## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## i \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # NERC©2024 # 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 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # Table of Contents ## List of Figures ... iv ## List of Tables ... 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 ... 8 ## 2.1.5 Generation mix ... 10 ## 2.2 Grid Performance ... 11 ## 2.2.1 Transmission loss factor ... 12 ## 2.2.2 Grid frequency ... 13 ## 2.2.3 Voltage fluctuation ... 15 ## 2.2.4 System collapse ... 16 ## 2.3 Commercial Performance ... 18 ## 2.3.1 Energy offtake performance ... 18 ## 2.3.2 Energy billed and billing efficiency ... 20 ## 2.3.3 Revenue and collection efficiency ... 21 ## 2.3.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss ... 23 ## 2.3.5 Market Remittance ... 25 ## 3.0 REGULATORY FUNCTIONS ... 33 ## 3.1 Regulations, Orders and Directives ... 34 ## 3.1.1 Regulations ... 34 ## 3.1.2 Orders ... 34 ## 3.1.3 Directives ... 39 ## 3.2 Licences Issued or Renewed ... 39 ## 3.3 Captive Power Generation Permits ... 40 ## 3.4 Mini-grid Permits and Registration Certificates ... 41 ## 3.5 Meter Service Providers/Meter Asset Providers ... 41 ## 3.6 Hearings and Public Consultations ... 42 ## 3.7 Compliance and Enforcement ... 43 ## 4.0 CONSUMER AFFAIRS ... 47 ## 4.1 Consumer Enlightenment and Stakeholder Engagements ... 47 ## 4.2 Metering End-Use Customers ... 48 ## 4.3 Customer Complaints ... 51 ## 4.3.1 NERC-CCU ... 52 ## 4.3.2 DisCo-CCUs ... 53 ## 4.3.3 Forum Offices ... 54 ## 4.4 Health and Safety ... 56 ## 5.0 Appendix ... 61 ## iii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # List of Figures **Figure 1: Average Available Capacity (MW) in 2024/Q2 vs. 2024/Q3 ... 3** **Figure 2: Average Hourly Generation (MWh/h) in 2024/Q2 vs. 2024/Q3 ... 7** **Figure 3: Load Factor (%) in 2024/Q2 vs. 2024/Q3 ... 10** **Figure 4: Electricity Generated by Energy Sources (%) in 2024/Q2 vs. 2024/Q3 ... 11** **Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) Apr-Sep 2024.. 13** **Figure 6: Monthly System Frequency (Hz) from April – September 2024 ... 14** **Figure 7: Monthly System Voltage (kV) from April-September 2024 ... 16** **Figure 8: DisCos Remittance Performances to NBET in 2024/Q3 ... 28** **Figure 9: DisCos Remittance Performances to MO in 2024/Q3 ... 29** **Figure 10: Category of complaints received at the Commission’s CCU in 2024/Q3 ... 53** **Figure 11: Category of complaints received by DisCos in 2024/Q3 ... 54** **Figure 12: Category of Complaints Received by Forum Offices in 2024/Q3 ... 56** **Figure 13: Accident Report for 2024/Q3 ... 58** ## iv \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * List of Tables Table 1: Plant Availability Factor (%) in 2024/Q2 vs. 2024/Q3.................................... 5 Table 2: Average Hourly Generation (MWh/h) in 2024/Q2 vs. 2024/Q3..................... 8 Table 3: System Collapse in 2024/Q3........................................................................ 17 Table 4: DisCo energy offtake performance in 2024/Q2 vs. 2024/Q3......................... 20 Table 5: Energy received and billing efficiency by DisCos in 2024/Q2 vs. 2024/Q3.... 21 Table 6: Revenue Collection Performance (%) of DisCos in 2024/Q2 vs. 2024/Q3 ...... 22 Table 7: ATC&C Loss (%) by DisCos in 2024/Q2 vs. 2024/Q3 ................................... 25 Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q3.......... 26 Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q3 ..................... 30 Table 10: Invoices and Remittances of Other Customers in 2024/Q3............................ 31 Table 11: Licences issued by the Commission in 2024/Q3............................................ 39 Table 12: Captive Generation Plants approved in 2024/Q3........................................ 40 Table 13: Meter Service Providers certified in 2024/Q3.............................................. 41 Table 14: Hearings conducted by the Commission in 2024/Q3.................................... 