 53** ## v \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * List of Abbreviations | ADR | Alternative Dispute Resolution | | --- | --- | | AEDC | Abuja Electricity Distribution Company Plc | | ATC&C | Aggregate Technical, Commercial & Collection Loss | | BEDC | Benin Electricity Distribution Company Plc | | CAPEX | Capital Expenditure | | CCU | Customers Complaint Unit | | CEET | Compagnie Energie Electrique du Togo | | CTC | Competition Transition Charge | | DisCos | Distribution Companies | | DSOs | Distribution System Operators | | EA | Electricity Act | | ECR | Eligible Customer Regulations | | EEDC | Enugu Electricity Distribution Company Plc | | EKEDP | Eko Electricity Distribution Company Plc | | EPSRA | Electric Power Sector Reform Act | | GenCos | Generation Companies | | GWh | Gigawatt hour | | IBEDC | Ibadan Electricity Distribution Company Plc | | IEDN | Independent Electricity Distribution Network | | IE | Ikeja Electric Plc | | JED | Jos Electricity Distribution Company Plc | | KAEDC | Kaduna Electricity Distribution Company Plc | | KEDCO | Kano Electricity Distribution Company Plc | | kWh | Kilowatt hour | | MAP | Meter Assets Provider | | MDA | Ministries, Departments and Agencies | | MO | Market Operator | | MTS | MYTO Target Sales | | MW | Megawatts | | MWh | Megawatt hour | | MYTO | Multi-Year Tariff Order | | NBET | Nigerian Bulk Electricity Trading plc | | NERC | Nigerian Electricity Regulatory Commission | | NESI | Nigerian Electricity Supply Industry | | NICE | Notices of Intention to Commence Enforcement | | NIGELEC | Société Nigerienne d'electricite; Nigerien Electricity Society | | NIPP | National Integrated Power Project | | NMMP | National Mass Metering Program | | PAC | Partial Activation of Contract | | PCC | Partial Contracted Capacity | | PHED | Port Harcourt Electricity Distribution Company Plc | | PP | Percentage points | | SBEE | Société Béninoise d'Energie Electrique | | TCN | Transmission Company of Nigeria Plc | | TLF | Transmission Loss Factor | | YEDC | Yola Electricity Distribution Company Plc | * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## vii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 1.0 SUMMARY The average available generation capacity in 2024/Q4 was 5,296.98MW Pursuant to Section 34(1)(e) of the Electricity Act 2023 which states that "the Commission shall ensure the safety, security, reliability, and quality of service in the production and delivery of electricity to consumers”, the Nigerian Electricity Regulatory Commission (NERC or the Commission) continues to monitor the technical, operational, and commercial performance of the Nigerian Electricity Supply Industry (NESI). The Commission publishes quarterly reports to apprise the public of the overall performance of the NESI. The average hourly generation in 2024/Q4 was 4,207.41MWh/h Operational Performance The operational performance parameters reported in 2024/Q4 include the available generation capacity, plant availability factor, quarterly generation, load factor, and generation mix of the twenty- 1 eight (28) grid-connected power plants. Other parameters reported include the frequency, voltage, and overall stability performance of the national grid during the quarter. a. Available Generation Capacity: In 2024/Q4, there were twentyeight (28) grid-connected power plants consisting of nineteen (19) gas, five (5) hydro, two (2) steam, and two (2) gas/steam-powered plants. For this quarter, the average available generation capacity of the gridconnected power plants was 5,296.89MW. The average available generation capacity across the grid-connected plants increased by 195.98MW (+3.84%) from the 5,100.90MW recorded in 2024/Q3 to 5,296.89MW in 2024/Q4 (Figure A). Fifteen (15) power plants recorded increased available generation capacities in 2024/Q4 compared to 2024/Q3. b. Quarterly Generation: The average hourly generation on the grid in 2024/Q4 was 4,207.41MWh/h, which translates to a total generation of 9,289.95GWh. The average hourly generation of gridconnected power plants decreased by 72.83MWh/h (-1.70%) from 4,280.24MWh/h in 2024/Q3. The total electricity generated in the quarter also decreased by 160.81GWh (-1.70%) from 9,450.76GWh 1 AES and Gbarain power plants are not included in the report because they are currently not operational. The Maiduguri Emergency Power Plant (MEPP) is currently not operating in grid-connected mode. viii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * in 2024/Q3 to 9,289.95GWh (Figure B). The decrease in generation during the quarter was primarily due to the decrease in energy offtake by the grid-connected customers (including DisCos) compared to 2024/Q3. Figure A: Available Generation Capacity (July - December 2024) Figure B: Average Hourly Generation (July - December 2024) c. Grid Performance: In 2024/Q4, the average lower daily (49.39Hz) and average upper daily (50.91Hz) system frequencies were outside the normal operating limits (49.75Hz - 50.25Hz) but remained within the lower and higher bound stress limits (48.75Hz - 51.25Hz). The average lower daily (300.21kV) and average upper daily (349.45kV) * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # system voltages were however outside the limits prescribed in the grid # code (313.50kV - 346.50kV). The Commission continues to push the # SO to improve its system coordination activities to avert the system risk # posed by the continuous operation of the grid outside the normal operating limits. # Three (3) incidents of total collapse and two (2) incidents of partial **collapse occurred on the national grid in 2024/Q4. The partial collapses were recorded on 14 October and 05 November 2024,** # while the total collapses were recorded on 19 October, 07 November # and 11 December 2024, respectively. As contained in section 20.1 of # the Grid Code, the SO is expected to submit to the Commission a # detailed report containing the root causes of the incidents leading to # the system disruptions and mitigation plans to avoid a recurrence of similar incidents. # Commercial Performance **The review of commercial performance for 2024/Q4 covers energy offtake performance, billing efficiency, collection efficiency, aggregate** **technical, commercial, and collection loss, and the market remittance of relevant market participants. The Commission monitors the financial** # performance of the NESI to ensure an efficient flow of cash along the # value chain to guarantee the sustainability of the industry. **a. Energy Offtake Performance: In 2024/Q4, the average energy offtake by DisCos at their trading points was 3,360.77MWh/h out of** **the available PCC of 3,552.26MWh/h, translating to an overall offtake performance of 94.61%. The energy offtake during the quarter** ## A total of _₦509.84_ # (3,360.77MWh/h) represents a decrease of 84.36MWh/h (-2.45%) ## billion was compared to the 3,445.13MWh/h recorded in 2024/Q3. ## collected by all ## DisCos in # b. Billing Efficiency: The total energy received by all DisCos in ## 2024/Q4 out ## of the ₦658.40 # 2024/Q4 was 7,420.58GWh, while the energy billed to end-use ## billion billed to customers was 6,207.84GWh, translating into an overall billing **customers.** **efficiency of 83.66%. This represents a +1.51pp increase in billing efficiency relative to the 82.15% recorded in 2024/Q3.** # c. Collection Efficiency: The total revenue collected by all DisCos in **2024/Q4 was ₦509.84 billion out of ₦658.40 billion billed to customers. This translates to a collection efficiency of 77.44%,** ## x \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # representing an increase of +2.89pp compared to 2024/Q3 (74.55%). **d. Aggregate Technical, Commercial and Collection (ATC&C) Loss: The Aggregate Technical, Commercial and Collection (ATC&C) loss is a** # summation of – i) billing losses incurred by a DisCo due to its inability **to bill 100% of energy delivered to customers (technical and commercial losses); ii) collection losses arising from the DisCo’s** # inability to collect 100% of the bills issued to customers. **The weighted average ATC&C loss across all the DisCo in 2024/Q4 was 35.22%, comprising technical and commercial loss (16.34%) and** # collection loss (22.56%). The ATC&C loss of 35.22% was +10.44pp # higher than the MYTO target (24.78%) and translates to a cumulative **revenue loss of ₦139.08 billion across all DisCos. The ATC&C loss decreased by-3.88pp (improved performance) compared to** # 2024/Q3 (39.10%). Only Yola and Eko DisCos achieved their target # ATC&C, as provided in the MYTO during the quarter. The other DisCos **failed to achieve their target ATC&C, with Kaduna DisCo recording the worst underperformance relative to the target ATC&C (Actual –** # 60.65% vs. target – 25.00%) (Figure C). **Target ATC&C (%) Actual ATC&C (%)** **62.00** **52.00** **42.00** **(%) 32.00** **&C** **ATC 22.00** **12.00** **2.00** **Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano PH Yola Total** **-8.00** # Figure C: Target and Actual ATC&C losses for DisCos in 2024/Q4 **e. Market remittance: In 2024/Q4, the cumulative upstream invoice payable by DisCos was ₦408.86 billion, consisting of ₦360.97 billion** ## xi \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS **for DRO-adjusted generation costs from NBET and ₦47.89 billion for transmission and administrative services by the Market Operator** # (MO). Out of this amount, the DisCos collectively remitted a total sum # of ₦378.93 billion (₦336.63 billion for NBET and ₦42.30 billion for # MO) with an outstanding balance of ₦29.92 billion. This translates to **a remittance performance of 92.68% in 2024/Q4 compared to the 83.77% recorded in 2024/Q3. The disaggregated DisCo remittance** # performance to the market for 2024/Q4 is presented in Figure D. **f. Remittance by Special and Bilateral Customers: In 2024/Q4, the six (6) international bilateral customers purchasing power from the grid-** # connected GenCos made a cumulative payment of $5.21 million **against the $14.05 million invoice issued to them by the MO for services rendered in 2024/Q4. Similarly, the domestic bilateral** # customers made a cumulative payment of ₦1,252.58 million against # the ₦1,977.02 million invoice issued to them by the MO for services **3** # rendered in 2024/Q4 . **Invoice (NBET + MO) Remittance (NBET + MO)** **80.0** **70.0** **60.0** **Billion** **50.0** ₦ **40.0** **30.0** **20.0** **10.0** **0.0** **5.21 2.412.41** **Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano Port Harcourt Yola** **Performance 96% 89% 99% 90% 93% 99% 80% 39% 94% 89% 100%** # Figure D: DRO adjusted invoices and remittances in 2024/Q4 **2** **The NBET invoice payable by the DisCos for 2024/Q4 was only ₦360.97 billion because the FGN has taken** **responsibility for ~57% (₦471.69 billion) of the total generation costs in the form of subsidies arising from the** **freezing of end-use customer tariffs at the rates payable in July 2024.** 3 **It is noteworthy that both local and international bilateral customers made payments during 2024/Q4 for** **outstanding MO invoices from previous quarters; the international bilateral customers paid $2.98 million while** **the domestic bilateral customers paid ₦135.81 million. The details of these payments are contained in Appendix** **VII.** **xii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * Regulatory Functions The Commission issued thirty-nine (39) new Orders in 2024/Q4. The EA 2023, section 34(2)(d), empowers the Commission to licence and regulate persons engaged in the generation, transmission, system operation, distribution, supply and trading of electricity in the NESI. Additionally, the Commission regulates market entry or exit by sector The Commission players and issues Regulations, Guidelines and Orders that guide the operations of licensees, permit holders and registered operators. a. Orders: The Commission issued thirty-nine (39) Orders in 2024/Q4. They include: • NERC/2024/112 (EKEDP)-Transfer of Regulatory Oversight of the Electricity Market in Lagos State from the Nigerian Electricity Regulatory Commission to the Lagos State Electricity Regulatory Commission (LASERC). • NERC/2024/113 (IE) - Transfer of Regulatory Oversight of the Electricity Market in Lagos State from the Nigerian Electricity Regulatory Commission to the Lagos State Electricity Regulatory Commission (LASERC). • NERC/2024/126—NERC/2024/136 — October 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. • NERC/2024/137—NERC/2024/147 — November 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. • NERC/2024/149—NERC/2024/159 — December 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. • NERC/2024/164 (IE) — Transfer of Regulatory Oversight of the Electricity Market in Ogun State from the Nigerian Electricity Regulatory Commission to the Ogun State Electricity Regulatory Commission (OGERC). * * * • NERC/2024/165 (IBEDC) — Transfer of Regulatory Oversight of the Electricity Market in Ogun State from the Nigerian Electricity Regulatory Commission to the Ogun State Electricity Regulatory Commission (OGERC). Seventy (70) licences, permits and certifications were issued by the Commission in 2024/Q4. b. Licences and Permits: The Commission issued seventy (70) licences, permits and certifications in 2024/Q4. The breakdown of the licences, permits and certifications issued are as follows: • One (1) off-grid generation licence with a total nameplate capacity of 2.63MW. • Three (3) new electricity trading licences. • Four (4) captive generation permits with a gross capacity of 22.50MW • Five (5) registration certificates for mini-grids. • Twenty-four (24) permits for mini-grids. • Eighteen (18) certifications for Meter Service Providers and fifteen (15) permits for Meter Asset Providers. c. Hearings and Public Consultation: The Commission is empowered by the EA 2023 to perform a quasi-judicial function towards resolving disputes between stakeholders in the NESI. One of the ways by which the Commission performs this function is 4 through hearings . During the quarter (2024/Q4), the Commission conducted administrative proceedings in the form of a public hearing on Grid Disturbances on 24 October 2024. d. Compliance and Enforcement: The Commission issued fourteen (14) Rectification Directives (RD) and sixteen (16) Notices of Intention to Commence Enforcement (NICE) to licensees for different breaches/defaults during the quarter. Hearings are proceedings pursuant to the provisions of the Act through which the Commission seeks additional information on petitions or any matter filed before it by market participants or consumers in order to make a final decision. \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Consumer Affairs a. Consumer Enlightenment and Stakeholder Engagements: The Commission’s main consumer education and enlightenment mechanisms are town hall meetings and customer complaints resolution meetings. In 2024/Q4, the Commission convened one (1) town hall meeting in Kaduna between 12-14 December 2024, where issues around service-based tariffs, capping, metering, and customer redress mechanisms were discussed. A total of 185,439 meters were installed in 2024/Q4. As part of its routine activities, the Commission also engages relevant stakeholders and the wider public to apprise them of the Commission’s activities. The details of these engagements and other educative content on pertinent industry issues are shared with the public via the Commission’s social media accounts (LinkedIn, X and Instagram). b. Metering: A total of 185,439 meters were installed in 2024/Q4, representing an increase of +0.19% compared to the 185,087 meters installed in 2024/Q3. The new installations increased the net end-user metering rate across all the DisCos by +0.42pp between 2024/Q3 (46.15%) and 2024/Q4 (46.57%). During the quarter, 179,064 meters (96.56% of the total installations) were installed under the MAP framework, 4,076 meters were installed under the Meter Acquisition Fund (MAF), 1,924 meters were installed under the Vendor Financed framework, and 374 meters were installed under the DisCo Financed framework. The metering by the respective DisCos in the quarter under review is presented in Figure E. The Commission expects DisCos to utilise a combination of all available frameworks contained in the 2021 Meter Asset Provider and National Mass Metering Regulations (NERC – R – 113 – 2021) as well as the MAF to close their respective metering gaps. As a safeguard for customers against exploitation due to the lack of meters, the Commission has continued to issue monthly energy caps for all feeders in each DisCo. This sets the maximum amount of energy that may be billed to an unmetered customer for the respective month based on gross energy received by the DisCo and consumption by metered customers on their respective feeders. * * * Figure E: Status of Customer metering as of December 2024 c. Customer Complaints: Across the quarter, DisCos only successfully resolved 1,231 out of the 4,180 complaints that were filed at the NERC-CCU; this translates to a resolution rate of 29.45%. The number of complaints received across all DisCo-CCUs was 275,681, which represents a -16.13% decrease compared to the 328,696 received in 2024/Q3. As in previous quarters, metering, billing and service interruption were the prevalent issues of customer complaints during the quarter. d. Forum Offices: Pursuant to the provisions of its Customer Protection Regulations 2023 (CPR 2023), the Commission set up Forum Offices across the country to review unresolved disputes from the DisCos’ Complaint Handling Units (DisCos-CCU). The total In 2024/Q4, the Forum Offices number of active appeals across the Forum Offices in 2024/Q4 resolved 67.74% of was 3,267 made up of 2,034 new appeals in 2024/Q4 and 1,233 the active appeals in pending appeals from 2024/Q3. During the period, the forum eighty-four (84) panels held eighty-four (84) sittings and resolved 2,209 of the appeals filed at Forum Offices nationwide (67.62% resolution rate); the resolution rate was +8.84pp higher than the 58.90% achieved in 2024/Q3. * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # service standards expected from the DisCos in line with international best practices. ## Investigations have ## been launched into e. Health & Safety: The total number of accidents in 2024/Q4 was ## all reported fifty-four (54), which resulted in nineteen (19) injuries and twenty- ## accidents in the six (26) fatalities. The Commission has launched investigations into **NESI.