43 Table 15: Compliance and Enforcement Actions of the Commission in 2024/Q3........... 44 Table 16: Metering Progress as of 2024/Q3............................................................... 48 Table 17: Meter Deployment by DisCos 2024/Q3 vs. 2024/Q2.................................. 49 Table 18: Meter Installations under the National Mass Metering Programme (NMMP).. 50 Table 19: Complaints Received by DisCos in 2024/Q2 vs. 2024/Q3........................... 53 Table 20: Appeals handled by Forum Offices in 2024/Q3........................................... 55 Table 21: Health and Safety (H&S) Reports in 2024/Q2 vs. 2024/Q3......................... 57 Table 22: Causes of casualties recorded in 2024/Q3.................................................. 58 * * * 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 | | EKEDC | 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 | * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## vii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * #### THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 1.0 SUMMARY ### 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.** ### Operational Performance ### The Operational performance parameters reported in 2024/Q3 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/Q3, there were twenty- eight (28) grid-connected power plants consisting of nineteen (19) gas,** #### The average ### five (5) hydro, two (2) steam, and two (2) gas/steam-powered plants. **available** ### For this quarter, the average available generation capacity of the grid- **generation** **capacity in** ### connected power plants was 5,100.90MW. #### 2024/Q3 was **5,100.90MW** **The average available generation capacity across the grid-connected plants increased by +16.04% (+705.13MW) from the 4,395.77MW** **recorded in 2024/Q2 to 5,100.90MW in 2024/Q3 (Figure A). Nineteen (19) power plants recorded increased available generation** ### capacities in 2024/Q3 compared to 2024/Q2. **1** **AES and Gbarain power plants are not included in the report because they are currently not operational.** **Maiduguri Emergency Power Plant (MEPP) is currently not configured to evacuate power onto the grid due to** **transmission limitations.** **viii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **6,000** **5,533** **) 5,500** **(MW** **5,000 4,915** **4,854** **4,574 Average Available Capacity (2024/Q3) 5,100.90MW** **4,500 4,391** **4,223** **Average Available Capacity 4,000** **Average Available Capacity (2024/Q2) 4,395.77MW** **3,500** **Apr-24 May-24 Jun-24 Jul-24 Aug-24 Sep-24** **Months** # Figure A: Available Generation Capacity (April-September 2024) **b. Quarterly Generation: The average hourly generation on the grid in 2024/Q3 was 4,280.24MWh/h, which translates to a total** # generation of 9,450.76GWh. The average hourly generation of grid- ## The average ## hourly generation # connected power plants increased by +6.51% (+261.67MWh/h) from ## in 2024/Q3 was 4,018.57MWh/h in 2024/Q2. The total electricity generated in the **2** **4,280.24MWh/h quarter also increased by +7.68% (+674.21GWh) from** # 8,776.55GWh in 2024/Q2 to 9,450.76GWh (Figure B). The increase # in generation during the quarter was primarily due to the increase in # the available generation capacities of the grid-connected power plants compared to 2024/Q2. **2** **The percentage change in total generation and average hourly generation in 2024/Q2 vs 2024/Q3 is** **different because the number of days in the quarters is not the same (91/92). When the number of days in the** **quarters being compared are the same, the percentage change in total generation will be the same as the** **percentage change in average hourly generation.** ## ix \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **4,600** **4,492** **h) 4,400** **/** **4,262** **199** **(MWh** **4,200** **4,** **,150** **4** **4,000 3,960** **Average Hourly Generation (2024/Q3) 4,280. 24MWh/h** **3,834** **3,800** **Average Hourly Generation (2024/Q2) 4,081.57MWh/h** **Average Hourly Generation 3,600** **3,400** **Apr-24 May-24 Jun-24 Jul-24 Aug-24 Sep-24** **Months** # Figure B: Average Hourly Generation (April-September 2024) **c. Grid Performance: In 2024/Q3, the average lower daily (49.56Hz) and average upper daily (50.75Hz) 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 (299.64kV) and average upper daily (352.68kV)** # 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. # One (1) incident of partial collapse on the national grid occurred in # 2024/Q3. The incident occurred on 06 July 2024. In line with 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/Q3 covers energy offtake performance, billing efficiency, collection efficiency, aggregate** **technical, commercial, and collection loss, as well as the market remittance of relevant market participants. The Commission monitors** ## x \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 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 total of ₦466.69 billion was collected by all DisCos in 2024/Q3 out of the ₦626.02 billion billed to customers. a. Energy Offtake Performance: In 2024/Q3, the average energy offtake by DisCos at their trading points was 3,445.13MWh/h out of the available PCC of 3,807.98MWh/h translating to an overall offtake performance of 90.47%. The energy offtake during the quarter (3,445.1MWh/h) represents an increase of +8.81% (+279.20MWh/h) compared to the 3,165.93MWh/h recorded in 2024/Q2. b. Billing Efficiency: The total energy received by all DisCos in 2024/Q3 was 7,606.84GWh while the energy billed to end-use customers was 6,249.21GWh, translating into an overall billing efficiency of 82.15%. This represents a -0.19pp decrease in billing efficiency relative to the 82.34% recorded in 2024/Q2. c. Collection Efficiency: The total revenue collected by all DisCos in 2024/Q3 was ₦466.69 billion out of ₦626.02 billion billed to customers. This translates to a collection efficiency of 74.55%, representing a decrease of -4.76pp compared to 2024/Q2 (79.31%). 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/Q3 was 39.10% comprising - technical and commercial loss (18.32%) and collection loss (25.45%). The ATC&C loss increased by +4.40pp compared to 2024/Q2 (34.70%). No DisCo achieved its target ATC&C as provided in the MYTO during the quarter. The worst underperformance relative to the target ATC&C was recorded in Kaduna DisCo (Actual – 70.84% vs. target – 25.00%). * * * 3 for DRO-adjusted generation costs from NBET and ₦58.77 billion for transmission and administrative services by the Market Operator (MO). Out of this amount, the DisCos collectively remitted a total sum of ₦370.01 billion (₦324.83 billion for NBET and ₦45.18 billion for MO) with an outstanding balance of ₦71.66 billion. This translates to a remittance performance of 83.77% in 2024/Q3 compared to the 79.76% recorded in 2024/Q2. The disaggregated DisCo remittance performance to the market for 2024/Q3 is presented in Figure C. f. Remittance by Special and Bilateral Customers: In 2024/Q3, the six (6) international bilateral customers purchasing power from the gridconnected GenCos made a cumulative payment of $6.49 million against the $12.19 million invoice issued to them by the MO for services rendered in 2024/Q3. Similarly, the domestic bilateral customers made a cumulative payment of ₦1,566.51 million against the ₦2,100.79 million invoice issued to them by the MO for services 4 rendered in 2024/Q3 Figure C: DRO adjusted invoices and remittances in 2024/Q3 3 The NBET invoice payable by the DisCos for 2024/Q3 was only ₦382.90 billion because the FGN has taken responsibility for ~55% (₦464.12 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. 4 It is noteworthy that both local and international bilateral customers made payments during 2024/Q3 for freezing of end-use customer tariffs at the rates payable in July 2024. 