** # all the accidents and will continue to work with all sector # stakeholders to improve the overall health and safety of the NESI. ## xvii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Key Facts on NESI Performance in Q4 of 2024 | 5,296.89MW | Average Available Generation Capacity;195.98MW(+3.84%)increasecomparedto2024/Q3\[5,100.90MW\] | | --- | --- | | 9,289.95GWh | Total QuarterlyGeneration;160.81GWh(-1.70%)decreasecomparedto2024/Q3\[9,450.76GWh\] | | 4,207.41MWh/h | AverageHourlyGeneration;72.83MWh/h(-1.70%)decreasecomparedto2024/Q3\[4,280.24MWh/h\] | | 79.43% | LoadFactor;-4.48ppdecreasecomparedto2024/Q3\[83.91%\] | | 32.61% | ShareoftotalquarterlygenerationfromHydropowerPlants;+0.01ppincreasecomparedto2024/Q3\[32.60%\] | | 3,360.77MWh/h | TotalenergyreceivedbytheDisCos;84.36MWh/h(-2.45%) decreasecomparedto2024/Q3\[3,445.13MWh/h\] | | 6,207.84GWh | Energybilledtocustomers;41.37GWh(-0.66%) decreasecomparedto2024/Q3\[6,249.21GWh\] | | N509.84billion | TotalRevenuecollectedbytheDisCos;N43.15billion(+9.25%)increasecomparedto2024/Q3\[N466.69billion\] | | 83.66% | CumulativebillingefficiencyacrossallDisCos;+1.51ppincreasecomparedto2024/Q3\[82.15%\] | | 77.44% | CumulativecollectionefficiencyacrossallDisCos;+2.89ppincreasecomparedto2024/Q3\[74.55%\] | | 35.22% | AggregateTechnical,CommercialandCollectionLoss;3.88ppbetterATC&Cperformancecomparedto2024/Q3\[39.10%\] | | N408.86billion | CombinedinvoicefromNBET(DRO-adjusted)andMO toDisCos;N32.81billion(-7.42%)decreasecomparedto2024/Q3\[N441.67billion\] | | N378.94billion | TotalamountremittedbyDisCostoNBETandTCN/MO;N8.93billion(+2.41%)increasecomparedto2024/Q3\[N370.15billion\] | | 92.68% | DisCos'overallremittanceperformance;+8.91ppincreasecomparedto2024/Q3\[83.77%\] | \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * FOURTH QUARTER 2024 | 185,439 | Number of new meters Installed; 352 more installations (+0.19%) compared to the 185,087 meters installed in 2024/Q3 | | --- | --- | | 275,681 | Total complaints received at the DisCo-CCU; -16.13% decrease compared to 328,696 complaints received in 2024/Q3 | | 67.62% | Forum Office complaint resolution rate; +8.72pp increase compared to 2024/Q3 \[58.90%\] | | 54 | Number of accidents; 2 fewer accidents compared to 2024/Q3 \[56\] | | 45 | Number of casualties (injuries and fatalities); 12 fewer casualties compared to 2024/Q3 \[57\] | * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * #### FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # 2.0 STATE OF THE INDUSTRY ### Pursuant to Section 34(1)(e) of the Electricity Act 2023 which states that "the ## Commission shall ensure the safety, security, reliability, and quality of service in the ## production and delivery of electricity to consumers”, the Nigerian Electricity **Regulatory Commission (NERC) continues to monitor the technical, operational, and commercial performance of the Nigerian Electricity Supply Industry (NESI).** **The Commission’s evaluation of the state of the NESI for 2024/Q4 covers the following key areas –** - **Operational performance: a measure of how effectively available resources are utilised to generate electricity** - **Grid performance: a measure of the technical performance of the national** **grid relative to the standards set out in the extant codes** - **Commercial performance: a measure of the flow of funds from customers to upstream electricity industry players** ## 2.1 Operational Performance ### The operational performance of the NESI is a measure of how effectively available ### resources are utilised to generate electricity. In evaluating the operational ### performance of the NESI, the following Key Performance Indicators (KPIs) are considered: - **Available generation capacity** - **Plant availability factor** - **Quarterly generation** - **Generation load factor** - **Generation mix** ### 2.1.1 Available generation capacity **In 2024/Q4, the average available generation capacity of the grid-connected power plants increased by 195.98MW (+3.84%) from the 5,100.90MW recorded** #### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * in 2024/Q3 to 5,296.89MW; this was driven by the increase in the available 5 capacity of fifteen (15) out of the twenty-eight (28) grid-connected power plants . The most significant increase in plant available generation capacity in 2024/Q4 compared to 2024/Q3 was recorded in Sapele\_2 (+270.88%). Notable increases in generation capacity between 2024/Q3 and 2024/Q4 were also recorded in Ihovbor\_2 (+46.03%), Odukpani\_1 (+45.92%), Omotosho\_2 (+42.74%), Kainji\_1 (+31.28%), Omotosho\_1 (+30.09%), Olorunsogo\_1 (+23.45%), and Geregu\_2 (+20.98%) power plants (Figure 1). Conversely, there were significant decreases in the average available capacities of Trans Amadi\_1 (-62.93%), Rivers\_1 (-55.75%), Afam\_2 (-39.68%), and Ibom Power\_1 (-36.97%) power plants in 2024/Q4 compared to 2024/Q3. Figure 1: Average Available Capacity (MW) in 2024/Q3 vs. 2024/Q4 The availability factor of a plant is measured as a ratio of the maximum rated output of the plant declared by the operator (available capacity) relative to the maximum rated output specified by the manufacturer (installed capacity). The available capacity of a plant may change from time to time due to several factors, including i) atmospheric conditions at the plant; ii) mechanical availability of the plant 2.1.2 Plant availability factor 5 The nomenclature of generating plants in the NESI has been revised pursuant to Order-NERC/2024/002. The old and new names are contained in Appendix I. * * * (planned and unplanned outages); iii) feedstock availability, etc. The formula for the plant availability factor (PAF) is represented by equation 1: {\\sf l a a t\ a v a a l a b i l i t y\ f a c t o r{=}\\frac{{\\sf a v e r a g e\ o v a i l a b l e\ c a p a c i t y\ (M W)}}{{\\sf i n s t a l l e d c\ a a p c c i i y\ (M W)}}\\times100} (1) The plant availability factor (PAF) is a critical parameter for evaluating the overall health of the upstream segment of the NESI. In 2024/Q4, the average plant availability factor for all grid-connected plants was 38.88%; more than 61.12% of the installed capacity across the twenty-eight (28) grid-connected power plants was not available for dispatch onto the grid across the quarter. Overall, eleven (11) power plants had availability factors above 50%, with Ikeja\_1 power plant recording the highest availability factor at 99.05%. On the other end of the spectrum, Alaoji\_1 recorded a PAF of 0% in 2024/Q4. The PAF of all the grid-connected plants is contained in Table 1. The gross PAF of 38.88% recorded in 2024/Q4 represents a +1.44pp increase relative to the 37.44% PAF that was recorded in 2024/Q3. Significant increases were recorded in the PAF of many thermal plants, including Odukpani\_1 (+19.53pp), Omotosho\_1 (+13.13pp), Ihovbor\_2 (+12.51pp), Sapele\_2 (+12.26pp), Ikeja\_1 (+10.43pp) and Olorunsogo\_1 (+10.24pp) in 2024/Q4 compared to 2024/Q3. Conversely, the PAF of Rivers\_1 and Afam\_2 power plants decreased significantly by –36.07pp and -20.18pp, respectively, between 2024/Q3 and 2024/Q4. Three (3) out of the five (5) grid-connected hydropower plants, Zungeru\_1 (-11.40pp), Shiroro\_1 (-5.80pp), and Dadin-Kowa\_1 (-2.44pp), also recorded decreases in PAF in 2024/Q4 compared to 2024/Q3. Table 1: Plant Availability Factor (%) in 2024/Q3 vs. 2024/Q4 | Plant | Installed capacity(MW) | Average AvailableCapacity(MW) | | Plant Availability Factor(%) | | | --- | --- | --- | --- | --- | --- | | 2024/Q3 | 2024/Q4 | 2024/Q3 | 2024/Q4 | | | | Ikeja\_1 | 110 | 97.48 | 108.96 | 88.62 | 99.05 | | Ihovbor\_2 | 461 | 388.03 | 445.68 | 84.17 | 96.68 | | Dadin-Kowa\_1 | 40 | 35.72 | 34.74 | 89.29 | 86.85 | | Jebba\_1 | 578 | 436.87 | 451.20 | 75.58 | 78.06 | | Kainji\_1 | 760 | 374.06 | 491.08 | 49.22 | 64.62 | | Odukpani\_1 | 625 | 265.81 | 387.87 | 42.53 | 62.06 | | Shiroro\_1 | 600 | 405.81 | 371.01 | 67.63 | 61.83 | | Omotosho\_1 | 335 | 146.14 | 190.11 | 43.62 | 56.75 | | Okpai\_1 | 480 | 292.09 | 262.45 | 60.85 | 54.68 | | Olorunsogo\_1 | 335 | 146.35 | 180.66 | 43.69 | 53.93 | | Geregu\_2 | 435 | 185.53 | 224.46 | 42.65 | 51.60 | \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * | Plant | Installed capacity(MW) | Average Available Capacity(MW) | | Plant Availability Factor(%) | | | --- | --- | --- | --- | --- | --- | | 2024/Q3 | 2024/Q4 | 2024/Q3 | 2024/Q4 | | | | Zungeru\_1 | 700 | 412.58 | 332.81 | 58.94 | 47.54 | | Egbin\_1 | 1,320 | 528.27 | 614.72 | 40.02 | 46.57 | | Igbafo\_1 | 45 | 16.36 | 19.24 | 36.35 | 42.77 | | Delta\_1 | 900 | 366.12 | 341.17 | 40.68 | 37.91 | | Afam\_2 | 650 | 330.61 | 199.43 | 50.86 | 30.68 | | Omoku\_1 | 150 | 54.30 | 44.27 | 36.20 | 29.52 | | Rivers\_1 | 180 | 116.47 | 51.53 | 64.70 | 28.63 | | Geregu\_1 | 435 | 141.24 | 119.59 | 32.47 | 27.49 | | Ibom power\_1 | 190 | 51.47 | 32.44 | 27.09 | 17.08 | | Sapele\_2 | 500 | 22.63 | 83.95 | 4.53 | 16.79 | | Olorunsogo\_2 | 750 | 92.99 | 109.08 | 12.40 | 14.54 | | Ihovbor\_1 | 500 | 44.57 | 65.09 | 8.91 | 13.02 | | Sapele Steam\_1 | 720 | 81.85 | 63.25 | 11.37 | 8.79 | | Afam\_1 | 726 | 54.12 | 58.18 | 7.45 | 8.01 | | Omotosho\_2 | 500 | 8.44 | 12.04 | 1.69 | 2.41 | | Trans Amadi\_1 | 100 | 4.98 | 1.85 | 4.98 | 1.85 | | Alaoji\_1 | 500 | 0.00 | 0.00 | 0.00 | 0.00 | | Total | 13,625 | 5,100.90 | 5,296.89 | 37.44 | 38.88 | \*Red PAF <50, Amber PAF 51≤80, Green PAF >80 2.1.3 Quarterly generation The hourly output produced by all the units in a power plant fluctuates based on grid demand, mechanical operability of the unit(s), and the availability of feedstock. Plants are only dispatched when the load on the grid is sufficient to offtake the energy while operating within acceptable technical limits. The factors that determine the dispatch of a plant include: • Plant availability (mechanical and feedstock) • Load offtake on the grid • Financial competitiveness of the plant in the economic merit order dispatch Both the hourly generation and the total generation decreased by -1.70% respectively in 2024/Q4 compared to 2024/Q3; the hourly generation decreased from 4,280.24MWh/h generated in 2024/Q3 to 4,207.41MWh/h (- 72.83MWh/h), while the total generation decreased from 9,450.76GWh 5 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] Total generation Ave. hourly generation (MWh/h)×24hrs× number of days in the quarter (2) The average hourly generation on the grid in 2024/Q4 was 4,207.41MWh/h, which translates to a total generation of 9,289.95GWh (equation 2). * * * generated in 2024/Q3 to 9,289.95GWh (-160.81GWh) in 2024/Q4. The decrease in quarterly generation despite an increase in power plants' cumulative available generation capacity (section 2.1.1) indicates a reduced load offtake on the grid in 2024/Q4. The most significant decreases in average hourly generation were recorded in Trans Amadi\_1 (-66.30%), Olorunsogo\_2 (-57.66%), Ibom Power\_1 (-49.65%), Rivers\_1 (-48.77%), Afam\_2 (-43.40%) and Sapele Steam\_1 (-41.74%) power plants. The average hourly generation of three (3) hydropower plants; Zungeru\_1 (-29.42%), Dadin-Kowa\_1 (-17.45%), and Shiroro\_1 (-8.46%), also decreased in 2024/Q4 compared to 2024/Q3. Conversely, the average hourly generation of Omotosho\_2 (+347.87%), Sapele\_2 (+275.80%), and Odukpani\_1 (+52.14%) increased significantly in 2024/Q4 compared to 2024/Q3 (Figure 2). Figure 2: Average Hourly Generation (MWh/h) in 2024/Q3 vs. 2024/Q4 Similarly, the cumulative average hourly generation from the grid-connected thermal plants during the quarter also decreased by 49.34MWh/h (--1.71%) compared to 2024/Q3, with eleven (11) out of the twenty-three (23) thermal plants recording decreases in their average hourly generation (Table 2). * * * Table 2: Average Hourly Generation (MWh/h) in 2024/Q3 vs. 2024/Q4 | Plant | Average Hourly Generation (MWh/h) | | Change (MWh/h) | Change(%) | | --- | --- | --- | --- | --- | | 2024/Q3 | 2024/Q4 | | | | | Omotosho\_2 | 1.66 | 7.44 | 5.78 | 347.87 | | Sapele\_2 | 12.02 | 45.18 | 33.16 | 275.80 | | Odukpani\_1 | 203.75 | 309.98 | 106.23 | 52.14 | | Kainji\_1 | 346.67 | 437.43 | 90.76 | 26.18 | | Omotosho\_1 | 130.37 | 159.05 | 28.68 | 22.00 | | Ihovbor\_2 | 327.88 | 386.25 | 58.37 | 17.80 | | Geregu\_2 | 101.38 | 118.64 | 17.27 | 17.03 | | Olorunsogo\_1 | 143.39 | 164.92 | 21.54 | 15.02 | | Ikeja\_1 | 86.38 | 96.21 | 9.83 | 11.38 | | Igbafo\_1 | 17.66 | 19.50 | 1.83 | 10.37 | | Egbin\_1 | 458.06 | 504.67 | 46.60 | 10.17 | | Afam\_1 | 49.95 | 54.86 | 4.91 | 9.83 | | Jebba\_1 | 358.78 | 381.07 | 22.28 | 6.21 | | Alaoji\_1 | 0.00 | 0.00 | 0.00 | 0.00 | | Shiroro\_1 | 296.85 | 271.74 | -25.11 | -8.46 | | Delta\_1 | 341.09 | 303.84 | -37.25 | -10.92 | | Ihovbor\_1 | 24.56 | 20.42 | -4.14 | -16.86 | | Okpai\_1 | 250.41 | 206.98 | -43.43 | -17.34 | | Dadin-Kowa\_1 | 35.13 | 29.00 | -6.13 | -17.45 | | Geregu\_1 | 120.12 | 93.02 | -27.09 | -22.56 | | Omoku\_1 | 62.87 | 46.23 | -16.65 | -26.48 | | Zungeru\_1 | 357.92 | 252.63 | -105.29 | -29.42 | | Sapele Steam\_1 | 49.28 | 28.71 | -20.57 | -41.74 | | Afam\_2 | 327.09 | 185.12 | -141.97 | -43.40 | | Rivers\_1 | 75.25 | 38.55 | -36.69 | -48.77 | | Ibom power\_1 | 43.90 | 22.10 | -21.79 | -49.65 | | Olorunsogo\_2 | 50.81 | 21.51 | -29.30 | -57.66 | | Trans Amadi\_1 | 7.01 | 2.36 | -4.65 | -66.30 | | Total | 4,280.24 | 4,207.41 | -72.83 | -1.70 | The load factor is a measure of the utilisation of a power plant’s available capacity, calculated as the ratio of the average electricity generated over a period to the maximum possible generation (assuming all the available capacity is utilised all the time over the period). A higher load factor means better capacity utilisation thereby reducing the cost per unit of energy and increasing profitability, as fixed costs are spread over a larger amount of dispatched energy. The load factor (also known as the dispatch rate) reflects both the demand for energy and a plant’s ability to supply it. The formula for load factor is represented by equation 3: 2.1.4 Generation load factor * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## Total Energy Generated (MWh) ## Load Factor × 100 (3) ## Ave. Available Capacity (MW)×24hrs×period (in days) # The overall load factor for all grid-connected power plants in 2024/Q4 was # 79.43%; meaning that on average, 20.57% of available energy (MWh) was not # dispatched during the quarter. The load factor in 2024/Q4 (79.43%) is a -4.48pp # decrease compared to the 83.91% load factor recorded in 2024/Q3. A decline in # load factor is expected because while the national grid experienced an increase in # available generation as shown in section 2.1.1, it also recorded a decline in energy # offtake, as explained in section 2.1.3, thereby leading to a reduction in the utilisation # of the capacity of the available plants. # The load factors of the seven (7) power plants with the highest dispatch rates in # 2024/Q4 are presented in Figure 3. Trans Amadi\_1, Omoku\_1, and Igbafo\_1 # recorded dispatch rates of 100%, while three (3) other plants recorded dispatch **rates above 90%. All the hydropower plants (Kainji\_1, Jebba\_1, Dadin-Kowa\_1, Zungeru\_1, and Shiroro\_1) recorded dispatch rates <90% (89.07%, 84.46%,** # 83.47%, 75.91% and 73.24%, respectively), which is inconsistent with the **6** # Commission’s Order No: NERC/189/2019 . The Commission is conducting further **investigations into the root causes of the non-compliance with a view to applying sanctions against the relevant market participants.** # 2.1.5 Generation mix # The electricity generation mix refers to the combination of fuels used to generate # electricity over a period. The electricity generation mix varies across countries and # is influenced by factors such as natural resource availability, government policies, # environmental considerations, type of power plants, energy demand, and seasonal # fluctuations. An ideal energy mix must balance the three key elements of the energy **2 3** # trilemma: i) Energy Security ; ii) Energy Sustainability ; and iii) Energy **4** **Affordability/Equity . The formula for the share of electricity generated by fuel source is given by equation 4:** ## Total electricty generated from fuel i (GWh) ## Share of fueli× 100 (4) ## Total electricity generated from all fuel sources (GWh) # The share of electricity generated from different fuel sources in 2024/Q3 and # 2024/Q4 is presented in Figure 4. The total generation from hydropower plants **The Order stipulates that hydropower plants which are the cheapest energy generation source, should be** **dispatched with priority to reduce wholesale energy costs for consumers** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * (3,029.07GWh) decreased by 51.87GWh (-1.68%) in 2024/Q4 compared to 2024/Q3 (3,080.94GWh). The contribution of hydropower to the energy mix in 2024/Q4 was 32.61% (3,029.07GWh out of 9,289.95GWh), which represents a +1pp change compared to its contribution in 2024/Q3 (32.60%). Figure 3: Load Factor (%) in 2024/Q3 vs. 2024/Q4 Figure 4: Electricity Generated by Energy Sources (%) in 2024/Q3 vs. 2024/Q4 * * * 2.2 Grid Performance The Transmission Company of Nigeria (TCN) which has the responsibility of transporting energy from power plants to DisCos holds two licences; Transmission Service Provider (TSP) and System Operator (SO). The TSP owns and maintains the transmission infrastructure, while the SO is responsible for maintaining system stability, load balance, load dispatch, and undertaking market operations responsibilities. To assess the performance of the grid, the Commission focuses on the following four (4) Key Performance Indicators (KPIs) that relate to power transmission: • Transmission loss factor • Stability of grid frequency • Voltage fluctuation • Incidence of system collapse 2.2.1 Transmission loss factor Transmission Loss Factor (TLF) refers to the proportion of the total energy sent out by the power plants that was either lost in transmission or utilised in the transmission Transmission Loss Factor (TLF) refers to the proportion of the total energy sent out by the power plants that was either lost in transmission or utilised in the transmission by the power plants that was either lost in transmission or utilised in the transmission station, i.e., neither delivered to the DisCos nor exported to international customers. There is an inverse relationship between the TLF and the efficiency of the transmission system; i.e. a decline in the TLF indicates an improvement in transmission efficiency over a given period. The formula for TLF is represented by equation 5: There is an inverse relationship between the TLF and the efficiency of the transmission system; i.e. a decline in the TLF indicates an improvement in transmission efficiency over a given period. The formula for TLF is represented by equation 5: \\mathsf{T L F}\ =\ \\left(1\\cdot\\frac{\\mathsf{E n e r g y ~~d e l i v e r e d~~ t o ~~a l l~~ D i s C o s+E n e r g y ~~E x p o r t e d}}{\\mathsf{E n e r g y~~ S e n t ~~o u t~~ b y ~~a l l~~ G e n C o s}}\\right)\ \\times100 ×100 (5) The 9.23% TLF recorded in 2024/Q4 represents an underperformance of +2.23pp relative to the MYTO target for 2024 – 7.00%. The TLF target represents the maximum efficient loss in transmission for which the Transmission Service Provider (TSP)’s revenue requirement allows for recovery from customers. Exceeding the TLF target means that the TSP will not be able to earn its full revenue requirement because there is no provision to recover the revenues needed to cover the excess (inefficient) losses. Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) July- December 2024 2.2.2 Grid frequency As specified in section 10.1.2 of the Grid Code, the standard frequency for operation on the Grid is 50Hz. The code provides that under normal circumstances, the grid can operate within a deviation of ±0.5%, i.e. between a lower limit of 49.75Hz and an upper limit of 50.25Hz. Section 10.1.2 of the Grid Code further provides that in extreme circumstances, the grid may operate within a tolerance of ±2.5%, i.e. system frequency may reach a lower bound stress limit of 48.75Hz and an upper bound stress limit of 51.25Hz. * * * During 2024/Q4, the average lower daily system frequency was 49.39Hz, while the average upper daily system frequency was 50.91Hz, which translates to a range of 1.52Hz (Figure 6). Comparatively, in 2024/Q3, the average lower daily system frequency was 49.56Hz, while the upper daily system frequency was 50.75Hz, which translated to a range of 1.19Hz. The 0.33Hz (+27.73%) increase in the average quarterly frequency range recorded in 2024/Q4 relative to 2024/Q3 indicates a decline in the operational performance of the National Grid. 2.2.3 Voltage fluctuation The average lower and average upper frequencies were outside the frequency range specified in the Grid Code throughout 2024/Q4. The operation of the grid outside the normal frequency limits indicates an imbalance in the supply and demand of electricity on the grid. This imbalance is primarily caused by the lack of a Supervisory Control and Data Acquisition (SCADA) system. The System Operator (SO) has invested in an IoT-based solution to improve real-time visibility into the operations of the Grid. However, the inability to remotely operate the entire system as would be possible under the SCADA system continues to pose challenges to the SO’s ability to operate the grid within the normal frequency limits provided in the grid code. * * * consumers and result in substantial commercial losses. Extreme cases of voltage fluctuations, particularly at the distribution network level, can cause severe damage to industrial machines, thereby compelling the industrial customers to seek alternative sources of power outside of the National Grid. The system voltage pattern from July to December 2024 is illustrated in Figure 7. The average lower and upper operating voltage bounds for the transmission network in 2024/Q4 were 294.37kV and 351.35kV, respectively; both values are outside the respective allowable limits specified in the Grid Code. As explained for frequency in section 2.2.2, the measure of the health of a system over a given period can also be evaluated based on the range between the average upper daily system voltage and the average lower daily system voltage. The lower the range, the more stable the system has been. By way of comparison, the range between the Grid’s average lower and upper operating voltage for 2024/Q4 was 56.98kV which is higher than the 53.04kV (average lower and upper voltages of 299.64kV and 352.68kV respectively) that was recorded in 2024/Q3, further reinforcing the hypothesis reported in section 2.2.2 that there was a decline in grid performance in 2024/Q4. The Commission continues to engage with TCN and other stakeholders to ensure sustained efforts at keeping the system voltage within the limits contained in the grid code and thus providing a safe and reliable electricity supply to end users. Figure 7: Monthly System Voltage (kV) from July - December 2024 * * * 2.2.4 System collapse The national power grid is a vast network of electrical transmission lines that link The national power grid is a vast network of electrical transmission lines that link power stations to end-use customers across the nation and is designed to function power stations to end-use customers across the nation and is designed to function within specific stability boundaries, including voltage (330kV ± 5.0%) and frequency (50Hz ± 0.5%). Any deviation from these stability ranges can result in decreased power quality and, in severe cases, cause widespread power outages ranging from power stations to end-use customers across the nation and is designed to function within specific stability boundaries, including voltage (330kV ± 5.0%) and frequency (50Hz ± 0.5%). Any deviation from these stability ranges can result in decreased power quality and, in severe cases, cause widespread power outages ranging from a partial collapse of a section of the grid to a full system-wide blackout. a partial collapse of a section of the grid to a full system-wide blackout. a partial collapse of a section of the grid to a full system-wide blackout. 1300k V\\pm5.0% 150H z\\pm0.5% While the SO is responsible for ensuring that all parameters are maintained within their respective tolerance thresholds, the primary parameter that the SO tracks to avoid system disturbances is frequency. When the electricity demand is higher than the supply, the grid frequency drops. Conversely, if supply surpasses demand, the frequency increases. In reaction to the grid operating at a frequency outside of the normal operation range (especially when the frequency is too low), safety settings on generation units can cause the units to shut down. This response can worsen the frequency imbalance, potentially causing a cascade of further shutdowns across generation units and resulting in a full or partial system collapse. There were three (3) incidents of total collapse and two (2) incidents of partial collapse on the national grid in 2024/Q4. The partial collapse occurred on 14 October and 05 November 2024, while the total collapses occurred on 19 October, 07 November, and 11 December 2024, respectively. The details of the incidents are contained in Table 3. Table 3: System Collapse in 2024/Q4 | SN | Date | Type of Collapse | Time of Collapse | Time of full system restoration | Remarks | | --- | --- | --- | --- | --- | --- | | 1 | 14/10/2024 | Partial | 18:48Hrs | 15/10/202416:14Hrs | Restoration was delayed due to the unavailability of some critical circuits. | | 2 | 19/10/2024 | Full | 08:15Hrs | 17:57Hrs | | | 3 | 05/11/2024 | Partial | 13:52Hrs | 23:37Hrs | Restoration was delayed due to the unavailability of some critical circuits. | | 4 | 07/11/2024 | Full | 11:29Hrs | 08/11/202410:59Hrs | | | 5 | 11/12/2024 | Full | 13:32Hrs | 20:07Hrs | | * * * ### FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # 2.3 Commercial Performance ## The commercial performance of the NESI is a measure of the flow of funds from ## customers to upstream electricity industry players. The financial performance is ## critical because funds are required to keep all the players along the value chain **operational. In evaluating the commercial performance of the NESI for 2024/Q4, the following parameters are considered:** - **Energy offtake performance** • **Energy billed and billing efficiency** - **Revenue and collection efficiency** • **Aggregate Technical, Commercial and Collection (ATC&C) loss** - **Remittances to the Market Operator (MO) and the Nigerian Bulk Electricity Trading Company (NBET).** ## 2.3.1 Energy offtake performance ## The Partial Activation of Contract (PAC) regime, which took effect in July 2022, **defines the target volume of energy to be off-taken by DisCos at any time as their** ## Partially Contracted Capacity (PCC). As explained in prior reports, under the PAC ## regime, DisCos have take-or-pay obligations on their PCC which means that they ## must pay for available capacity irrespective of their offtake. This structure is **consistent with international best practices for long-term contract-based power procurement and ensures that GenCos earn capacity payments (cover fixed costs)** ## to compensate them for making their generation units available. ## The PAC regime also mandates GenCos or TCN to compensate DisCos through ## Liquidated Damages (LDs) in the event of capacity shortfalls. Under the single-buyer ## model being operated in the NESI, when there is a shortfall in generation, LDs from **GenCos are treated as net-offs in the invoices issued to NBET thereby reducing the net payables due from DisCos.** ## When there is sufficient generation capacity, every DisCo will be directed by the SO ## to offtake its entire PCC. When generation falls below the required target, the SO ## prorates the available capacity among all DisCos based on their respective PCCs – ## “Available PCC”. The ratio between a DisCo’s energy offtake and the available ## PCC is known as the “energy offtake performance”. The formula for determining a ## DisCo’s energy offtake performance is represented by equation 6: ### Energy Offtake **Energy Offtake performance (%) =** () **× 100 (6)** **Available PCC** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # Considering the large disparity between the energy on the national grid and # customer demand, it is expected that DisCos will offtake 100% of their available # PCC at all times. However, the Commission continues to observe with concern that # many DisCos do not take their full PCC due to a combination of technical limitations # as well as load rejection by the DisCos largely due to commercial reasons, i.e., # instances where DisCos deliberately reduced energy supply to areas with high commercial and collection losses. # It is noteworthy that when DisCos have offtake ratios below 100%, they incur # increased wholesale energy costs as they still have to pay NBET/GenCos for # unutilised capacity. The tariff methodology utilised by the Commission does not allow **DisCos to recover the resultant additional wholesale energy costs (relative to the volume of energy off-taken) from customers.** # In 2024/Q4, the average energy offtake by DisCos at their trading points was **3,360.77MWh/h, which represents a decrease of 84.36MWh/h (-2.45%) when compared to 3,445.13MWh/h off-take in 2024/Q3. The decrease in the average** # energy offtake at trading points can be attributed to the decrease in energy **available for offtake (PCC), which was a result of the decrease in generation during the quarter explained in section 2.1.3.** **The cumulative energy offtake performance of DisCos during the quarter was 94.61%. Benin (99.57%), Enugu (96.82%), Port Harcourt (96.62%), Ibadan** # (96.60%) and Ikeja (96.15%) DisCos took >95% of their available PCC during the # quarter. All the other DisCos took <95% of available PCC with Yola DisCo (76.89%) # recording the worst offtake performance (Table 4). At an aggregate level, the # energy offtake performance of the DisCos increased by +4.14pp between 2024/Q4 # and 2024/Q3; this is consistent with the trends have been reported in prior quarters; # a reduction in available PCC across 2 quarters often leads to an increase in energy **offtake performance while an increase in available PCC across 2 quarters often leads to a decrease in energy offtake performance.** # The Orders on Performance Monitoring Framework for DisCos (NERC/2024/086 – **096) issued on 05 July 2024 mandates that DisCos have to take at least 95% of** **their available PCC or face sanctions by the Commission. Pursuant to these** **provisions, the Commission has already commenced the appropriate enforcement** **actions against DisCos that did not meet the minimum offtake requirement for 2024/Q4.** ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Table 4: DisCo energy offtake performance in 2024/Q3 vs. 2024/Q4 | DisCos | 2024/Q3 | | | 2024/Q4 | | | | --- | --- | --- | --- | --- | --- | --- | | Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance(%) | Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance(%) | | | Abuja | 509.40 | 588.74 | 86.52 | 526.83 | 573.32 | 91.89 | | Benin | 314.46 | 320.83 | 98.01 | 346.46 | 347.96 | 99.57 | | Eko | 445.31 | 491.07 | 90.68 | 454.74 | 481.42 | 94.46 | | Enugu | 288.14 | 292.08 | 98.65 | 294.17 | 303.82 | 96.82 | | Ibadan | 434.05 | 458.33 | 94.70 | 437.59 | 452.98 | 96.60 | | Ikeja | 512.08 | 571.77 | 89.56 | 539.20 | 560.79 | 96.15 | | Jos | 194.26 | 220.44 | 88.12 | 136.43 | 143.63 | 94.99 | | Kaduna | 202.16 | 246.62 | 81.97 | 149.64 | 170.67 | 87.68 | | Kano | 215.57 | 249.50 | 86.40 | 149.08 | 162.97 | 91.47 | | PH | 253.81 | 266.86 | 95.11 | 263.96 | 273.18 | 96.62 | | Yola | 75.89 | 101.72 | 74.61 | 62.67 | 81.50 | 76.89 | | All DisCos | 3,445.13 | 3,807.98 | 90.47 | 3,360.77 | 3,552.26 | 94.61 | 2.3.2 Energy billed and billing efficiency Billing efficiency measures the proportion of energy billed to customers (including metered and unmetered customers) relative to the total energy supplied to a given area over a period. The key drivers of billing losses are i) technical - energy loss along the distribution network and ii) commercial - DisCo's inability to account for 100% of the energy supplied. Commercial losses could either be a result of theft on the part of the customer, i.e. a meter bypass, or other factors under the DisCo’s control, such as poor customer enumeration and the proliferation of inaccurate meters. A billing efficiency of 70% means that only ₦70.00 worth of electricity is billed out of ₦100.00 worth of electricity distributed by DisCos. The formula for billing efficiency is represented by equation 7: The disaggregated performance of the DisCos shows that Ibadan DisCo recorded the highest billing efficiency of 89.99%, while Kaduna DisCo recorded the lowest The total energy offtake by all DisCos in 2024/Q4 was 7,420.58GWh, and the total energy billed was 6,207.84GWh, which translates to a billing efficiency of 83.66%. Comparatively, the total energy received and billed in 2024/Q3 were 7,606.84GWh and 6,249.21GWh, respectively, which translated to a billing efficiency of 82.15%. This means that at an aggregate level, DisCos recorded a +1.51pp increase in billing efficiency between 2024/Q3 and 2024/Q4. \ {\\tt{S i l l i n g\ E f f c c i e n c y=}}\\left(\ \ \\frac{{\\tt{T o t a l\ e n e r g y\ b i l l e d\ t o\ c u s t o m e r s\ (G W h)}}}{{\\tt{T o t a l\ e n e r g y\ r e c e v i v e d\ b y\ t h e n n e r w w\ W W h}}}\\right)\\times100 ) × 100 (7) * * * billing efficiency of 70.87%. A quarter-on-quarter comparison of billing efficiency shows that seven (7) DisCos recorded improvements in their billing efficiencies in 2024/Q4 relative to 2024/Q3, with Jos and Kaduna DisCos recording the most significant increases of +18.38pp and +6.86pp, respectively. Conversely, four (4) DisCos recorded decreases in billing efficiency with Kano DisCo (-3.99pp) recording the most significant decrease (Table 5). Table 5: Energy received and billing efficiency by DisCos in 2024/Q3 vs. 2024/Q4 | DisCos | 2024/Q3 | | | 2024/Q4 | | | | --- | --- | --- | --- | --- | --- | --- | | Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) | Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) | | | Abuja | 1,124.76 | 911.00 | 81.00 | 1,163.25 | 918.00 | 78.92 | | Benin | 694.32 | 585.07 | 84.27 | 764.99 | 664.68 | 86.89 | | Eko | 983.24 | 878.00 | 89.30 | 1,004.07 | 895.65 | 89.20 | | Enugu | 636.21 | 477.00 | 74.98 | 649.53 | 475.00 | 73.13 | | Ibadan | 958.37 | 862.31 | 89.98 | 966.20 | 869.45 | 89.99 | | Ikeja | 1,130.67 | 952.53 | 84.24 | 1,190.55 | 1004.99 | 84.41 | | Jos | 428.92 | 268.78 | 62.66 | 301.24 | 244.11 | 81.04 | | Kaduna | 446.37 | 285.73 | 64.01 | 330.41 | 234.17 | 70.87 | | Kano | 475.98 | 415.89 | 87.38 | 329.16 | 274.47 | 83.39 | | Port Harcourt | 560.41 | 469.26 | 83.74 | 582.82 | 503.02 | 86.31 | | Yola | 167.57 | 143.65 | 85.73 | 138.37 | 124.29 | 89.83 | | All DisCos | 7,606.84 | 6,249.21 | 82.15 | 7,420.58 | 6,207.84 | 83.66 | Collection efficiency is the ratio of the amount that has been collected from customers relative to the amount billed to them by the DisCos. The significant under-recovery of the invoices issued to customers by DisCos is driven by a lack of willingness of customers to pay bills when due, unsatisfactory DisCos’ services and inadequate customer metering, among other challenges. A collection efficiency of 70%, for Collection efficiency is the ratio of the amount that has been collected from customers relative to the amount billed to them by the DisCos. The significant under-recovery of the invoices issued to customers by DisCos is driven by a lack of willingness of customers to pay bills when due, unsatisfactory DisCos’ services and inadequate customer metering, among other challenges. A collection efficiency of 70%, for instance, implies that for every ₦100.00 worth of energy billed to customers by DisCos, approximately ₦30.00 remained unrecovered from the billed customers. The formula for collection efficiency is represented by equation 8: The formula for collection efficiency is represented by equation 8: The formula for collection efficiency is represented by equation 8: * * * {\\sf C o l l e c t i o n\ E f f c c i n n c y}=\ \ \\left(\ \\frac{{\\sf T o l a l\ R e v e n u e\ C o l l e t t d\ (H)}}{{\\sf T o l a l\ B i l l e\ A A m o u n t\ (H)}}\\right)\\times100 ) × 100 (8) The total revenue collected by all DisCos in 2024/Q4 was ₦509.84 billion out of the ₦658.40 billion that was billed to customers. This translates to a collection efficiency of 77.44%. In comparison, the total revenue collected by all DisCos in 2024/Q3 was ₦466.69 billion out of the ₦626.02 billion billed to customers, which translated to a 74.55% collection efficiency. The 77.44% collection efficiency recorded in 2024/Q4 is +2.89pp higher than the collection efficiency recorded in 2024/Q3 (74.55%). The summary of the revenue collection performance of all DisCos is contained in Table 6. Similar to the trend observed in 2024/Q3, Eko (90.00%) and Ikeja (82.63%) DisCos recorded the highest collection efficiencies in 2024/Q4. Conversely, Jos DisCo recorded the lowest collection efficiency at 49.68%. A comparison of DisCos performance shows that eight (8) DisCos recorded improvements in collection efficiency between 2024/Q3 and 2024/Q4, with Yola improvements in collection efficiency between 2024/Q3 and 2024/Q4, with Yola (+13.93pp) and Kano (+9.88pp) recording the greatest improvements. Conversely, the remaining three (3) DisCos recorded declines in collection efficiency with Jos (- 3.61pp) and Abuja (-3.39pp) DisCos having the most significant declines over the period. improvements in collection efficiency between 2024/Q3 and 2024/Q4, with Yola (+13.93pp) and Kano (+9.88pp) recording the greatest improvements. Conversely, the remaining three (3) DisCos recorded declines in collection efficiency with Jos (- 3.61pp) and Abuja (-3.39pp) DisCos having the most significant declines over the | DisCos | 2024/Q3 | | | 2024/Q4 | | | | --- | --- | --- | --- | --- | --- | --- | | Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) | Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) | | | Abuja | 99.26 | 78.28 | 78.87 | 107.91 | 81.45 | 75.48 | | Benin | 50.77 | 41.09 | 80.94 | 56.28 | 45.69 | 81.17 | | Eko | 103.11 | 87.02 | 84.40 | 107.31 | 96.58 | 90.00 | | Enugu | 46.71 | 36.07 | 77.23 | 49.24 | 39.49 | 80.20 | | Ibadan | 74.96 | 57.60 | 76.84 | 78.64 | 60.91 | 77.46 | | Ikeja | 99.73 | 83.55 | 83.78 | 123.35 | 101.92 | 82.63 | | Jos | 30.73 | 16.37 | 53.29 | 28.67 | 14.25 | 49.68 | | Kaduna | 24.57 | 11.40 | 46.42 | 19.45 | 10.80 | 55.52 | | Kano | 43.89 | 20.64 | 47.03 | 33.72 | 19.19 | 56.91 | | Port Harcourt | 41.31 | 29.22 | 70.76 | 44.01 | 33.36 | 75.79 | | Yola | 10.98 | 5.41 | 49.31 | 9.82 | 6.21 | 63.24 | | All DisCos | 626.02 | 466.69 | 74.55 | 658.40 | 509.84 | 77.44 | In 2024/Q4, billing and collection efficiencies improved by +1.51pp and +2.89pp, respectively, compared to 2024/Q3. Based on historical trends, these improvements * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # can be attributed to the reduced energy offtake during the quarter compared to # 2024/Q3. Typically, when DisCos offtake less energy, they are able to dedicate a # higher share of their energy to areas with lower billing and collection inefficiencies. # The most proven methods to improve energy accounting and revenue recovery are # accurate customer enumeration and the installation of end-use customer meters. The # Commission issued the Order on the operationalisation of Tranche A of the Meter # Acquisition Fund (MAF) in 2024/Q2. The Order, which became effective on 24 June # 2024, directed DisCos to utilise the first tranche of disbursement from the MAF # scheme to procure and install meters for unmetered Band A customers within their franchise areas. # As of December 2024, DisCos have metered more than 4,000 Band A customers # through the MAF scheme. In addition to the MAF, DisCos are expected to continue # to utilise any of the metering frameworks provided for in the NERC MAP and NMMP # metering regulation (2021) to improve end-use customer metering in their franchise # areas. This will reduce commercial and collection losses, thereby improving the flow # of funds to upstream market participants in the NESI. # 2.3.