4 It is noteworthy that both local and international bilateral customers made payments during 2024/Q3 for outstanding MO invoices from previous quarters; the international bilateral customers paid $1.33 million while the domestic bilateral customers paid ₦31.51 million. The details of these payments are contained in Appendix VIII. * * * The Commission issued fifty (50) new Orders in 2024/Q3. Regulatory Functions 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 players and issues Regulations, Guidelines and Orders that guide the operations of licensees, permit holders and registered operators. a. Orders: The Commission issued fifty (50) Orders in 2024/Q3. They include: • NERC/2024/074—NERC/2024/084 — July 2024 Supplementary Order to the Multi-Year Tariff Order (MYTO) for the Distribution Companies. • NERC/2024/086—NERC/2024/096 — Order on Performance Monitoring Framework for the Distribution Companies. • NERC/2024/097 — Revised Order on the Transition Accounting Treatment of Tariff-Related Liabilities in the Financial Records of Market Participants -July 2024. • NERC/2024/058 — Order on the Transition to Bilateral Trading in the NESI. • NERC/2024/002 — Order on the Nomenclature of Generating Plants. • NERC/2024/098—NERC/2024/108 — August 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. • NERC/2024/114—NERC/2024/124 — September 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. * * * • NERC/2024/125 — Transfer of Regulatory Oversight of the Electricity Market in Kogi State from the Nigerian Electricity Regulatory Commission to the Kogi State Electricity Regulatory Commission (KSERC). Fifty (50) licences, permits and certifications were issued by the Commission in 2024/Q3. b. Licences and Permits: The Commission issued fifty (50) licences, permits and certifications in 2024/Q3. They include: • Six (6) new off-grid generation licences with a total nameplate capacity of 30.06MW. • One (1) on-grid generation licence renewal (gross capacity of 39MW). • Two (2) new electricity trading licences. • Eleven (11) captive generation permits with a gross capacity of 63.36MW. • One (1) registration certificate for mini-grid. • Seven (7) certifications for Meter Service Providers and twentytwo (22) permits for Meter Asset Providers. c. Hearings and Public Consultation: The Commission is empowered by 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 5 through hearings . During the quarter (2024/Q3) the Commission conducted five (5) hearings to consider the petitions filed by different stakeholders on issues pertaining to the provision and utilisation of electricity services. 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 being drafted or reviewed. 5 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. xiv \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 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/Q3, the Commission convened two (2) town hall meetings in Gombe and Calabar between18th-20th July 2024 and 8th-10th August 2024 respectively, where issues around service-based tariffs, capping, metering, and customer redress mechanisms were discussed. 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). A total of 184,507 meters were installed in 2024/Q3. b. Metering: A total of 184,507 meters were installed in 2024/Q3, representing an increase of +256.01% compared to the 51,826 meters installed in 2024/Q2. The new installations increased the net end-user metering rate in the NESI by +0.72pp between 2024/Q2 (45.43%) and 2024/Q3 (46.15%). During the quarter, 178,715 meters (96.86% of the total installations) were installed under the MAP framework, 3,508 meters were installed under the Vendor Financed framework and 2,298 meters were installed under the DisCo Financed framework. The metering by the respective DisCos in the quarter under review is presented in Figure D. * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **based on gross energy received by the DisCo and consumption by metered customers on their respective feeders.** **Customer number as at September 2024 Metered customers as at September 2024** **3,000** **2,583** **Average Metering rate as at** **September 2024 46.15%** **2,500** **)** **2,000** **(thousand** **1,500 1,402 1,396** **1,263 1,249** **1,179** **1,115** **1,000 897 956 882 884** **821** **Number of Customers 689** **724** **655** **753** **500 455** **512** **203 254 214 215** **118** **76** **0** **Aba Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano Port Yola** **Harcourt** **Performance 38% 71% 49% 63% 47% 43 % 77% 34% 24% 24% 43% 14%** # Figure D: Status of Customer metering as of September 2024 **c. Customer Complaints: The number of complaints received at the NERC-CCU in 2024/Q3 was 5,287 and 1,647 complaints** **were resolved by DisCos (31.15% resolution rate). The number of complaints received across all DisCo-CCUs was 328,696** **which translates to a +14.35% increase compared to the 287,441 received in 2024/Q2. As in previous quarters,** # metering, billing and service interruption were the prevalent issues of customer complaints during the quarter. ## In 2024/Q3, the ## Forum Offices # d. Forum Offices: Pursuant to the provisions of its Customer ## resolved 58.90% of ## the active appeals in # Protection Regulations 2023 (CPR 2023), the Commission set up ## seventy-seven (77) Forum Offices across the country to review unresolved disputes **sittings.** **from the DisCos’ Complaint Handling Units (DisCos-CCU). The total number of active appeals across the Forum Offices in** **2024/Q3 was 3,202 made up of 2,167 new appeals in 2024/Q3 and 1,035 pending appeals from 2024/Q2. During** **the period, the forum panels held seventy-seven (77) sittings and resolved 1,886 of the appeals filed at Forum Offices nationwide** # (58.90% resolution rate); the resolution rate was +4.00pp higher than the 54.90% achieved in 2024/Q2. **The Commission continues to take measures that will ensure a more efficient customer complaint resolution process starting** ## xvi \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Investigations have been launched into all reported accidents in the NESI. with improvements in the quality of complaint resolution at the DisCo-CCU. To this end, the CPR 2023 contains updates to the customer service standards expected from the DisCos in line with international best practices. e. Health & Safety: The total number of accidents in 2024/Q3 was fifty-six (56) which resulted in twenty-eight (28) injuries and twenty-nine (29) fatalities. The Commission has launched investigations into all the accidents and will continue to work with all sector stakeholders to improve the overall health and safety of the NESI. * * * Key Facts on NESI Performance in Q3 of 2024 | 5,100.90MW | Average Available Generation Capacity;+705.13MW(+16.04%)increase compared to2024/Q2\[4,395.77MW\] | | --- | --- | | 9,450.76GWh | Total Quarterly Generation;+674.21GWh(+7.68%)increase compared to2024/Q2\[8,776.55GWh\] | | 4,280.24MWh/h | Average Hourly Generation;+261.67MWh/h(+6.51%)increase compared to2024/Q2\[4,018.57MWh/h\] | | 83.91% | Load Factor;-7.51pp decrease compared to2024/Q2\[91.42%\] | | 32.60% | Share of total quarterly generation fromHydropower Plants;+5.62pp increase compared to2024/Q2\[26.98%\] | | 3,445.13MWh/h | Total energy received by theDisCos;+279.20MWh/h(+8.81%)increase compared to2024/Q2\[3,165.93MWh/h\] | | 6,249.21GWh | Energy billed to customers;+556.1GWh(+9.76%)increasecompared to2024/Q2\[5,693.11GWh\] | | 4466.69 billion | Total Revenue collected bythe DisCos;+35.53billion(+8.24%)increasecomparedto2024/Q2\[431.16billion\] | | 82.15% | Cumulative billing efficiency acrossall DisCos;-0.19ppdecreasecomparedto2024/Q2\[82.34%\] | | 74.55% | Cumulative collection efficiency acrossall DisCos;-4.76ppdecreasecomparedto2024/Q2\[79.31%\] | | 39.10% | Aggregate Technical,Commercial andCollection Loss;+4.40ppworseATC&Cperformancecomparedto2024/Q2\[34.70%\] | | 441.67 billion | Combined invoicefromNBET(DRO-adjusted)andMO toDisCos;+42.14billion(+10.54%)increasecomparedto2024/Q2\[399.53billion\] | | 370.01 billion | Total amount remittedbyDisCos;+51.36billion(+16.12%)increasecomparedto2024/Q2\[318.65billion\] | * * * | 83.77% | DisCos' overall remittance performance;+4.01pp increase compared to 2024/Q2\[79.76%\] | | --- | --- | | 184,507 | Number of new meters Installed;132,681 more installations(+256.01%)compared to the51,826 