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss # The Aggregate Technical, Commercial and Collection (ATC&C) loss is a summation **of – i) billing losses incurred by a DisCo due to its inability to bill 100% of energy** # delivered to customers (technical and commercial losses); and ii) collection losses # arising from the DisCo’s inability to collect 100% of the bills issued to customers. The # ATC&C loss is a critical performance-setting parameter for tariff computation as the # MYTO makes allowance for target ATC&C loss levels for each DisCo. # The target ATC&C reflects the efficient operational losses which the DisCo is # expected to incur in its operations and this is recoverable from the allowed tariffs. # The target ATC&C usually reduces over time as DisCos make investments that are # geared towards improving operational efficiency. ATC&C loss is made up of the following components: **a. Technical Loss: heat loss due to load flow in electrical lines and transformation loss in transformers.** **b. Commercial Loss: due to discrepancies in meter reading, erroneous billing, unmetered consumption, or energy theft;** # c. Collection Loss: unpaid bills. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * The formula for ATC&C loss is represented by equation 9: ATC&C Loss \[1 - (Billing Efficiency × Collection Efficiency)\] × 100 (9) ATC&C Loss \[1 - (Billing Efficiency × Collection Efficiency)\] × 100 (9) Any DisCo that can outperform its allowed ATC&C (i.e., has a lower actual ATC&C than the target used to compute its cost-reflective tariff) will earn more returns on its set tariffs. Conversely, any DisCo that fails to meet its allowed ATC&C (i.e., has a higher actual ATC&C than the target) will not be able to earn the total revenue requirement upon which its tariffs have been determined; this could pose risks to its long-term financial position. The aggregate ATC&C loss recorded across all 11 DisCos in 2024/Q4 was 35.22%, which comprised 16.34% in technical and commercial losses and 22.56% in collection loss (Table 7.) The aggregate ATC&C loss of 35.22% recorded in 2024/Q4 is +10.49pp higher than the allowed aggregate efficient loss target (24.73%) applied in the computation of the tariffs in the MYTO for the year 2024 and translates to a cumulative revenue loss of ₦139.08 billion for the DisCos. 7 Only Yola (Actual - 43.19% vs. target - 56%) and Eko (Actual - 19.72% vs. target - 20.07%) DisCos achieved their ATC&C loss targets in 2024/Q4. This means that only these two DisCos will be able to earn their revenue requirements as designed in their tariffs. The other nine (9) DisCos failed to achieve their ATC&C loss targets with the widest variance (target – actual) being recorded by Kaduna (-35.65pp), Kano (-27.55pp) and Jos (-27.02pp) DisCos. These excess ATC&C losses (inefficiencies) are not recoverable from customers and may compromise the longterm financial positions of the affected DisCos. The average ATC&C loss recorded in 2024/Q4 (35.22%) was -3.88pp lower (better performance) than what was recorded in 2024/Q3 (39.10%). Nine (9) DisCos recorded improvements in their ATC&C loss performance in 2024/Q4 compared to 2024/Q3, with Yola (-13.86pp) and Kaduna (-10.19pp) DisCos recording the greatest improvements. Conversely, the remaining two (2) DisCos (Abuja; +4.30pp and Ikeja; +0.47pp) recorded declines in their ATC&C loss performances between 2024/Q4 and 2024/Q3 (Table 7 ). 7 Yola DisCo has a high ATC&C loss allowance due to the provisions contained in its performance agreement upon reprivatisation in 2021. 21 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Table 7: ATC&C Loss (%) by DisCos in 2024/Q3 vs. 2024/Q4 | DisCo | MYTO Target(%) | ATC&C(%) | | Variance(pp) | | | --- | --- | --- | --- | --- | --- | | 2024 | 2024/Q3 | 2024/Q4 | 2024/Q3 | 2024/Q4 | | | Abuja | 25.00 | 36.13 | 40.43 | -11.13 | -15.43 | | Benin | 25.00 | 31.80 | 29.47 | -6.80 | -4.47 | | Eko | 20.07 | 24.62 | 19.72 | -4.55 | 0.35 | | Enugu | 25.00 | 42.89 | 41.35 | -17.89 | -16.35 | | Ibadan | 25.00 | 30.86 | 30.30 | -5.86 | -5.30 | | Ikeja | 18.73 | 29.78 | 30.25 | -11.05 | -11.52 | | Jos | 32.72 | 66.81 | 59.74 | -34.09 | -27.02 | | Kaduna | 25.00 | 70.84 | 60.65 | -45.84 | -35.65 | | Kano | 25.00 | 59.82 | 52.55 | -34.82 | -27.55 | | Port Harcourt | 25.00 | 41.70 | 34.58 | -16.70 | -9.58 | | Yola | 56.00 | 57.05 | 43.19 | -1.05 | 12.81 | | All DisCos | | | | | | | MYTO Level | 24.73 | | | | | | Total Technical, Commercial & Collection losses | - | 39.10 | 35.22 | | | | Technical & Commercial losses | - | 18.32 | 16.34 | | | | Collection losses | - | 25.45 | 22.56 | | | 2.3.5 Market Remittance Under the account administration mechanism set up by the CBN in 2014 as part of the Nigerian Electricity Market Stabilisation Facility (NEMSF) intervention, all the collections of the DisCos are escrowed. The DisCos only have access to their revenues after relevant deductions towards their loan obligations have been made. This escrow mechanism also provides visibility into the financial performance of the DisCos with respect to collections. Prompt payment of upstream invoices is critical for securing the availability of generation and transmission capacities. The waterfall regime pushes DisCos to boost their collections because most of their allowed revenues rank below the payment of market obligations in the waterfall. * * * ### FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # 2.3.5.1 Market Remittance to NBET ## In the absence of cost-reflective tariffs, the Government undertakes to cover the ## resultant gap (between the cost-reflective and allowed tariff) in the form of tariff ## subsidies. For ease of administration, the subsidy is only applied to the generation ## cost payable by DisCos to NBET at source in the form of a DisCo’s Remittance ## Obligation (DRO). The DRO represents the total GenCo invoice that is billed to the **8** ## DisCos by NBET based on what the allowed DisCo tariffs can cover . Furthermore, **DisCos are expected to remit 100% of the invoices received from the MO for transmission and administrative service costs.** ## As explained in prior reports, the DRO regime replaced the Minimum Remittance **9** ## Obligation (MRO) framework in January 2024, and DisCos are expected to pay ## 100% of their DROs. The transition to the DRO regime was necessitated by the risk ## of unpaid tariff subsidy debts encumbering the balance sheets of the DisCos, thereby ## preventing them from raising finance to undertake critical investments in their ## distribution network. Thus, the portion of GenCo invoices not covered by DRO is the ## tariff subsidy which is invoiced directly to the Federal Ministry of Finance by NBET. ## The total NBET invoices and final obligation for each DisCo (based on DRO) during **2024/Q4 are summarised in Table 8. It is important to note that due to the absence** ## of cost-reflective tariffs across all DisCos, the Government incurred a subsidy **10** ## obligation of ₦471.69 billion (56.65% of total NBET invoice) in 2024/Q4. ## Between 2024/Q3 and 2024/Q4, the subsidy obligation of the government ## increased by ₦7.57 billion, from ₦464.12 billion (54.71% of the total GenCo ## invoice) to ₦471.69 billion (56.65% of the total GenCo invoice). The increase in **the subsidy obligation of the FGN is a result of the FGN policy to freeze allowed** ## tariffs paid by customers despite the increase in the cost-reflective tariffs across the quarters. **8** **The outstanding portion of GenCo invoice not covered by allowed tariffs and thus not billed to the DisCos is** **to be covered by the FGN in the form of tariff subsidies.** **9** **For the MRO framework, DisCos are invoiced 100% of energy cost but only expected to pay MRO share of** **the invoice. The outstanding balance is only cleared from the DisCo’s record when the FGN subsidy is paid to** **NBET** **Monthly subsidy obligation during the quarter; Oct - ₦159 billion, Nov - ₦149 billion and Dec - ₦163** **billion.** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q4 | DisCos | Total NBET Invoice(N'billion) | Final Obligation(N'billion) | | --- | --- | --- | | Abuja | 132.52 | 61.46 | | Benin | 83.39 | 36.17 | | Eko | 112.91 | 57.38 | | Enugu | 72.23 | 29.91 | | Ibadan | 107.51 | 45.18 | | Ikeja | 132.73 | 66.68 | | Jos | 33.73 | 11.01 | | Kaduna | 38.41 | 12.21 | | Kano | 37.47 | 12.98 | | Port Harcourt | 64.47 | 26.14 | | Yola | 17.29 | 1.85 | | All DisCos | 832.67 | 360.97 | In 2024/Q4, the DRO-adjusted invoice from NBET to the DisCos was ₦360.97 11 billion while the total remittance made was ₦336.63 billion, which translates to 93.26% remittance performance. Comparatively, in 2024/Q3, the DRO-adjusted invoice from NBET to DisCos was ₦382.90 billion, and the total remittance was ₦324.83 billion, which translated to 84.83% remittance performance. The +8.43pp increase in DisCos’ remittance performance to NBET between 2024/Q3 and 2024/Q4 can be attributed to two (2) things; i) the -5.73% decrease in DROadjusted invoice across the quarters and ii) the +9.25% increase in collections by DisCos in 2024/Q4 compared to 2024/Q3 (₦509.84 billion vs. ₦466.69 billion). Disaggregated remittance performance of the DisCos to NBET in 2024/Q4 shows that Eko, Ikeja and Yola DisCos achieved 100% remittance performance to NBET while Abuja (97%), Benin (90%), Enugu (90%), Ibadan (93%), Kano (95%) and Port Harcourt (90%) achieved ≥90% remittance performance. Kaduna DisCo recorded the lowest remittance performance of 41.02% (Figure 8). A quarter-onquarter analysis showed that all DisCos recorded improvements in remittance performance to NBET in 2024/Q4 compared to 2024/Q3. Kano (+28.59pp), Jos (+15.50pp) and Port Harcourt (+14.11pp) DisCos recorded the greatest improvements in remittance performance to NBET across the two quarters. 11 Total NBET invoice for 2024/Q4 without adjustment for DRO (total bill issued by GenCos) is ₦832.67 billion 24 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### FOURTH QUARTER 2024 NERC QUARTERLY REPORTS **NBET Invoice NBET Remittance** **70.0** **60.0** **50.0** **Billion** ₦ **(** **40.0** **30.0** **Remittances** **20.0** **10.0** **85 85** **0.0** **1\. 1.** **Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano Port Harcourt Yola** **Performance 97% 90% 100% 90% 93% 100% 80% 41% 95% 90% 100%** **Figure 8: DisCos Remittance Performances to NBET in 2024/Q4** # 2.4.5.2 Market Remittance to MO ## The Market Operator issues invoices to DisCos for energy transmission and ## administrative services. In 2024/Q4, DisCos made a total remittance of ₦42.30 ## billion against the cumulative invoice of ₦47.89 billion issued by the MO. This ## payment translates to 88.32% remittance performance and is a +11.44pp increase ## when compared to 76.88% remittance performance recorded in 2024/Q3 when ## DisCos remitted ₦45.18 billion out of ₦58.77 billion invoice issued by the MO. ## The disaggregated remittance performance of the DisCos to MO shows that Yola, ## Abuja and Ikeja DisCos recorded the highest remittance performances of 100%, ## 94.65%, and 93.76%, respectively, while Kaduna had the lowest remittance ## performance of 16.47% (Figure 9). Between 2024/Q3 and 2024/Q4, all DisCos ## except Ikeja and Kaduna recorded improvements in their remittance performance **to MO with Jos (+18.15pp), Kano (+16.42pp) and Port Harcourt (+14.24pp) recording the most significant improvements.** ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Figure 9: DisCos Remittance Performances to MO in 2024/Q4 2.4.5.3 Market Remittance to NBET and MO Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q4 The cumulative DisCos’ remittance to NBET and MO in 2024/Q4 is presented Table 9. | DisCos | DRO Adjusted Invoice(NE' Billion) | | | Actual Remittance(NE' Billion) | | | RemittancePerformance(%) | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | NBET | MO | NBET+MO | NBET | MO\* | NBET+MO | 2024/Q3 | 2024/Q4 | | | Abuja | 61.46 | 8.88 | 70.34 | 59.33 | 8.40 | 67.73 | 89.56 | 96.29 | | Benin | 36.17 | 5.20 | 41.37 | 32.56 | 4.37 | 36.93 | 83.59 | 89.27 | | Eko | 57.38 | 6.28 | 63.66 | 57.38 | 5.59 | 62.97 | 98.55 | 98.92 | | Enugu | 29.91 | 4.85 | 34.76 | 27.03 | 4.31 | 31.35 | 81.14 | 90.17 | | Ibadan | 45.18 | 7.09 | 52.27 | 42.12 | 6.50 | 48.61 | 87.67 | 93.00 | | Ikeja | 66.68 | 8.52 | 75.20 | 66.68 | 7.99 | 74.67 | 93.89 | 99.29 | | Jos | 11.01 | 0.85 | 11.86 | 8.84 | 0.63 | 9.47 | 63.13 | 79.89 | | Kaduna | 12.21 | 1.19 | 13.40 | 5.01 | 0.20 | 5.21 | 27.82 | 38.83 | | Kano | 12.98 | 0.58 | 13.57 | 12.38 | 0.42 | 12.80 | 65.04 | 94.34 | | P/Harcourt | 26.14 | 3.88 | 30.02 | 23.46 | 3.33 | 26.79 | 75.09 | 89.23 | | Yola | 1.85 | 0.57 | 2.41 | 1.85 | 0.57 | 2.41 | 91.27 | 100.00 | | All DisCos | 360.97 | 47.89 | 408.86 | 336.63 | 42.30 | 378.94 | 83.77 | 92.68 | \*Based on the provisions of the SLA between the TCN and DisCos, the TSP has to pay a total of ₦2.41 billion to Jos, Kaduna, Kano and Yola DisCos due to service shortfalls in October and November 2024. The breakdown of the outstanding payments are as follows: Jos (Oct; ₦0.27 billion, Nov; ₦0.37 billion), Kaduna (Oct; ₦0.37 billion), Kano (Oct; ₦0.60 billion, Nov: ₦0.51 billion) and Yola (Oct; ₦0.26 billion, Nov; ₦0.01 billion). * * * 2.4.5.4 Market Remittance by Other Customers The remittances made by bilateral customers (domestic and international) and special customers for invoices issued in 2024/Q4 by the MO are detailed in Table 10\. The six (6) international bilateral customers being supplied by GenCos in the NESI made a payment of $5.21 million against the cumulative invoice of $14.05 NESI made a payment of $5.21 million against the cumulative invoice of $14.05 million issued by the MO for services rendered in 2024/Q4, translating to a remittance performance of 37.08%. The domestic bilateral customers made a cumulative payment of ₦1,252.58 million against the invoice of ₦1,977.02 million issued to them by the MO for services rendered in 2024/Q4, translating to 63.36% remittance performance. NESI made a payment of $5.21 million against the cumulative invoice of $14.05 million issued by the MO for services rendered in 2024/Q4, translating to a remittance performance of 37.08%. The domestic bilateral customers made a cumulative payment of ₦1,252.58 million against the invoice of ₦1,977.02 million issued to them by the MO for services rendered in 2024/Q4, translating to 63.36% remittance performance. It is noteworthy that some bilateral customers (both domestic and international customers) made payments during 2024/Q4 for outstanding MO invoices from previous quarters. Paras-CEET, Pars-SBEE and Transcorp-SBEE made payments of $0.98 million, $0.70 million and $1.30 million, respectively, towards outstanding invoices from previous quarters. Similarly, the MO received ₦135.81 million from the domestic bilateral customers \[NDPHC-Weewood; ₦21.17 million, North-\ South/Star Pipe; ₦11.00 million, Taopex; ₦83.00 million and Trans-Amadi\ (OAU/FMPI); ₦20.74 million\] towards outstanding invoices from previous quarters. The details of these payments are contained in Appendix VII. The special customer (Ajaokuta Steel Co. Ltd and the host community) did not make any payment towards the ₦1.27 billion (NBET) and ₦0.11 billion (MO) invoices received in 2024/Q4. This continues a longstanding trend of non-payment by this customer, and the Commission has communicated the need for intervention on this issue to the relevant FGN authorities. Table 10: Invoices and Remittances of Other Customers in 2024/Q4 | | NBET | | | MO | | | | --- | --- | --- | --- | --- | --- | --- | | Invoice(Million) | Remittance(Million) | Performance(%) | Invoice(Million) | Remittance(Million) | Performance(%) | | | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | | | International Bilateral Customers | | | | | | | | PARAS-SBEE($) | - | - | - | 2.65 | - | 0.00 | | PARAS-CEEET($) | | | | 1.64 | - | 0.00 | | TRANSCORP-SBEE(UGHELLI)($) | - | - | - | 3.59 | 1.71 | 47.52 | | TRANSCORP-SBEE(AFAM3)($) | | | | 1.20 | 0.90 | 74.99 | | MAINSTREAM-NIGELEC($) | - | - | - | 2.60 | 2.60 | 100.00 | | ODUKPANI-CEEET($) | - | - | - | 2.37 | - | 0.00 | | Total | - | - | - | 14.05 | 5.21 | 37.08 | | | | | | | | | * * * FOURTH QUARTER 2024 NERC QUARTERLY REPORTS | | NBET | | | MO | | | | --- | --- | --- | --- | --- | --- | --- | | Invoice(Million) | Remittance(Million) | Performance(%) | Invoice(Million) | Remittance(Million) | Performance(%) | | | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | 2024/Q4 | | | Local Bilateral Customers | | | | | | | | MSTM/INNER GALAXY(N) | | | | | | | | MSTM/KAM IND.(N) | | | | | | | | MSTM/KAM INT.(N) | - | - | - | 1,135.14 | 1,135.14 | 100.00 | | MAINSTREAM/PRISM(N) | | | | | | | | MSTM ZEBERCED(N) | | | | | | | | MSTM/ADFV(N) | | | | | | | | NDPHC/WEEWOOD(N) | - | - | - | 92.82 | 0 | 0.00 | | NORTH SOUTH/STAR P(N) | - | - | - | 30.73 | 0 | 0.00 | | TRANS AMADI(OAU)(N) | - | - | - | 28.82 | 17.44 | 60.50 | | TRANS AMADI(FMPI)(N) | | | | | | | | NDPHC/SUNFLAG(N) | - | - | - | 37.25 | 0.00 | 0.00 | | OMOTOSHO II/PULKIT(N) | - | - | - | 385.93 | 100.00 | 25.91 | | ALAOJI GENCO/APLE(N) | - | - | - | 215.39 | 0.00 | 0.00 | | TAOPEX/KAM INT(N) | | | | | | | | TAOPEX/KAM STEEL(N) | - | - | - | 50.95 | 0.00 | 0.00 | | SAPELE/PHOENIX(N) | | | | | | | | Total | - | - | - | 1,977.02 | 1,252.58 | 63.36 | | Special CustomerAJAOKUTA STEEL(N) | 1,276.17 | 0 | 0 | 117.31 | 0 | 0 | 1. NBET, MO, SBEE, CEET and NIGELEC are Nigeria Bulk Electricity Trader, Market Operator, Société Beninoise d’Energie Electrique, Compagnie Energie Electrique du Togo and Société Nigerienne d’electricite * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 3.0 REGULATORY FUNCTIONS Section 34 (2)(d) of the EA 2023 provides that the Commission is empowered to “licence and regulate persons engaged in the generation, transmission, system operation, distribution, supply and trading of electricity” in the NESI. In exercising the powers conferred on it by the EA 2023, the Commission primarily engages with participants in the NESI through selected regulatory instruments as prescribed by the Act. Some of the regulatory instruments utilised by the Commission include – • Regulations: Regulations are detailed legal rules, and bye-laws formulated by the Commission pursuant to sections 46(2), 64, 215 and 226 of the Electricity Act, to govern and conduct operations within the electricity sector, ensure adherence to statutory requirements, and give effect to the implementation of the Act. • Orders: Orders are authoritative commands, legally binding instructions, and directions issued by the Commission pursuant to sections 47, 64 and 215 of the Electricity Act, requiring licensees to perform certain actions, cease, desist from specific activities, or act in a particular way. • Directives: Directives are enforceable instructions issued by the Commission pursuant to sections 64 and 215 of the Electricity Act, to address specific issues, implement policies, or ensure compliance with regulatory objectives. • Licences: Licences are authorisations granted by the Commission pursuant to sections 34(2)(d), 63(1), 64, and 215 of the Electricity Act, that allow entities to operate in activities such as the generation, transmission, trading and distribution of electricity under specified terms and conditions. 3.1 Regulations, Orders and Directives The Commission did not issue any new Regulation for the NESI in 2024/Q4. • Permits: Permits are authorisations issued by the Commission pursuant to sections 63(2), 64 and 215 of the Electricity Act, for specific activities, such as the generation of electricity for own use or authorisation to participate as a meter service provider. 3.1.1 Regulations * * * 3.1.2 Orders During the quarter, the Commission issued thirty-nine (39) Orders to guide the activities of licensees. The details of the Orders are outlined below: A. Order No: NERC/2024/112 — Transfer of Regulatory Oversight of the Electricity Market in Lagos State from the Nigerian Electricity Regulatory Commission to the Lagos State Electricity Regulatory Commission (LASERC). The Order became effective on 05 December 2024 and has the following objectives; i. Commence the process of the transfer of regulatory oversight for the intrastate electricity market in Lagos State from the Commission to LASERC in accordance with the CFRN and EA. ii. Provide a transition plan for the transfer of regulatory oversight for the intrastate electricity market in Lagos State from the Commission to LASERC in accordance with the CFRN and the EA. iii. Address ensuing transitional matters arising from the transfer of regulatory oversight for the intrastate electricity market in Lagos State from the Commission to LASERC. The Order mandates Eko Electricity Distribution Plc (EKEDP) to incorporate within 60 days, a subsidiary under the CAMA for the assumption of its responsibilities for intrastate supply and distribution of electricity in Lagos State from EKEDP. B. Order No: NERC/2024/113 — Transfer of Regulatory Oversight of the Electricity Market in Lagos State from the Nigerian Electricity Regulatory Commission to the Lagos State Electricity Regulatory Commission (LASERC). The Order became effective on 05 December 2024 and has the following objectives; i. Commence the process of the transfer of regulatory oversight for the intrastate electricity market in Lagos State from the Commission to LASERC in accordance with the CFRN and EA. iii. Address ensuing transitional matters arising from the transfer of regulatory oversight for the intrastate electricity market in Lagos State from the Commission to LASERC. * * * The Order mandates Ikeja Electric Plc (IE) to incorporate, within 60 days, a subsidiary under the CAMA for the assumption of its responsibilities for intrastate supply and distribution of electricity in Lagos State from IE. C. Order Nos: NERC/2024/126—NERC/2024/136 (11 Orders issued to 11 DisCos) — October 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which provide for monthly tariff reviews, the October 2024 supplementary Orders (effective date - 01 October 2024) sought to reflect the changes in the passthrough indices outside the control of licensees including inflation rates, ₦/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff. Pursuant to the policy directive of the FGN on electricity subsidy which mandates a freeze on tariffs across all bands (A-E) at rates payable in July 2024, all enduse customer tariffs remain unchanged. D. Order Nos: NERC/2024/137—NERC/2024/147 (11 Orders issued to 11 DisCos) — November 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which provide for monthly tariff reviews, the November 2024 supplementary Orders (effective date - 01 November 2024) sought to reflect the changes in the pass-through indices outside the control of licensees including inflation rates, ₦/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff. Pursuant to the policy directive of the FGN on electricity subsidy which mandates a freeze on tariffs across all bands (A-E) at rates payable in July 2024, all enduse customer tariffs remain unchanged. E. Order Nos: NERC/2024/149-NERC/2024/159 (11 Orders issued to 11 DisCos) — December 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which provide for monthly tariff reviews, the December 2024 supplementary Orders (effective date - 01 December 2024) sought to reflect the changes in the pass-through indices outside the control of licensees including inflation rates, ₦/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff. * * * ### FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # Pursuant to the policy directive of the FGN on electricity subsidy which mandates **a freeze on tariffs across all bands (A-E) at rates payable in July 2024, all end-** # use customer tariffs remain unchanged. ## F. Order No: NERC/2024/162 — Addendum 1 to the Order on Performance **Monitoring Framework for the Distribution Companies July 2024. The Order became effective on 23 December 2024. This order seeks to:** **i. Improve regulatory efficiency by aligning the frequency of KPI evolutions with data availability, ensuring timely and effective interventions.** **ii. Enhance compliance and enforcement measures by refining the regulatory framework to support DisCos in achieving targets.** ## The Commission noted that the evaluation of compliance with two (2) Key ## Performance Indicators (Energy offtake relative to PCC and Compliance with ## Reporting of Uniform System of Accounts) relies on data which are available ## only at the end of the market cycle which may delay the implementation of **consequential regulatory interventions provided in the original Order issued to the DisCos (Order Nos: NERC/2024/086 - NERC/2024/096). Thus, this Order** **seeks to adjust the evaluation frequency and the associated consequential regulatory interventions for non-compliance with the aforementioned KPIs.** ## G. Order No: NERC/2024/163 — Transfer of Regulatory Oversight of the Electricity ## Market in Ogun State from the Nigerian Electricity Regulatory Commission to the **Ogun State Electricity Regulatory Commission (OGERC). The Order became effective on 24 December 2024 and has the following objectives;** ## i. Commence the process of the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and EA.** ## ii. Provide a transition plan for the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and the EA.** ## iii. Address ensuing transitional matters arising from the transfer of regulatory ## oversight for the intrastate electricity market in Ogun State from the Commission to OGERC. ## The Order mandates Eko Electricity Distribution Plc (EKEDP) to incorporate within ## 60 days, a subsidiary under the CAMA for the assumption of its responsibilities ## for intrastate supply and distribution of electricity in Ogun State from EKEDP. ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS # H. Order No: NERC/2024/164 — Transfer of Regulatory Oversight of the Electricity # Market in Ogun State from the Nigerian Electricity Regulatory Commission to **the Ogun State Electricity Regulatory Commission (OGERC). The Order became effective on 24 December 2024 and has the following objectives;** # i. Commence the process of the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and EA.** # ii. Provide a transition plan for the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and the EA.** # iii. Address ensuing transitional matters arising from the transfer of regulatory # oversight for the intrastate electricity market in Ogun State from the Commission to OGERC. # The Order mandates Ikeja Electric Plc (IE) to incorporate within 60 days, a # subsidiary under the CAMA for the assumption of its responsibilities for intrastate # supply and distribution of electricity in Ogun State from IE. # I. Order No: NERC/ 2024/165 - Transfer of Regulatory Oversight of the Electricity # Market in Ogun State from the Nigerian Electricity Regulatory Commission to the **Ogun State Electricity Regulatory Commission (OGERC). The Order became effective on 24 December 2024 and has the following objectives;** # i. Commence the process of the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and EA.** # ii. Provide a transition plan for the transfer of regulatory oversight for the **intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and the EA.** # iii. Address ensuing transitional matters arising from the transfer of regulatory # oversight for the intrastate electricity market in Ogun State from the Commission to OGERC. # The Order mandates Ibadan Electricity Distribution Company Plc (IBEDC) to # incorporate within 60 days, a subsidiary under the CAMA for the assumption of # its responsibilities for intrastate supply and distribution of electricity in Ogun State from IBEDC. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 3.1.3 Directives The Commission did not issue any directives to licensees in 2024/Q4. 3.2 Licences Issued or Renewed In 2024/Q4, the Commission issued one (1) off-grid generation licence \[gross\ capacity of 2.63MW\] and three (3) new trading licences in the NESI (Table 11). Table 11: Licences issued by the Commission in 2024/Q4 | SN | Licensee | Location | Capacity(MW) | License Type | Fuel Type | | --- | --- | --- | --- | --- | --- | | 1 | Capstone Energies Limited | Abuja | N/A | Trading | N/A | | 2 | Ecovolt Trade Limited | Lagos State | N/A | Trading | N/A | | 3 | Tendon Innovation Limited | Lagos State | N/A | Trading | N/A | | 4 | Daybreak Power Solutions Limited | Lagos State | 2.63 | Off-grid | Solar | Captive power generation permits are issued to entities that intend to own and maintain power plants exclusively for their own consumption i.e. no sale of electricity generated from the plant to any third party. The Commission approved the grant of captive power generation permits to four (4) applicants \[gross capacity of\ 22.50MW\] as detailed in Table 12. Table 12: Captive Generation Plants approved in 2024/Q4 Pursuant to section 165(1)(m) of the EA 2023 which states that the Commission shall “award licence of mini-grid concessions to renewable energy companies to exclusively serve a specific geographical location indicating aggregate electricity to be generated and distributed from a site with obligation to serve customers to request service”, the Commission continues to encourage the development and | S/N | Company Name | Location/State | Capacity(MW) | | --- | --- | --- | --- | | 1 | Ro-Marong Nigeria Limited(Renewal) | Amuwo-Odofin,Lagos | 4.40 | | 2 | Quantum Paper Limited | Agbara,Ogun State | 7.00 | | 3 | Psaltry International Company Limited | Alayide village,Oyo State | 1.10 | | 4 | Nile University of Nigeria | Airport Road,Jabbi Abuja | 10.00 | * * * utilisation of renewable energy by issuing permits and registration certificates for mini-grid development. A permit is issued to a mini-grid developer for the construction, operation, and maintenance of mini-grids with a distribution capacity above 100kW and generation capacity up to 1MW. The Commission also issues registration certificates to developers for one or more systems with a distribution capacity below 100kW. In 2024/Q4, the Commission issued twenty-four (24) permits \[gross capacity of\ 5.5MW\] and five (5) registration certificates \[gross capacity of 0.45MW\]. Table 13: Mini-grid Permits and Registration Certificates issued in 2024/Q4 | S/N | Name | Capacity(kW) | Location | | --- | --- | --- | --- | | | Permits | | | | 1 | Prado Limited | 150.00 | Achor maav-asar,Kwande L.G.A,Benue | | 2 | Prado Limited | 150.00 | Adabu,Obi LGA,Nasarawa | | 3 | Prado Limited | 100.00 | Adamgbe,VandeikjeLGA,Benue | | 4 | Prado Limited | 100.00 | Tashibo,LapaiLGA,Niger | | 5 | Prado Limited | 100.00 | Lobi,UshongoLGA,Benue | | 6 | Prado Limited | 150.00 | Majaki,LapaLGA,Niger | | 7 | Prado Limited | 600.00 | Oboro,OjuLGA,Benue | | 8 | Prado Limited | 100.00 | RuganMugu,LapaiLGA,Niger | | 9 | Prado Limited | 100.00 | TsuaMbagbera,VandekyaLGA,Benue | | 10 | Prado Limited | 550.00 | Tjoadoo,GbokoLGA,Benue | | 11 | Prado Limited | 250.00 | Utonkon,AdorLGA,Benue | | 12 | Prado Limited | 150.00 | Wuesa,KonshishaLGA,Benue | | 13 | Prado Limited | 150.00 | Ajio,KwendeLGA,Benue | | 14 | Prado Limited | 300.00 | Amahunda,KwandeLGA,Benue | | 15 | Prado Limited | 300.00 | Assakio,LafiaLGA,Nasarawa | | 16 | Prado Limited | 100.00 | AtsekeOrferegh,TarkaLGA,Benue | | 17 | Prado Limited | 400.00 | AzaraMaisamri,AwrLGA,Nasarawa | | 18 | Prado Limited | 250.00 | BetseVandeikjaLGA,Benue | | 19 | Prado Limited | 100.00 | AnhulMbaaakunne,GbokoLGA,Benue | | 20 | Prado Limited | 200.00 | NambeMbaikjan,KwandeLGA,Benue | | 21 | Prado Limited | 300.00 | PikaMbsur,GbokoLGA,Benue | | 22 | Prado Limited | 200.00 | AlaElefoson, AkureNorthLGA, Ondo | | 23 | Prado Limited | 400.00 | NataAla,TundunWadaLGA, Kano | | 24 | Prado Limited | 300.00 | Jita(farinrua)tudunwadaLGA,Kano | | | Registration | | | | 1 | Crossboundary Energy | 100.00 | Ataswa,lokoja,Kogi | | 2 | Crossboundary Energy | 100.00 | OgedeAjiekpe,Ankpa,Kogi | * * * NERC QUARTERLY REPORTS | S/N | Name | Capacity(kW) | Location | | --- | --- | --- | --- | | 3 | Crossboundary Energy | 100.00 | Atuma, ankpa, Kogi | | 4 | Crossboundary Energy | 100.00 | Ajitata Ojokweje, kogi | | 5 | Crossboundary Energy | 50.00 | Ogegume, Ofu, Kogi | 3.5 Meter Service Providers/Meter Asset Providers A Meter Service Provider (MSP) is an entity certified by the Commission as a manufacturer, supplier, vendor, or installer of electric energy meters and/or metering systems. A Meter Asset Provider (MAP) is an entity that is granted a permit by the Commission to provide metering services with roles that may include meter financing, procurement, supply, installation, maintenance, and replacement. A Meter Service Provider (MSP) is an entity certified by the Commission as a manufacturer, supplier, vendor, or installer of electric energy meters and/or metering systems. A Meter Asset Provider (MAP) is an entity that is granted a permit by the Commission to provide metering services with roles that may include meter financing, procurement, supply, installation, maintenance, and replacement. The Commission certified eighteen (18) MSPs – six (6) meter installer companies, six (6) manufacturers, three (3) vendors and three (3) importers in 2024/Q4. The Commission also issued fifteen (15) permits for MAP. Details of the certified MSPs and MAP are contained in Table 14. Table 14: Meter Service Providers certified in 2024/Q4 | S/N | Name | Authorisation Type | | --- | --- | --- | | | Meter Service Providers | | | 1 | Caplan Integrated Services Limited | Installer A1 | | 2 | Cartlark International Limited | Installer A1 | | 3 | Gosslink Engineering Limited | Installer A1 | | 4 | MBH Power Limited | Installer A1 | | 5 | Arrowhead Electric Solutions Ltd | Installer A1 | | 6 | Chapet Energy Ltd | Installer C1 | | 7 | Unistar H-Tech system Ltd | Manufacturer | | 8 | CWG Plc | Manufacturer | | 9 | Skyrun Electric Power Tech | Manufacturer | | 10 | Holley Metering Limited | Manufacturer | | 11 | Smart Meters Co. Ltd | Manufacturer | | 12 | Mojec International Ltd | Manufacturer | | 13 | Integrated Power Nig Ltd | Vendor | | 14 | Utility Performance Ltd | Vendor | | 15 | Gosslink Engineering Ltd | Vendor | | 16 | Gosslink Engineering Ltd | Importer | \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * FOURTH QUARTER 2024 NERC QUARTERLY REPORTS | S/N | Name | Authorisation Type | | --- | --- | --- | | 17 | Phoenix Renewable Limited | Importer | | 18 | Kenpetrus Energy Resources Limited | Importer | | | Meter Asset Providers | | | 1 | Eve Electric Technology Co.Ltd | MAP | | 2 | Zenithpoint Limited | MAP | | 3 | Tesla Automation Limited | MAP | | 4 | Tetra-electric Solutions Limited. | MAP | | 5 | Bee-springs Services Limited. | MAP | | 6 | Brooksfield Technologies Limited | MAP | | 7 | RLG-Adulawa Limited | MAP | | 8 | Incomtel Engineering Limited | MAP | | 9 | Lowpai Energy & Marine Limited | MAP | | 10 | Power Cap Limited | MAP | | 11 | Regno Development Limited | MAP | | 12 | Hampcc Uti Limited | MAP | | 13 | Nicholas Ojo Alokomaro and Sons Limited | MAP | | 14 | M E Metering Company Limited | MAP | | 15 | Direct Credit E-Solutions Nigeria Limited | MAP | Class “A1” Certification authorises a holder to undertake installations of (i) Low Voltage single-phase and three-phase Metering systems for installation exceeding 750 metering Systems/Contract, and (ii) Installations at grid voltages exceeding 5 Metering Systems. Class “C1” Certification authorises a holder to undertake installations of Low Voltage Distribution singlephase and three-phase Metering Systems exceeding 500 Metering Systems/Contract. 3.6 Hearings and Public Consultations As part of the conditions of their licences, section 72(2)(c) of the EA requires licensees to ‘’refer disputes to the Commission for arbitration, mediation, or determination by the Commission and file appeal against the decisions of the Commission’’. One of the ways by which the Commission performs this quasi-judicial function towards the resolution of disputes between stakeholders is through 12 hearings. Furthermore, the Business Rules of the Commission- NERC-R-0306 allows the Commission to undertake public consultations through which the Commission aggregates input/opinions on licensee applications and regulatory instruments which are being drafted or reviewed. 12 Hearings are proceedings pursuant to the provisions of the Electricity Act through which the Commission seeks additional information on petitions or any matter filed before it by market participants or consumers in order to make a final decision. 38 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * were recorded during the quarter. The hearing was conducted on 24 October 2024 at the Commission’s headquarters in Abuja. 3.7 Compliance and Enforcement Section 64(1) of the EA 2023 mandates all licensees to comply with the provisions of their licences, regulations, codes, orders and other requirements issued by the Commission. The Commission is responsible for evaluating the compliance of all its licensees/permit-holders and carrying out enforcement actions against infractions based on the provisions of the Act and other extant regulatory instruments. Pursuant to the provisions of Section 76 of the EA 2023, the Commission issued fourteen (14) Rectification Directives (RD) and sixteen (16) Notices of Intention to Commence Enforcement (NICE) for different breaches/defaults in 2024/Q4 (full list and further details can be found in Table 15). 3.8 Alternative Dispute Resolution Pursuant to the provisions of section 42.3.7 of the Market Rule, the Commission has established an Alternative Dispute Resolution (ADR) process to resolve disputes between market participants in the NESI. This includes the constitution of a Dispute Resolution Panel (DRP) and the appointment of a Dispute Resolution Counsellor (DRC). No disputes were brought before the DRP during this quarter. | SN | RD/NICE/Fine | Licensee | Date of Issuance | Deadline | | --- | --- | --- | --- | --- | | Rectification Directive | | | | | | 1 | Non-compliance with Eko forum ruling | Eko DisCo | 20 December 2024 | 27 December 2024 | | 2 | Non-Compliance with Meter Asset Provider & National Mass Metering Regulations | Eko DisCo | 20 December 2024 | 03 January 2025 | | 3 | Non-compliance with the Commission's order on capping estimated bills | Enugu DisCo | 20 November 2024 | 30 November 2024 | | 4 | Non-compliance with the Commission's order on capping of estimated bills | P/Harcourt DisCo | 20 November 2024 | 30 November 2024 | | 5 | Non-compliance with the Commission's customer complaints resolution procedures | Eko DisCo | 26 November 2024 | 06 December 2024 | | 6 | Non-compliance with the Commission's customer complaints resolution procedures | Eko DisCo | 26 November 2024 | 06 December 2024 | * * * FOURTH QUARTER 2024 NERC QUARTERLY REPORTS | SN | RD/NICE/Fine | Licensee | Date of Issuance | Deadline | | --- | --- | --- | --- | --- | | Rectification Directive | | | | | | 7 | Non-compliance with the Commission's resolution on appeal in Dada Makanjola vs IBEDC | Ibadan DisCo | 26 November 2024 | 10 December 2024 | | 8 | Non-compliance with the decision in the complaint regarding vandalism and theft of infrastructure in KYC Estate, Sabon-lugbe | Abuja DisCo | 19 November 2024 | 26 November 2024 | | 9 | Non-compliance with the Abuja Forum Decision in complaint AFO/2019/09/B460 | Abuja DisCo | 12 November 2024 | 19 November 2024 | | 10 | Non-compliance with the Abuja Forum Decision in complaint AFO/2024/08/C233 | Abuja DisCo | 04 November 2024 | 11 November 2024 | | 11 | Non-compliance with the Sokoto Forum Decision in complaint NERC/SFO/01/24/223 | Kaduna DisCo | 1 November 2024 | 15 November 2024 | | 12 | Non-compliance with the Abuja Forum Decision in complaint AFO/2024/09/C244 | Abuja DisCo | 11 October 2014 | 25 October 2024 | | 13 | Non-compliance with the Ikeja Forum Decision in complaint IFO/2024/06/10630 | Ikeja DisCo | 16 October 2024 | 30 October 2024 | | 14 | Non-compliance with the Commission's directive to file audited financial statements. | Green Energy International Limited (GEIL) | 10 October 2024 | 23 October 2024 | | | Notice of Intention to Commence Enforcement(NICE) | | | | | 1 | Unauthorised supply of power to KARIG Farms through a TEE-OFF Connection | Obafemi Awolowo University(OAU) | 10 December 2024 | 24 December 2024 | | 2 | Failure to respond to the Commission's requests for an update on the resolution of the complaint from Residents Association Brains and Hammers,Apo 3 | Abuja DisCo | 26 November 2024 | 10 December 2024 | | 3 | Non-Compliance with the Kano Forum ruling in complaint KNF/NERC/24/04/0048 | Kano DisCo | 21 November 2024 | 5 December,2024 | | 4 | Non-compliance with the Account Administration Agreement | Kaduna DisCo | 8 November 2024 | 22 November 2024 | | 5 | Non-compliance with the Commission's directives on Principal Collection Accounts | Kaduna DisCo | 8 November 2024 | 22 November 2024 | | 6 | Non-compliance with the Commission's directives on Principal Collection Accounts | Kano DisCo | 8 November 2024 | 22 November 2024 | | 7 | Non-compliance with the Commission's directives on Principal Collection Accounts | P/Harcourt DisCo | 8 November 2024 | 22 November 2024 | | 8 | Non-compliance with the Abuja Forum Decision in complaint AFO/2021/11/B856 | Abuja DisCo | 1 November 2024 | 15 November 2014 | * * * FOURTH QUARTER 2024 NERC QUARTERLY REPORTS | SN | RD/NICE/Fine | Licensee | Date of Issuance | Deadline | | --- | --- | --- | --- | --- | | Rectification Directive | | | | | | 9 | Non-compliance with NESIS Regulations leading to the fatal electrocution of Master Abdulakeem Abdullahi | Ibadan DisCo | 04 October 2024 | 28 October 2024 | | 10 | Non-compliance with NESIS Regulations leading to the fatal electrocution of Master Abdulakeem Abdullahi | Ibadan DisCo | 14 October 2024 | 28 October 2024 | | 11 | Non-compliance with the Commission's directive to file audited financial statements | Green Energy International Limited(GIGL) | 28 October 2024 | 11 November 2024 | | 12 | Non-compliance with NESIS Regulations leading to the fatal electrocution of Mrs. Amuda | Ibadan DisCo | 24 October 2024 | 07 November 2024 | | 13 | Non-compliance with NESIS Regulations and the Health and Safety Code leading to the fatal electrocution of four members of a family. | Yola DisCo | 23 October 2024 | 06 November 2024 | | 14 | Non-compliance with the Commission's directives in the appeal of Mr.Kashopefoluwa vs AEDC | Abuja DisCo | 22 October 2024 | 05 November 2024 | | 15 | Non-compliance with NESIS Regulations leading to damage of various 33Kv feeders and transmission equipment | Abuja DisCo | 14 October 2024 | 28 October 2024 | | 16 | Non-Compliance with the Grid Code.i.e.late submission of incident report on shattered 33Kv blue phase voltage transformer at Katampe | TCN | 14 October 2024 | 28 October 2024 | * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 4.0 CONSUMER AFFAIRS 4.1 Consumer Enlightenment and Stakeholder Engagements The Commission’s main consumer education and enlightenment mechanisms are town hall meetings and customer complaints resolution meetings. These are used to enlighten consumers/stakeholders on the Commission’s activities, regulatory instruments, consumer rights and obligations, and to ensure swift resolution of complaints. These also provide avenues for the Commission to gather feedback from consumers which is beneficial to the Commission in its decision-making processes. As part of its routine activities, the Commission also engages relevant stakeholders and the wider public to apprise them of the Commission’s activities. The main avenues for the interface between the Commission and stakeholders are: • NESI stakeholder meetings • Trainings/Workshops • General stakeholder engagement activities The details of these engagements are shared with the public via the Commission’s social media accounts (LinkedIn, X and Instagram). In addition to the update on the engagement activities, the Commission also uses these channels to address relevant issues including: • Consumer rights and obligations • Service delivery standards • NESI performance factsheets • NESI performance factsheets • Serviced Based Tariff (SBT) provisions • Capping of estimated bills for unmetered customers Electricity customer rights and obligations • Regulatory instruments issued by the Commission In 2024/Q4, the Commission held one (1) town hall meeting in Kaduna (12-14 December 2024). Some of the major issues that were discussed at the town hall meeting include: • Metering frameworks and * * * • Strategies by the Commission to ensure improved overall service delivery to customers. The Commission also continued to sponsor radio jingles across radio stations throughout the country. These jingles educate customers on complaint redress mechanisms and provide addresses of NERC Forum Offices. 4.2 Metering End-Use Customers As of 31st December 2024, 6,288,624 (46.57%) out of the 13,503,342 registered electricity customers across the twelve (12) DisCos were metered (breakdown contained in Table 16). st Table 16: Metering Progress as of 31 December 2024 31^{t} | DisCos | Total No.of Registered Customers | No. of Metered Customers | Metering Rate(%) | | --- | --- | --- | --- | | Aba | 206,540 | 78,281 | 37.90 | | Abuja | 1,195,429 | 910,942 | 76.20 | | Benin | 1,435,685 | 714,242 | 49.75 | | Eko | 729,169 | 460,187 | 63.11 | | Enugu | 1,396,440 | 671,760 | 48.11 | | Ibadan | 2,644,124 | 1,153,025 | 43.61 | | Ikeja | 1,286,026 | 998,986 | 77.68 | | Jos | 832,053 | 225,188 | 27.06 | | Kaduna | 884,647 | 217,033 | 24.53 | | Kano | 891,410 | 215,834 | 24.21 | | Port Harcourt | 1,179,194 | 524,256 | 44.46 | | Yola | 822,625 | 118,908 | 14.45 | | Total | 13,503,342 | 6,288,624 | 46.57 | | \\* Metering rate: Red<50 Amber 50≤70 Green>70 | | | | \*Metering rate: Red <50, Amber 50≤70, Green ≥70 During 2024/Q4, 185,439 end-user customers were metered across all the DisCos with Ikeja, Ibadan and Benin DisCos recording the highest number of meter installations – they accounted for 28.81%, 20.00%, and 12.62% respectively, of the total installations. Relative to 2024/Q3, when 185,087 customers were metered, there was a slight increase (+0.19%) in the total number of customers metered in 2024/Q4. * * * with Aba (-55.38%), Abuja (-22.99%) and Eko (-18.32%) DisCos recording significant declines (Table 17). Table 17: Meter Deployment by DisCos in 2024/Q4 vs. 2024/Q3 | DisCos | Total No.of metered customers as of2024/Q4 | No.of customers metered in2024/Q4 | No.of customers metered in2024/Q3 | Change in meter deployments across quarters(%) | | --- | --- | --- | --- | --- | | Aba | 78,281 | 2,199 | 4,928 | -55.38 | | Abuja | 910,942 | 20,755 | 26,951 | -22.99 | | Benin | 714,242 | 23,965 | 17,175 | 39.53 | | Eko | 460,187 | 14,688 | 17,982 | -18.32 | | Enugu | 671,760 | 16,489 | 19,075 | -13.56 | | Ibadan | 1,153,025 | 37,089 | 39,624 | -6.40 | | Ikeja | 998,986 | 53,431 | 46,959 | 13.78 | | Jos | 225,188 | 3,525 | 2,824 | 24.82 | | Kaduna | 217,033 | 2,439 | 1,845 | 32.20 | | Kano | 215,834 | 1,226 | 1,347 | -8.98 | | Port Harcourt | 524,256 | 7,878 | 6,377 | 23.54 | | Yola | 118,908 | 1,755 | - | - | | Total | 6,288,624 | 185,439 | 185,087^{13}$ | 0.19 | Out of the 185,439 end-use customers metered in 2024/Q4, 179,064 (96.56%) of customers were metered under the MAP framework, 4,076 (2.20%) were metered under the Meter Acquisition Fund (MAF) framework, 1,924 (1.04%) were metered under the Vendor Financed framework, and 374 (0.21%) were metered under the Out of the 185,439 end-use customers metered in 2024/Q4, 179,064 (96.56%) of customers were metered under the MAP framework, 4,076 (2.20%) were metered under the Meter Acquisition Fund (MAF) framework, 1,924 (1.04%) were metered under the Vendor Financed framework, and 374 (0.21%) were metered under the under the Vendor Financed framework, and 374 (0.21%) were metered under the DisCo Financed framework. The Meter Acquisition Fund that was created by the Commission in June 2024 provides for a metering surcharge in the allowed tariffs for all DisCos. It is geared towards providing regulatory-backed long-tenor financing for the procurement of meters towards closing the metering gap in the NESI. A proportionate amount is deducted from the monthly collections of DisCos towards the MAF; this is then made 13 Upon data reconciliation, the number of meters installed across all metering schemes in 2024/Q3 was 185,087 as against 184,507 reported in the 2024/Q3 report. 45 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * available for DisCos to purchase meters either through a bulk one-off procurement or repayment of mid/long-term vendor-financed meter deployments. The Commission vide the Order: NERC/2024/072 on the Operationalisation of Tranche A of the MAF approved the use of ₦21.00 billion out of the funds that have accrued in the MAF as of the April 2024 settlement cycle, for DisCos to provide meters for Band A customers in their franchise area at no cost. The approved fund was distributed pro-rata among the DisCos based on their contribution to the MAF scheme at the cut-off date. During the quarter (2024/Q4), 4,076 meters were installed under the MAF framework. Yola (1,755), Jos (1,674), Benin (568) and Kano (79) are the only DisCos that have commenced meter installations under the MAF. Further details on the metering progress under the MAP, MAF as well as Vendor and DisCo financed frameworks are presented in appendices IX, X and XI respectively. 4.3 Customer Complaints * * * C. NERC Forum Offices: Forum offices serve as the “court of second instance” for customers not happy with the resolution of their complaints at the DisCo-CCU. The Commission set up Forum Offices to hear and resolve customer complaints not satisfactorily resolved at the DisCo-CCUs. The Forum Office is managed by the forum secretariat while the hearings are conducted by five (5) forum panel members who are not staff of the Commission, as stipulated in the Customer Protection Regulation (CPR) 2023. The forum panels hear and resolve customer complaints in the state in which it is situated, if there is no Forum Office in a state, the Commission determines which neighbouring Forum Office will oversee customer complaints from the state. The composition of the forum panel is as follows: 1. A legal practitioner with experience in alternative dispute resolution nominated by the Nigerian Bar Association (NBA). 2. A financial expert nominated by either the Manufacturers Association of Nigeria, Nigerian Association of Chambers of Commerce, Industry, Mines and Agriculture (NACCIMA) or any other reputable organisation. 3. A qualified electrical engineer nominated by either the Council for Regulation of Engineering in Nigeria (COREN) or the Nigerian Society of Engineers (NSE). 4. A nominee of the Federal Competition and Consumer Protection Commission (FCCPC). As of 30 September 2024, the Commission had thirty-three (33) operational Forum Offices in thirty-one (31) states and the FCT, Abuja. However, during the quarter 14 (2024/Q4), the Commission closed down the Forum Offices in six (6) States following the transfer of regulatory oversight to these States; this means by the end of 2024/Q4, the Commission only has twenty-seven (27) active forum offices across twenty-six (26) states and the FCT. The details, including names, addresses, and contacts of the remaining operational Commission’s Forum Offices are contained in Appendix XV. As part of the transition of the regulatory functions to the states, the Commission organised accelerated hearings across the affected forum offices to ensure that all pending cases were adjudicated before the closure of the forum offices. 14 Enugu, Imo, Ekiti, Oyo, Kogi and Edo States. 47 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * D. Power Outage Reporting System (PORS): This is a mobile application designed for electricity customers to report outages in real time. The pilot phase for the operationalisation of the PORS has already started with AEDC and there are clear timelines for the extension of the system to other DisCos once the pilot phase is completed. 4.3.1 NERC-CCU In 2024/Q4, 4,180 complaints were received at the Commission’s CCU and 1,231 were resolved, corresponding to a 29.45% resolution rate. This resolution rate represents a -1.70pp decrease compared to the 31.15% resolution rate recorded in 2024/Q3. Customers of Ikeja and Eko DisCos lodged 1,731 and 836 complaints accounting for 41.41% and 20.00%, respectively of the total complaints lodged at NERC-CCU. Conversely, Aba Power had the lowest number of complaints with 8 (0.19%). The Commission notes the poor resolution rate (29.45%) of complaints lodged at the NERC-CCU in 2024/Q4 and is taking steps to improve the speediness of complaint resolution by DisCos. During the quarter, customer complaints about metering constituted 36.82% of the total complaints. Other common issues among the 4,180 complaints received were 15 billing (31.24%), service interruption (15.50%) and tariff bands (6.29%). These four (4) complaint categories cumulatively accounted for 89.86% of the total complaints in the quarter (Figure 10). The complaints on billing that were resolved 15 Complaints on tariff bands are from customers who are dissatisfied with their current energy supply band 48 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * during the quarter resulted in a credit adjustment on customers' bills to the tune of ₦40,193,039 (Appendix XIII). 4.3.2 DisCo-CCUs The number of complaints received by DisCos in 2024/Q3 and 2024/Q4 are contained in Table 18. The total number of complaints received in 2024/Q4 was 275,681 across all DisCos; this translates to a –16.13% decrease compared to the 328,696 received in 2024/Q3. Port Harcourt DisCo received the highest number of complaints (54,683), representing 19.84% of total complaints received. Yola DisCo received the least number of complaints (1,917), representing 0.69% of total complaints received. Nine (9) DisCos recorded declines in the number of customer complaints received in 2024/Q4 compared to 2024/Q3. Kaduna (-43.71%), Kano (-37.01%), Eko (- 26.28%), Yola (-25.78%), Enugu (-24.81%), and Abuja (-23.70%) recorded the most reductions. Benin (+18.16%), Aba (+11.76%) and Ikeja (+1.15%) DisCos recorded an increase in the number of customer complaints received between 2024/Q3 and 2024/Q4. Table 18: Complaints Received by DisCos in 2024/Q3 vs. 2024/Q4 | DisCos | No. of complaints received in2024/Q3 | No. of complaints received in2024/Q4 | Change in No.of complaints received | Change in No.of complaints received(%) | | --- | --- | --- | --- | --- | | Aba | 4,933 | 5,513 | 580 | 11.76 | | Abuja | 31,407 | 23,963 | -7,444 | -23.70 | | Benin | 11,809 | 13,953 | 2,144 | 18.16 | | Eko | 64,987 | 47,911 | -17,076 | -26.28 | | Enugu | 20,769 | 15,617 | -5,152 | -24.81 | | Ibadan | 56,597 | 47,510 | -9,087 | -16.06 | | Ikeja | 22,971 | 23,236 | 265 | 1.15 | | Jos | 20,782 | 19,882 | -900 | -4.33 | | Kaduna | 7,405 | 4,168 | -3,237 | -43.71 | | Kano | 27,511 | 17,328 | -10,183 | -37.01 | | PH | 56,942 | 54,683 | -2,259 | -3.97 | | Yola | 2,583 | 1,917 | -666 | -25.78 | | Total | 328,696 | 275,681 | -53,015 | -16.13 | The most common issues among the 275,681 complaints received by DisCos in 2024/Q4 were metering (51.29%), billing (10.70%) and service interruption (8.49%). These three (3) categories cumulatively accounted for 70.48% of the total complaints in the quarter (Figure 11). * * * Figure 11: Category of complaints received by DisCos in 2024/Q4 4.3.3 Forum Offices The summary of the appeals received across the Forum Offices is presented in Table 19\. Through 2024/Q4, a total of 2,209 out of the 3,267 active appeals (1,233 pending appeals from 2024/Q3 and 2,034 new appeals in 2024/Q4) across the 33 Forum Offices were resolved. This represents a +2.03% increase compared to the 3,202 active appeals in the previous quarter (2024/Q3). Compared to 2024/Q3, the pending appeals carried over in the quarter (2024/Q4) increased by 198 (+19.13%), while new appeals decreased by 133 (-6.14%). The Forum Offices serving Ibadan DisCo have the highest number of active appeals (1,313), representing 40.19% of the total, while the Forum Office serving Aba has the fewest (15) in 2024/Q4. * * * Table 19: Appeals handled by Forum Offices in 2024/Q4 | DisCos | Forum Offices | Appeals Received¹ | Appeals Resolved² | Appeals Pending³ | No. of Sittings | | --- | --- | --- | --- | --- | --- | | Abuja | Abuja, Lafia & Lokoja | 96 | 68 | 28 | 5 | | Aba | Umuahia | 15 | 7 | 8 | 2 | | Benin | Asaba & Benin | 139 | 85 | 54 | 7 | | Eko | Eko | 303 | 205 | 98 | 6 | | Enugu | Abakaliki, Akwa, Enugu, Owerri, & Umuahia | 303 | 203 | 98 | 14 | | Ibadan | Ibadan, Abeokuta, Ilorin & Osogbo | 1,313 | 735 | 480 | 22 | | Ikeja | Ikeja | 587 | 544 | 43 | 8 | | Jos | Bauchi, Gombe, Jos & Makurdi | 80 | 52 | 22 | 2 | | Kaduna | Gusau, Kaduna, Kebbi & Sokoto | 54 | 26 | 22 | 4 | | Kano | Jigawa, Kano & Katsina | 34 | 23 | 11 | 1 | | P/Harcourt | Calabar, Port Harcourt & Uyo | 308 | 236 | 68 | 11 | | Yola | Yola, Damaturu | 35 | 25 | 8 | 2 | | All DisCos | All Forum Offices | 3,267 | 2,209 | 940 | 84 | 1 2. Appeals received include outstanding appeals from the preceding quarter. Appeals resolved excludes 106 appeals rejected 3\. and 12 appeals withdrawn. Appeals are still within the regulatory timeframe of 2 months to resolve. Figure 12: Category of Complaints Received by Forum Offices in 2024/Q4 The breakdown of the various categories of active appeals at the Forum Offices in 2024/Q4 is contained in Figure 12. Similar to 2024/Q3, appeals related to billing were the most prevalent, accounting for 47.32% of the total appeals received (2024/Q3 – 50.21%). Appeals related to metering and disconnection represented * * * 34.43% and 4.77% of the appeals, respectively. The Commission is working on interventions to improve the quality of customer complaint resolution at the DisCo- CCU thereby reducing the number of appeals filed at the Forum Offices. 4.4 Health and Safety Pursuant to Section 34(1)(e) of the EA 2023 which mandates the Commission to “ensure the provision of safe and reliable electricity to consumers”, the Commission monitors the health and safety performance of the NESI. Licensees are mandated to submit monthly Health and Safety reports to the Commission in accordance with the requirements of their licence. In 2024/Q4, out of the 99 mandatory health and safety reports expected to be received from licensees, only 95 received. Pursuant to Section 34(1)(e) of the EA 2023 which mandates the Commission to “ensure the provision of safe and reliable electricity to consumers”, the Commission monitors the health and safety performance of the NESI. Licensees are mandated to submit monthly Health and Safety reports to the Commission in accordance with the requirements of their licence. In 2024/Q4, out of the 99 mandatory health and 16 safety reports expected to be received from licensees, only 95 reports were The Commission will continue to enforce 100% reporting compliance by licensees as contained in the terms and conditions of their respective licences, and apply sanctions where applicable. Statistics of accidents in the NESI for 2024/Q4 are presented in Table 20. Relative to 2024/Q3, the number of accidents decreased by -3.57% (56 to 54), the number of fatalities decreased by -10.34% (29 to 26) and the number of injuries decreased by -32.14% (28 to 19). Table 20: Health and Safety (H&S) Reports in 2024/Q3 vs. 2024/Q4 | Item | 2024/Q3 | 2024/Q4 | Net Change | | --- | --- | --- | --- | | Number of Accidents | 56 | 54 | -2 | | Number of fatalities (employees&third parties) | 29 | 26 | -3 | | Number of Injuries | 28 | 19 | -9 | During the quarter (2024/Q4), none of the GenCos recorded casualties among the DisCos, Benin and Kaduna were the only DisCos that did not record 17 casualties. Out of the forty-five (45) casualties reported in the quarter, the licensees with the highest number of casualties were Eko (14), Port Harcourt (5) and Abuja (5) DisCos, which represented 31.11%, 11.11%, and 11.11% of the total, respectively. During the quarter (2024/Q4), none of the GenCos recorded casualties while among the DisCos, Benin and Kaduna were the only DisCos that did not record . Out of the forty-five (45) casualties reported in the quarter, the licensees with the highest number of casualties were Eko (14), Port Harcourt (5) and Abuja which represented 31.11%, 11.11%, and 11.11% of the total, 16 The licensees with outstanding reports are Dadin kowa (November) and Paras Energy (October, November and December). 17Casualty refers to the count of injuries and deaths arising from any safety accident/incident. 17Casualty refers to the count of injuries and deaths arising from any safety accident/incident. * * * As observed in previous quarters, DisCos continue to account for the majority of the safety challenges experienced in NESI. Cumulatively, they accounted for 93.33% of causalities recorded in 2024/Q4, having accounted for 96.30%, 100% and 92.98% in 2024/Q1, 2024/Q2 and 2024/Q3, respectively. Furthermore, TCN recorded 21 cases of damage to property/infrastructure due to explosions, fire outbreaks or acts of vandalism in 2024/Q4. The accident report showing licensees with casualties during the quarter is detailed in Figure 13. Figure 13: Accident Report for 2024/Q4 The breakdown of the causes of casualties arising from the accidents reported in 2024/Q4 is contained in Table 21. | Cause of Casualty | Number of Fatalities | Number of Injuries | | --- | --- | --- | | Wire snaps | 5 | 2 | | Illegal/unauthorised access | 3 | 1 | | Vandalism | 8 | 0 | | Unsafe acts/conditions | 7 | 14 | | Falls from height | 0 | 0 | * * * The Commission has initiated investigations into all reported accidents and will enforce appropriate actions where necessary. Furthermore, the Commission continues to closely monitor the implementation of licensees’ accident reduction strategy for the NESI. The Commission also organises various programs including the Health and Safety Manager’s Meeting, aimed at improving the health and safety performance of the NESI. The Commission has initiated investigations into all reported accidents and will enforce appropriate actions where necessary. Furthermore, the Commission continues to closely monitor the implementation of licensees’ accident reduction strategy for the NESI. The Commission also organises various programs including the Health and Safety Manager’s Meeting, aimed at improving the health and safety The biannual Health and Safety Manager’s Meetings organised by the Commission with compliance and regulatory officers of licensees are aimed at discussing the reporting obligations of licensees as well as health and safety matters. During the meetings, licensees' scorecards on compliance with health and safety standards, forum office decisions, and key performance indicators are discussed while highlighting areas of improvement. The Commission shall continue to ensure that all licensees comply with the subsisting performance standards in the NESI. families of accident victims in the NESI. This is to ensure transparency of the families of accident victims in the NESI. This is to ensure transparency of the settlement process and to help the victim’s family secure fair compensation for losses suffered. In 2024/Q4, the Commission oversaw the successful conclusion of three families of accident victims in the NESI. This is to ensure transparency of the settlement process and to help the victim’s family secure fair compensation for losses suffered. In 2024/Q4, the Commission oversaw the successful conclusion of three (3) compensation negotiations between licensees and families of victims of accidents. accidents. * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * APPENDIX Appendix I: Old and New Names of Generating Plants in the NESI | S/N | Old Name | New Name | | --- | --- | --- | | 1 | Shiroro | Shiroro\_1 | | 2 | Kainji | Kainji\_1 | | 3 | Jebba | Jebba\_1 | | 4 | Dadin-Kowa | Dadin-Kowa\_1 | | 5 | Zungeru | Zungeru\_1 | | 6 | Egbin ST(1-6) | Egbin\_1 | | 7 | Sapele Steam | Sapele Steam\_1 | | 8 | Delta | Delta\_1 | | 9 | Geregu | Geregu\_1 | | 10 | Omotosho | Omotosho\_1 | | 11 | Olorunsogo | Olorunsogo\_1 | | 12 | Afam IV-V | Afam\_1 | | 13 | Sapele NIPP | Sapele\_2 | | 14 | Alaoji NIPP | Alaoji\_1 | | 15 | Geregu NIPP | Geregu\_2 | | 16 | Olorunsogo NIPP | Olorunsogo\_2 | | 17 | Omotosho NIPP | Omotosho\_2 | | 18 | Ihovbor NIPP | Ihovbor\_1 | | 19 | Gbarain NIPP | Gbarain\_1 | | 20 | Okpai | Okpai\_1 | | 21 | Afam VI | Afam\_2 | | 22 | AES | AES\_1 | | 23 | Omoku | Omoku\_1 | | 24 | Azura IPP | Ihovbor\_2 | | 25 | Ibom Power | Ibom Power\_1 | | 26 | Trans Amadi | Trans Amadi\_1 | | 27 | Rivers IPP | Rivers\_1 | | 28 | Odukpani | Odukpani\_1 | | 29 | Paras Energy | Ikeja\_1 | | 30 | Taopex Energy | Igbafo\_1 | * * * Appendix II: Energy Generation in 2024/Q3 vs. 2024/Q4 | GenCos | Available Capacity (MW) | | Average Daily Gen (MWh) | | Quarterly Generation (GWh) | | | --- | --- | --- | --- | --- | --- | --- | | | 2024/Q3 | 2024/Q4 | 2024/Q3 | 2024/Q4 | 2024/Q3 | 2024/Q4 | | Afam\_1 | 54.12 | 58.18 | 1,198.86 | 1,316.72 | 110.29 | 121.14 | | Afam\_2 | 330.61 | 199.43 | 7,850.09 | 4,442.86 | 722.21 | 408.74 | | Alaoji\_1 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | | Dadin-Kowa\_1 | 35.72 | 34.74 | 843.12 | 695.97 | 77.57 | 64.03 | | Delta\_1 | 366.12 | 341.17 | 8,186.21 | 7,292.18 | 753.13 | 670.88 | | Egbin\_1 | 528.27 | 614.72 | 10,993.52 | 12,111.98 | 1,011.40 | 1,114.30 | | Geregu\_1 | 141.24 | 119.59 | 2,882.79 | 2,232.56 | 265.22 | 205.40 | | Geregu\_2 | 185.53 | 224.46 | 2,433.01 | 2,847.40 | 223.84 | 261.96 | | Ibom power\_1 | 51.47 | 32.44 | 1,053.49 | 530.48 | 96.92 | 48.80 | | Igbafo\_1 | 16.36 | 19.24 | 423.93 | 467.88 | 39.00 | 43.05 | | Ihovbor\_1 | 44.57 | 65.09 | 589.47 | 490.09 | 54.23 | 45.09 | | Ihovbor\_2 | 388.03 | 445.68 | 7,869.02 | 9,269.97 | 723.95 | 852.84 | | Ikeja\_1 | 97.48 | 108.96 | 2,073.18 | 2,309.06 | 190.73 | 212.43 | | Jebba\_1 | 436.87 | 451.20 | 8,610.79 | 9,145.59 | 792.19 | 841.39 | | Kainji\_1 | 374.06 | 491.08 | 8,320.17 | 10,498.29 | 765.46 | 965.84 | | Odukpani\_1 | 265.81 | 387.87 | 4,889.91 | 7,439.54 | 449.87 | 684.44 | | Okpai\_1 | 292.09 | 262.45 | 6,009.93 | 4,967.54 | 552.91 | 457.01 | | Olorunsogo\_1 | 146.35 | 180.66 | 3,441.33 | 3,958.17 | 316.60 | 364.15 | | Olorunsogo\_2 | 92.99 | 109.08 | 1,219.34 | 516.21 | 112.18 | 47.49 | | Omoku\_1 | 54.30 | 44.27 | 1,508.92 | 1,109.42 | 138.82 | 102.07 | | Omotosho\_1 | 146.14 | 190.11 | 3,128.92 | 3,817.16 | 287.86 | 351.18 | | Omotosho\_2 | 8.44 | 12.04 | 39.86 | 178.54 | 3.67 | 16.43 | | Rivers\_1 | 116.47 | 51.53 | 1,805.92 | 925.25 | 166.14 | 85.12 | * * * Appendix III: Monthly energy offtake and energy billed by DisCos in 2024/Q3 and 2024/Q4 | DisCos | Energy Offtake(GWh) | | | | | | Energy Billed(GWh) | | | | | | Billing Efficiency | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q3 | | | 2024/Q4 | | | 2024/Q3 | | | | | | 2024/Q3(%) | 2024/Q4(%) | | | | | | Oct | Nov | Dec | July | Aug | Sept | Oct | Nov | Dec | | | | | July | Aug | Sept | Oct | Nov | Dec | July | Aug | Sept | Oct | Nov | Dec | | | | | Abuja | 378 | 380 | 365 | 382 | 391 | 390 | 307 | 312 | 292 | 302 | 309 | 307 | 81.00 | 78.92 | | Benin | 223 | 227 | 242 | 239 | 257 | 269 | 187 | 192 | 206 | 206 | 223 | 235 | 84.27 | 86.89 | | Eko | 315 | 315 | 352 | 318 | 321 | 365 | 280 | 284 | 314 | 283 | 288 | 325 | 89.30 | 89.20 | | Enugu | 203 | 212 | 214 | 203 | 216 | 230 | 151 | 165 | 161 | 148 | 160 | 167 | 74.98 | 73.13 | | Ibadan | 310 | 318 | 329 | 306 | 323 | 338 | 279 | 288 | 296 | 276 | 291 | 303 | 89.98 | 89.99 | | Ikeja | 355 | 372 | 402 | 385 | 382 | 424 | 299 | 320 | 333 | 326 | 325 | 354 | 84.24 | 84.41 | | Jos | 142 | 143 | 146 | 96 | 89 | 116 | 84 | 94 | 91 | 74 | 71 | 99 | 62.66 | 81.04 | | Kaduna | 158 | 152 | 135 | 95 | 108 | 128 | 93 | 96 | 97 | 74 | 71 | 89 | 64.01 | 70.87 | | Kano | 165 | 154 | 155 | 96 | 102 | 132 | 137 | 138 | 141 | 85 | 80 | 109 | 87.38 | 83.39 | | P/Harcourt | 188 | 184 | 187 | 183 | 175 | 224 | 153 | 154 | 162 | 157 | 150 | 196 | 83.74 | 86.31 | | Yola | 57 | 54 | 54 | 37 | 45 | 57 | 45 | 50 | 49 | 36 | 42 | 47 | 85.73 | 89.83 | | All DisCos | 2,499 | 2,522 | 2,584 | 2,339 | 2,409 | 2,673 | 2,014 | 2,092 | 2,143 | 1,967 | 2,010 | 2,231 | 82.15 | 83.66 | * * * Appendix IV: Monthly revenue performance and collection efficiency by DisCos in 2024/Q3 and 2024/Q4 | DisCos | Total Billing(N'Billion) | | | | | | Revenue Collected(N'Billion) | | | | | Collection Efficiency | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q3 | | | 2024/Q4 | | | 2024/Q3 | | | 2024/Q4 | | | 2024/Q3(%) | 2024/Q4(%) | | | July | Aug | Sept | Oct | Nov | Dec | July | Aug | Sept | Oct | Nov | Dec | | | | | Abuja | 31.05 | 33.44 | 34.77 | 35.84 | 36.95 | 35.12 | 23.86 | 26.18 | 28.24 | 27.09 | 28.53 | 25.83 | 78.87 | 75.48 | | Benin | 15.50 | 16.82 | 18.45 | 18.07 | 18.86 | 19.35 | 12.83 | 13.45 | 14.80 | 14.68 | 15.46 | 15.54 | 80.94 | 81.17 | | Eko | 31.99 | 32.85 | 38.28 | 34.30 | 35.33 | 37.68 | 28.05 | 28.71 | 30.30 | 30.94 | 31.16 | 34.47 | 84.40 | 90.00 | | Enugu | 14.14 | 15.83 | 16.75 | 15.60 | 16.71 | 16.94 | 11.16 | 12.65 | 12.25 | 12.45 | 13.71 | 13.33 | 77.23 | 80.20 | | Ibadan | 24.27 | 24.59 | 26.10 | 24.66 | 26.50 | 27.48 | 17.88 | 18.39 | 21.32 | 16.91 | 21.83 | 22.17 | 76.84 | 77.46 | | Ikeja | 29.44 | 33.91 | 36.38 | 39.74 | 40.02 | 43.58 | 24.69 | 26.13 | 32.71 | 33.45 | 34.70 | 33.77 | 83.78 | 82.63 | | Jos | 8.78 | 10.32 | 11.63 | 10.00 | 7.36 | 11.32 | 6.06 | 5.61 | 4.70 | 4.71 | 3.89 | 5.65 | 53.29 | 49.68 | | Kaduna | 8.29 | 8.06 | 8.22 | 6.11 | 6.14 | 7.20 | 4.00 | 3.61 | 3.78 | 2.94 | 4.21 | 3.65 | 46.42 | 55.52 | | Kano | 14.92 | 14.02 | 14.95 | 10.46 | 10.16 | 13.10 | 9.30 | 8.03 | 3.30 | 4.59 | 7.05 | 7.55 | 47.03 | 56.91 | | P/Harcourt | 13.97 | 13.09 | 14.25 | 13.89 | 13.13 | 17.00 | 11.28 | 9.63 | 8.30 | 11.95 | 10.05 | 11.35 | 70.76 | 75.79 | | Yola | 3.15 | 3.79 | 4.04 | 2.88 | 3.28 | 3.66 | 1.66 | 1.89 | 1.85 | 1.83 | 2.17 | 2.21 | 49.30 | 63.24 | | All DisCos | 195.50 | 206.71 | 223.81 | 211.54 | 214.44 | 232.42 | 150.77 | 154.31 | 161.60 | 161.55 | 172.77 | 175.52 | 74.55 | 77.44 | * * * Appendix V: DisCos monthly invoices & remittances to NBET in 2024/Q3 and 2024/Q4 | DisCos | Invoice(N' Billion) | | | | | | Remittance(N' Billion) | | | | | | Remittance Performance | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q3 | | | | 2024/Q4 | | | 2024/Q3 | | | | 2024/Q4 | | | 2024/Q3(%) | 2024/Q4(%) | | | July | Aug | Sept | Oct | Nov | Dec | July | Aug | Sept | Oct | Nov | Dec | | | | | | | Abuja | 21.98 | 20.68 | 20.41 | 20.83 | 20.79 | 19.85 | 17.42 | 18.84 | 20.43 | 19.75 | 20.79 | 18.80 | 89.87 | 96.53 | | | | Benin | 11.57 | 10.99 | 11.62 | 11.81 | 12.24 | 12.12 | 8.96 | 9.23 | 10.53 | 10.27 | 11.12 | 11.18 | 84.05 | 90.03 | | | | Eko | 19.99 | 18.67 | 20.58 | 18.87 | 18.74 | 19.77 | 20.04 | 18.76 | 20.62 | 18.87 | 18.74 | 19.77 | 100.00 | 100.00 | | | | Enugu | 10.17 | 10.39 | 10.04 | 9.71 | 10.12 | 10.08 | 7.88 | 8.67 | 8.38 | 8.48 | 9.49 | 9.06 | 81.47 | 90.38 | | | | Ibadan | 15.95 | 15.53 | 15.63 | 14.86 | 15.24 | 15.08 | 12.96 | 13.04 | 15.42 | 11.80 | 15.24 | 15.08 | 87.94 | 93.22 | | | | Ikeja | 22.46 | 21.94 | 23.04 | 22.35 | 21.72 | 22.61 | 18.35 | 21.77 | 23.20 | 22.35 | 21.72 | 22.61 | 93.92 | 100.00 | | | | Jos | 4.77 | 6.08 | 4.07 | 2.99 | 3.61 | 4.41 | 3.67 | 3.44 | 2.57 | 2.99 | 2.43 | 3.42 | 64.81 | 80.32 | | | | Kaduna | 7.56 | 6.72 | 3.62 | 2.46 | 4.56 | 5.19 | 2.05 | 1.74 | 1.62 | 1.18 | 2.29 | 1.53 | 30.22 | 41.02 | | | | Kano | 8.33 | 7.62 | 4.12 | 2.33 | 4.74 | 5.91 | 6.47 | 5.33 | 1.59 | 2.33 | 4.74 | 5.31 | 66.75 | 95.34 | | | | Port Harcourt | 9.26 | 8.60 | 8.72 | 8.40 | 8.17 | 9.57 | 7.96 | 6.58 | 5.56 | 8.40 | 7.12 | 7.94 | 75.62 | 89.73 | | | | Yola | 0.60 | 0.90 | 0.31 | 0.23 | 0.72 | 0.89 | 0.60 | 0.82 | 0.31 | 0.23 | 0.72 | 0.89 | 95.05 | 100.00 | | | Notes: 1. Where the remittance by a DisCo for a given period is more than the invoice received (Remittance performance >100%), it reflects payment for outstanding bills/arrears 2\. All data is based on MRO/DRO * * * Appendix VI: DisCos monthly invoices & remittances to MO in 2024/Q3 and 2024/Q4 | DisCos | Invoice(N'Billion) | | | | | | Remittance(N'Billion) | | | | | | Remittance Performance | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q3 | | | 2024/Q4 | | | 2024/Q3 | | | 2024/Q4 | | | 2024/Q3(%) | 2024/Q4(%) | | | July | Aug | Sept | Oct | Nov | Dec | July | Aug | Sept | Oct | Nov | Dec | | | | | Abuja | 2.97 | 3.36 | 3.09 | 3.15 | 2.87 | 2.86 | 2.26 | 3.00 | 2.98 | 2.96 | 2.75 | 2.69 | 87.47 | 94.65 | | Benin | 1.57 | 1.80 | 1.63 | 1.86 | 1.66 | 1.68 | 1.14 | 1.45 | 1.44 | 1.58 | 1.40 | 1.38 | 80.44 | 84.00 | | Eko | 2.40 | 2.66 | 2.12 | 1.88 | 1.81 | 2.59 | 1.60 | 2.48 | 1.94 | 1.70 | 1.58 | 2.32 | 83.84 | 89.01 | | Enugu | 1.02 | 1.67 | 1.60 | 1.57 | 1.59 | 1.69 | 0.75 | 1.35 | 1.29 | 1.34 | 1.47 | 1.50 | 78.79 | 88.87 | | Ibadan | 2.19 | 2.56 | 2.48 | 2.55 | 2.21 | 2.33 | 1.69 | 2.08 | 2.43 | 1.96 | 2.21 | 2.33 | 85.89 | 91.59 | | Ikeja | 2.84 | 3.10 | 2.89 | 2.99 | 2.62 | 2.91 | 2.68 | 2.94 | 2.74 | 2.84 | 2.44 | 2.71 | 94.68 | 93.76 | | Jos | 1.14 | 1.30 | 1.19 | - | - | 0.85 | 0.79 | 0.60 | 0.65 | - | - | 0.63 | 56.20 | 74.35 | | Kaduna | 1.31 | 1.41 | 1.27 | - | 0.26 | 0.94 | 0.16 | 0.11 | 0.40 | - | 0.01 | 0.19 | 17.04 | 16.47 | | Kano | 1.26 | 1.39 | 1.03 | - | - | 0.58 | 0.92 | 0.89 | 0.24 | - | - | 0.42 | 55.71 | 72.13 | | Port Harcourt | 1.36 | 1.34 | 1.31 | 1.40 | 0.98 | 1.51 | 1.12 | 0.96 | 0.78 | 1.27 | 0.84 | 1.22 | 71.57 | 85.81 | | Yola | 0.50 | 0.55 | 0.45 | - | - | 0.57 | 0.46 | 0.38 | 0.45 | - | - | 0.57 | 86.67 | 100.00 | | All DisCos | 18.57 | 21.13 | 19.06 | 15.40 | 14.00 | 18.51 | 13.59 | 16.23 | 15.35 | 13.66 | 12.70 | 15.95 | 76.88 | 88.32 | Notes: 1. Where the remittance by a DisCo for a given period is more than the invoice received (Remittance performance >100%), it reflects payment for outstanding bills/arrears * * * Appendix VII: Domestic and international bilateral customers invoices & remittances to MO in 2024/Q4 | | Oct-24 | | Nov-24 | | Dec-24 | | 2024/Q4 | | 2024/Q4 | Other Remittances(million) | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | RemittancePerformance(%) | | | | | International Customers | | | | | | | | | | | | | PARAS-SBEE($) | 1.55 | 0 | 1.30 | 0 | 1.42 | 0 | 4.28 | 0 | 0.00 | 1.68 | | | PARAS-CEET($) | | | | | | | | | | | | | TRANSCORP-SBEE(UGHELI)($) | 0.93 | 0.93 | 1.67 | 1.67 | 2.18 | 0 | 4.79 | 2.60 | 54.28 | 1.30 | | | TRANSCORP-SBEE(AFAM3)($) | 0.91 | 0.91 | 0.81 | 0.81 | 0.86 | 0.86 | 2.59 | 2.59 | 100.00 | 0.00 | | | MAINSTREAM-NIGELEC($) | 0.92 | 0 | 0.85 | 0 | 0.59 | 0 | 2.37 | 0 | 0.00 | 0.00 | | | ODUKPANI-CEET($) | 4.31 | 1.84 | 4.63 | 2.48 | 5.05 | 0.86 | 14.05 | 5.21 | 38.64 | 2.98 | | | Total | | | | | | | | | | | | | Bilateral Customers | | | | | | | | | | | | | MSTM/INNER GALAXY(N) | | | | | | | | | | | | | MSTM/KAM IND.(N) | | | | | | | | | | | | | MSTM/KAM INT.(N) | 376.33 | 376.33 | 357.96 | 357.96 | 400.83 | 400.83 | 1,135.14 | 1,135.14 | 100.00 | 0.00 | | | MAINSTREAM/PRISE(N) | | | | | | | | | | | | | MSTM ZEBERCED(N) | | | | | | | | | | | | | MSTM/ADFV(N) | | | | | | | | | | | | | NDPHC/WEEWOOD(N) | 32.38 | 0.00 | 31.80 | 0.00 | 28.63 | 0.00 | 92.82 | 0.00 | 0.00 | 21.06 | | | NORTH SOUTH/STAR P(N) | 10.28 | 0.00 | 10.03 | 0.00 | 10.41 | 0.00 | 30.73 | 0.00 | 0.00 | 11.00 | | | TRANS AMADI/OAU(N) | 6.61 | 6.00 | 10.82 | 8.93 | 11.38 | 0.00 | 28.82 | 17.44 | 60.50 | 20.74 | | | TRANS AMADI/FMPI(N) | | | | | | | | | | | | | NDPHC/SUNFLAG(N) | 13.45 | 0.00 | 14.17 | 0.00 | 9.61 | 0.00 | 37.25 | 0.00 | 0.00 | 0.00 | | | OMOTOSHO II/PULKIT(N) | | | | | | | | | | | | | ALAOJI GENCO/APLE(N) | 102.30 | 100.00 | 126.92 | 0.00 | 156.70 | 0.00 | 385.93 | 100.00 | 25.91 | 0.00 | | * * * Appendix VIII: Meter installation for all Frameworks (MAP, NMMP, Vendor and DisCo Financed) | DisCos | Meters contracted | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Meters installed in 2024/Q3 | Meters installed in 2024/Q4 | Total installations since 2019 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Aba | 24,000 | - | - | - | 9,917 | 7,817 | 8,784 | 4,928 | 2,199 | 33,645 | | Abuja | 1,000,475 | 105,253 | 87,987 | 83,494 | 105,154 | 21,493 | 11,733 | 26,951 | 20,755 | 526,745 | | Benin | 664,646 | 11,154 | 72,838 | 6,771 | 34,344 | 10,455 | 3,510 | 17,175 | 23,965 | 181,381 | | Eko | 283,178 | 32,353 | 64,618 | 44,577 | 36,484 | 4,637 | 810 | 17,982 | 14,688 | 221,928 | | Enugu | 713,926 | 54,603 | 96,836 | 57,751 | 73,256 | 13,932 | 4,241 | 19,075 | 16,488 | 353,843 | | Ibadan | 1,106,294 | 38,403 | 94,309 | 146,044 | 139,138 | 25,551 | 5,865 | 39,624 | 37,089 | 554,352 | | Ikeja | 1,186,114 | 160,469 | 125,460 | 145,364 | 151,197 | 27,795 | 9,076 | 46,959 | 53,431 | 743,311 | | Jos | 606,096 | 4,673 | 88,827 | 19,190 | 12,937 | 3,649 | 3,114 | 2,824 | 3,525 | 159,736 | | Kaduna | 519,152 | 8,258 | 17,942 | 34,385 | 10,039 | 3,027 | 2,450 | 1,845 | 2,439 | 81,229 | | Kano | 562,747 | 3,314 | 80,969 | 3,476 | 2,056 | 199 | 418 | 767 | 1,226 | 92,850 | | Port Harcourt | 220,044 | 36,546 | 92,543 | 33,549 | 48,989 | 6,278 | 1,825 | 6,377 | 7,878 | 241,988 | | Yola | 749,376 | 478 | 5,955 | 30,386 | 19,295 | 831 | - | - | 1,755 | 58,310 | | Total | 7,636,048 | 455,504 | 828,284 | 604,987 | 642,806 | 125,664 | 51,826 | 184,507 | 185,439 | 3,017,006 | * * * Appendix IX: Meter installation through the MAF Framework as of 2024/Q4 | DisCos | Meters installed in2024/Q4 | Totalinstallationssince2024 | | --- | --- | --- | | Aba | - | - | | Abuja | 568 | 568 | | Benin | - | - | | Eko | - | - | | Enugu | - | - | | Ibadan | - | - | | Ikeja | - | - | | Jos | 1674 | 1674 | | Kaduna | - | - | | Kano | 79 | 79 | | PortHarcourt | - | - | | Yola | 1755 | 1755 | | Total | 4076 | 4076 | * * * Appendix X: Meter installation through the MAP Framework as of 2024/Q4 | DisCos | Meters contracted | Meters installed in2020 | Meters installed in2021 | Meters installed in2022 | Meters installed in2023 | Meters installed in2024/Q1 | Meters installed in2024/Q2 | Meters installed in2024/Q3 | Meters installed in2024/Q4 | Totalinstallationssince2019 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Aba | 12,000 | - | - | - | 8,475 | 1,346 | 301 | 2,135 | 1,013 | 13,270 | | Abuja | 900,000 | 87,476 | 5,289 | 82,293 | 103,200 | 21,440 | 10,717 | 26,376 | 20,536 | 421,252 | | Benin | 573,776 | 11,154 | 1,104 | 422 | 29,181 | 10,419 | 3,510 | 17,175 | 23,397 | 97,531 | | Eko | 204,000 | 32,298 | 7,703 | 28,883 | 30,156 | 4,637 | 810 | 17,982 | 14,688 | 142,918 | | Enugu | 621,545 | 54,752 | 5,405 | 57,372 | 73,256 | 13,932 | 4,241 | 19,075 | 16,489 | 261,734 | | Ibadan | 988,915 | 33,418 | 548 | 127,418 | 125,752 | 25,551 | 5,828 | 39,603 | 37,089 | 399,978 | | Ikeja | 1,074,411 | 160,616 | 13,781 | 145,364 | 147,741 | 25,281 | 5,732 | 46,819 | 53,431 | 622,154 | | Jos | 500,000 | 3,769 | 27 | 3,317 | 12,151 | 1,165 | 283 | 547 | 1,477 | 21,365 | | Kaduna | 450,000 | 7,352 | 2,767 | 3,565 | 9,887 | 3,003 | 2,186 | 1,845 | 2,438 | 33,172 | | Kano | 475,000 | 3,303 | - | 976 | 2,056 | 199 | 322 | 781 | 628 | 8,060 | | PortHarcourt | 137,324 | 22,334 | 24,035 | 33,549 | 48,989 | 6,278 | 1,825 | 6,377 | 7,878 | 159,268 | | Yola | 664,000 | - | - | - | 2,721 | 831 | - | - | - | 3,552 | | Total | 6,600,971 | 416,472 | 60,659 | 483,159 | 593,565 | 114,082 | 35,775 | 178,715 | 179,064 | 2,184,252 | * * * Appendix XI: Meter installation through Vendor and DisCo Finance Frameworks as of 2024/Q4 | DisCos | Vendor Finance | | | | | | DisCo Finance | | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Meters installed in 2024/Q3 | Meters installed in 2024/Q4 | Total installations | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Meters installed in 2024/Q3 | Meters installed in 2024/Q4 | Meters installed in 2024/Q4 | Total installations since 2019 | | | | Aba | 1,442 | 6,471 | 8,483 | 2,793 | 1,186 | 20,375 | | | | - | - | - | - | - | - | - | - | | Abuja | 1,954 | 53 | 1,016 | 575 | 219 | 5,018 | - | - | - | - | - | - | - | - | - | - | - | | Benin | 2,849 | 36 | - | - | | 3,126 | - | - | - | - | - | - | - | - | - | - | - | | Eko | - | - | - | - | | | - | - | - | - | - | - | - | - | - | - | - | | Enugu | - | - | - | - | | | 193 | 193 | 105 | - | - | - | - | - | - | - | 597 | | Ibadan | - | - | - | - | | | - | - | - | 13,379 | - | 37 | 21 | 374 | 84 | | | | Ikeja | 3,456 | 2,514 | 3,344 | 140 | | 9,454 | - | - | - | - | - | - | - | - | - | - | - | | Jos | - | - | - | - | | | - | 2,326 | 7,164 | 257 | 2,484 | 2,831 | 2,277 | | | 40,932 | | | Kaduna | - | - | - | - | | | - | - | 96 | 53 | - | - | - | - | - | 149 | | | Kano | - | - | - | - | 519 | 1,135 | - | - | - | - | - | 96 | - | | | 96 | | | Port Harcourt | - | - | - | - | | | - | - | - | - | - | - | - | - | - | - | - | | Yola | - | - | - | - | | | - | - | - | - | - | - | - | - | - | - | - | | Total | 9,701 | 9,074 | 12,843 | 3,508 | 1,924 | 39,108 | 193 | 2,519 | 7,365 | 53 | 2,484 | 2,964 | 2,298 | 374 | 78,769 | | | * * * Appendix XII: Category of complaints received by DisCos in 2024/Q4 | DisCos | Complaints Received | Complaint Categories | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | | | | Aba | 5,513 | 3,629 | 145 | 23 | 2 | 740 | 57 | 138 | 779 | | Abuja | 23,963 | 9,274 | 548 | 146 | - | 677 | 1,971 | - | 11,347 | | Benin | 13,953 | 182 | 973 | 104 | 118 | 920 | 79 | 4 | 11,609 | | Eko | 47,510 | 28,205 | 3,930 | 220 | 7 | 2,199 | - | - | 13,350 | | Enugu | 15,617 | 13,227 | 835 | 146 | 1 | 919 | 91 | 40 | 358 | | Ibadan | 47,510 | 27,279 | 1,049 | 169 | - | 15,081 | 2,015- | - | 1,917 | | Ikeja | 23,236 | 12,843 | 2,351 | 307 | 66 | 1,628 | 93 | 204 | 5,744 | | Jos | 19,882 | 6,742 | 8,193 | 230 | 1 | 2,989 | 202 | 1 | 1,524 | | Kaduna | 4,168 | 1,211 | 2,139 | 273 | 32 | 212 | 111 | 19 | 171 | | Kano | 17,328 | 15,886 | 467 | 50 | - | 870 | 18 | - | 37 | | Port Harcourt | 54,683 | 21,774 | 2,339 | 852 | - | 3,234 | 346 | 157 | 25,981 | | Yola | 1,917 | 1,143 | 470 | 177 | 7 | 38 | 67 | - | 15 | | All DisCos | 275,681 | 141,395 | 23,403 | 2,697 | 234 | 29,507 | 5,050 | 563 | 72,832 | * * * Appendix XIII: Category of complaints received at the NERC-CCU in 2024/Q4 | DisCos | Complaints Received | Complaints Resolved | Credit Adjustment(N'000) | Complaint Categories | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | Band | Non-compliance | | | | | | Aba | 8 | 1 | 0 | 1 | 3 | 0 | 0 | 0 | 3 | | 0 | 1 | 0 | | Abuja | 672 | 232 | 0 | 175 | 117 | 9 | 3 | 229 | 62 | | 1 | 72 | 3 | | Benin | 116 | 42 | 139,480 | 19 | 37 | 3 | 2 | 35 | 17 | | 0 | 1 | 0 | | Eko | 836 | 262 | 0 | 372 | 114 | 7 | 2 | 209 | 40 | | 1 | 82 | 0 | | Enugu | 167 | 64 | 554,236 | 59 | 24 | 1 | 3 | 54 | 18 | | 0 | 2 | 0 | | Ibadan | 315 | 7 | 0 | 134 | 60 | 3 | 2 | 68 | 13 | | 1 | 32 | 0 | | Ikeja | 1,731 | 490 | 29,348,036 | 672 | 194 | 5 | 4 | 652 | 143 | | 3 | 45 | 0 | | Jos | 41 | 21 | 0 | 11 | 10 | 3 | 0 | 2 | 5 | | 0 | 10 | 1 | | Kaduna | 18 | 9 | 0 | 1 | 11 | 0 | 1 | 2 | 2 | | 0 | 1 | 0 | | Kano | 13 | 2 | 0 | 3 | 8 | 0 | 0 | 0 | 0 | | 0 | 2 | 0 | | Port Harcourt | 240 | 92 | 0 | 88 | 61 | 3 | 2 | 51 | 17 | | 0 | 13 | 0 | | Yola | 23 | 9 | 0 | 4 | 9 | 1 | 0 | 4 | 2 | | 0 | 1 | 0 | | All DisCos | 4,180 | 1,231 | 40,193,039 | 1,539 | 648 | 35 | 19 | 1,306 | 322 | | 6 | 263 | 4 | * * * Appendix XIV: List and addresses of NERC Forum Offices as of December 2024 | S/N | Forum Office | Location | Telephone | Email | | --- | --- | --- | --- | --- | | 1 | Abakaliki, Ebonyi State | 3, Ezekuna Crescent, Off Nsugbe Street, Abakaliki Ebonyi State | 9037808590 | [abakalikiforum@nerc.gov.ng](mailto:abakalikiforum@nerc.gov.ng) | | 2 | Abeokuta, Ogun State | 33, First Avenue, Ibara Housing Estate, Ibrar GRA, Abekaua | 9139381008 | [abeokutaforum@nerc.gov.ng](mailto:abeokutaforum@nerc.gov.ng) | | 3 | Abuja, FCT | 14, Road 131, Gwarinpa, Federal Capital Territory, Abujia | 8146862225 | [abujiaforum@nerc.gov.ng](mailto:abujiaforum@nerc.gov.ng) | | 4 | \*Ado-Ekiti, Ekiti State | Km 5, Iwokoro Road, Ado Ekiti, Ekiti State | 9169978242 | [ado-ekitifiorum@nerc.gov.ng](mailto:ado-ekitifiorum@nerc.gov.ng) | | 5 | Asaba, Delta State | Denis Osadebe Way, Beside Mobil Filling Station, Asaba, Delta State | 9062277247 | [asabaforum@nerc.gov.ng](mailto:asabaforum@nerc.gov.ng) | | 6 | Awka, Anambra State | Plat 80, Aroma Junction Layout, Opp, CBN, Awka, Anambra State | 9037808594 | [awkaforum@nerc.gov.ng](mailto:awkaforum@nerc.gov.ng) | | 7 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bouchi, Bauchi State | 9062924607 | [bauchiforum@nerc.gov.ng](mailto:bauchiforum@nerc.gov.ng) | | 8 | \*Benin, Edo State | 34, Akpakpava Street, Benin City, Edo State | 9037808592 | [beninforum@nerc.gov.ng](mailto:beninforum@nerc.gov.ng) | | 9 | B/Kebbi, Kebbi State | 8, Ahmadu Bello Way, Opp. Kebbi State Govt House, Kebbi State | 9062863161 | [birninkebbiforum@nerc.gov.ng](mailto:birninkebbiforum@nerc.gov.ng) | | 10 | Calabar, C/Rivers State | Plat 109, MCC Road by Ibok Street, Calabar, Cross River State | 9062863159 | [calabarforum@nerc.gov.ng](mailto:calabarforum@nerc.gov.ng) | | 11 | Damaturu, Yobe State | No. 5, AD Road, Abba Ibrahim Extension, Off Potiskum Road, Damaturu, Yobe State | 9169978243 | [damaturuforum@nerc.gov.ng](mailto:damaturuforum@nerc.gov.ng) | | 12 | Dutez, Jigawa State | Dutez G.R.A, Dutez, Jigawa State | 7031704827 | [jigawaforum@nerc.gov.ng](mailto:jigawaforum@nerc.gov.ng) | | 13 | Eko, Lagos State | 61, Odunlani Street, Off Marina, Lagos Island, Lagos State | 8106870261 | [ekoformorum@nerc.gov.ng](mailto:ekoformorum@nerc.gov.ng) | | 14 | \*Enugu, Enugu State | John Anichukuw Close, Plot 7 Mkpokiti Pocket Layout, Enugu, Enugu State | 8146862230 | [enuguforum@nerc.gov.ng](mailto:enuguforum@nerc.gov.ng) | | 15 | Gombe, Gombe State | Government Taxe GDP/2, Along Ministry of Education Road, Gombe State | 8140400797 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) | | 16 | Gusau, Zamfara State | 2 Canteen Daij, J. B. Yakubu Road, Gusau, Zamfara State | 9062863163 | [gusauforum@nerc.gov.ng](mailto:gusauforum@nerc.gov.ng) | | 17 | \*Ibadan, Oyo State | Jibowu Str, Maga, Maga Police Station, Iyaganku, G.R.A, Ibadan, Oyo State | 8146862252 | [ibadaforum@nerc.gov.ng](mailto:ibadaforum@nerc.gov.ng) | | 18 | Ikewa, Lagos State | 199, Obafemi Awolowo Way, Alausa, Ikewa, Lagos State | 8106870298 | [ikeieforum@nerc.gov.ng](mailto:ikeieforum@nerc.gov.ng) | | 19 | Ilorin, Kwara State | 30, Stadium Road, Off Taiwo Road, Ilorin, Kwara State | 9062924603 | [ilorinforum@nerc.gov.ng](mailto:ilorinforum@nerc.gov.ng) | | 20 | Jos, Plateau State | 5a, Rayfield Road, Jos, Plateau State | 9037808597 | [josformorum@nerc.gov.ng](mailto:josformorum@nerc.gov.ng) | | 21 | Kaduna, Kaduna State | 22, Ahmadu Bello Way, Opposite NNDC Building, Kaduna, Kaduna State | 8106870299 | [kadunaforum@nerc.gov.ng](mailto:kadunaforum@nerc.gov.ng) | | 22 | Kano, Kano State | 2 Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 8146862222 | [kanoforum@nerc.gov.ng](mailto:kanoforum@nerc.gov.ng) | | 23 | Katsina, Katsina State | 7, Abjuzi Crescent, Off Hassan Usman Katsina Road, Katsina, Katsina State | 7031704821 | [katsinaforum@nerc.gov.ng](mailto:katsinaforum@nerc.gov.ng) | | 24 | Lafia, Nasarawa State | Manjiy Street, Off Jos Road, Bukan Sidi, Lafia, Nasarawa State | 9062924599 | [lafiforum@nerc.gov.ng](mailto:lafiforum@nerc.gov.ng) | \*Forum Offices that were closed during 2024/Q4 due to the transfer of the regulatory oversight to the respective states where they are located. * * * Appendix XV: Appeals handled by Forum Offices in 2024/Q3 and 2024/Q4 | S/N | 2024/Q3 | | | | 2024/Q4 | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Forum Offices | Appeals Received | Appeals Resolved | Appeals Pending | Resolution Rate (%) | Appeals Received | Appeals Resolved | Appeals Pending | Resolution Rate (%) | | | 1 | Abakaliki, Ebonyi State | 64 | 57 | 6 | 89.06 | 49 | 34 | 15 | 69.39 | | 2 | Abeokuta, Ogun State | 180 | 90 | 30 | 50.00 | 228 | 82 | 48 | 35.96 | | 3 | Abuja, FCT | 65 | 48 | 17 | 73.85 | 77 | 61 | 16 | 79.22 | | 4 | Ado-Ekiti | 24 | 17 | 7 | 70.83 | 10 | 7 | 3 | 70.00 | | 5 | Asoba, Delta State | 55 | 38 | 17 | 69.09 | 74 | 48 | 26 | 64.86 | | 6 | Awka, Anambra State | 168 | 94 | 74 | 55.95 | 172 | 150 | 22 | 87.21 | | 7 | Bauchi, Bauchi State | 6 | 6 | 0 | 100.00 | 10 | 2 | 8 | 50.00 | | 8 | Benin, Edo State | 49 | 19 | 30 | 0.00 | 55 | 30 | 25 | 0.00 | | 9 | Damaturu, Yobe State | 5 | 3 | 2 | 0.00 | 4 | 4 | 0 | 0.00 | | 10 | Calabar, C/Rivers State | 31 | 20 | 11 | 64.52 | 35 | 28 | 7 | 80.00 | | 11 | Dutse, Jigawa State | 3 | 2 | 1 | 66.67 | 3 | 0 | 3 | 0.00 | | 12 | Eko, Lagos State | 270 | 175 | 94 | 64.81 | 303 | 205 | 98 | 67.66 | | 13 | Enugu, Enugu State | 186 | 151 | 26 | 81.18 | 26 | 0 | 26 | 0.00 | | 14 | Gombe, Gombe State | 20 | 1 | 18 | 5.00 | 27 | 14 | 12 | 51.85 | | 15 | Gusau, Zamfara State | 7 | 1 | 6 | 14.29 | 14 | 6 | 8 | 42.86 | | 16 | Ibadan, Oyo State | 220 | 59 | 161 | 26.82 | 311 | 113 | 198 | 36.33 | | 17 | Ikewa, Lagos State | 719 | 414 | 305 | 57.58 | 587 | 544 | 43 | 92.67 | | 18 | Illorin, Kwara State | 159 | 129 | 30 | 81.13 | 201 | 179 | 22 | 89.05 | | 19 | Jos, Plateau State | 38 | 23 | 15 | 60.53 | 30 | 30 | 0 | 100.00 | | 20 | Kaduna, Kaduna State | 29 | 24 | 4 | 82.76 | 26 | 14 | 6 | 53.85 | | 21 | Kano, Kano State | 23 | 17 | 0 | 73.91 | 30 | 22 | 8 | 73.33 | | 22 | Katsina, Katsina State | 4 | 3 | 1 | 75.00 | 1 | 1 | 0 | 100.00 | \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Appendix XVI: Category of appeals received by Forum Offices in 2024/Q3 and 2024/Q4 | Forum Office | 2024/Q3 | | | | | | 2024/Q4 | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others | Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others | | | 46 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 42 | 0 | 0 | 1 | 0 | 0 | 0 | | | Abakaliki, Ebonyi State | 55 | 8 | 0 | 0 | 32 | 4 | 1 | 17 | 63 | 7 | 0 | 0 | 78 | 16 | 1 | 33 | | Abeokuta, Ogun State | 2 | 0 | 0 | 0 | 41 | 0 | 0 | 7 | 2 | 0 | 0 | 0 | 53 | 0 | 0 | 5 | | Abuja, FCT | 8 | 2 | 0 | 2 | 3 | 0 | 1 | 0 | 2 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | | Ado-Ekili, Ekiti State | 8 | 1 | 0 | 2 | 5 | 0 | 0 | 4 | 43 | 1 | 0 | 0 | 6 | 0 | 0 | 0 | | Aasaba, Delta State | 30 | 1 | 0 | 0 | 5 | 0 | 0 | 1 | 87 | 1 | 0 | 0 | 4 | 0 | 0 | 1 | | Awka, Anambra State | 104 | 7 | 0 | 0 | 10 | 0 | 0 | 1 | 3 | 6 | 1 | 1 | 0 | 2 | 0 | 1 | | Bauchi, Beach State | 2 | 0 | 0 | 0 | 1 | 0 | 0 | 3 | 1 | 1 | 0 | 0 | 3 | 0 | 0 | 3 | | Benin, Edo State | 31 | 0 | 1 | 0 | 5 | 0 | 0 | 5 | 19 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | | Damaturu, Yabe State | 3 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | | Calabar, C/Rivers State | 16 | 1 | 0 | 0 | 5 | 0 | 0 | 2 | 11 | 5 | 0 | 0 | 5 | 0 | 0 | 2 | | Dutse, Jigawa State | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | | Eko, Lagos State | 93 | 2 | 0 | 13 | 77 | 0 | 1 | 21 | 68 | 12 | 0 | 0 | 92 | 0 | 0 | 24 | | Enugu, Enugu State | 82 | 12 | 0 | 0 | 16 | 0 | 0 | 0 | 0 | 0 | 0 | 13 | 0 | 0 | 0 | 0 | | Gombe, Gombe State | 3 | 0 | 0 | 0 | 5 | 0 | 0 | 0 | 5 | 0 | 0 | 0 | 4 | 0 | 0 | 0 | | Gusau, Zamfara State | 4 | 1 | 1 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 6 | 0 | 1 | 1 | * * * ## FOURTH QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]