meters installed in2024/Q2 | | 328,696 | Total complaints received at the DisCo-CCU;+14.35%increase compared to287,441 complaints received in2024/Q2 | | 58.90% | Forum Office complaint resolution rate;+4.00pp increasecompared to2024/Q2\[54.90%\] | | 29 | Number of fatalities;5 fewer deaths compared to2024/Q2\[34\] | | 28 | Number of injuries;11 more injuries compared to2024/Q2\[17\] | * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 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/Q3 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 • Plant availability factor 2.1.1 Available generation capacity In 2024/Q3, the average available generation capacity of the twenty-eight (28) grid-connected power plants increased by +16.04% (+705.13MW) from the 4,395.77MW recorded in 2024/Q2 to 5,100.90MW; this was driven by the • Quarterly generation • Generation load factor • Generation mix * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **increase in the available capacity of nineteen (19) out of the twenty-eight (28) grid- connected power plants .** **Significant increases in available generation capacity were recorded in Afam\_1 (+182.05%), Omotosho\_1 (+92.36%) and Olorunsogo\_1 (+84.01%) power plants** **in 2024/Q3 compared to 2024/Q2. The cumulative available generation capacity of the NDPHC power plants (Odukpani\_1, Olorunsogo\_2, Omotosho\_2,** **Ihovbor\_1, Geregu\_1, Sapele\_2 & Alaoji\_1) also increased by +24.21% from 499.16MW in 2024/Q2 to 619.98MW in 2024/Q3.** **Similarly, the average available generation capacity of Shiroro\_1, Jebba\_1, Kainji\_1 and Zungeru\_1 hydropower plants increased by +80.45%, +47.26%,** **+24.42% and +11.22% respectively in 2024/Q3 compared to 2024/Q2. However, the average available capacity of Egbin\_1 and Ihovbor\_2 power plants** # decreased by -19.87% and -14.15% respectively over the period (Figure 1). **Variance** **2,500** **2024\_Q2 2024\_Q3** **)** **2,000** **(MW** **1,500** **1,000** **Average Available Capacity 500** **0** **Egbin\_1 Jebba\_1 Zungeru\_1 Shiroro\_1 Ihovbor\_2 Kainji\_1 Delta\_1 Others** **Figure 1: Average Available Capacity (MW) in 2024/Q2 vs. 2024/Q3** # 2.1.2 Plant availability factor **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 **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 II.** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **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 (planned **and unplanned outages); iii) feedstock availability, etc. The formula for the plant availability factor (PAF) is represented by equation 1:** ## average available capacity (MW) ## Plant availability factor × 100 (1) ## installed capacity (MW) # The plant availability factor (PAF) is a critical parameter for evaluating the overall # health of the upstream segment of the NESI. In 2024/Q3, the average plant # availability factor for all grid-connected plants was 37.44%; more than 62% of the **installed capacity across the twenty-eight (28) grid-connected plants was not available for dispatch onto the grid.** # Overall, nine (9) plants had availability factors above 50% with the Dadin-Kowa\_1 # hydropower plant recording the highest availability factor at 89.29%. On the other # end of the spectrum, Alaoji\_1 recorded a PAF of 0% in 2024/Q3. **The PAF of all the grid-connected plants is contained in Table 1. The gross PAF of** # 37.44% recorded in 2024/Q3 represents a +5.14pp change relative to the 32.30% **PAF that was recorded in 2024/Q2. The hydropower plants; Dadin-Kowa\_1 (+73.24pp), Shiroro\_1 (+30.15pp), Jebba\_1 (+24.26pp), Kainji\_1 (+9.66pp) and** # Zungeru\_1 (+5.95pp) recorded increases in PAF in 2024/Q3 compared to # 2024/Q2. The significant increases in the PAF of the hydropower plants are # consistent with the expected impact of seasonality on river flows. The rivers # supplying the hydropower plants experience inflow/flood season between July and # October each year thereby alleviating the feedstock constraints they face during the # earlier part of the year. The PAF of Rivers\_1 (+28.38pp), Omotosho\_1 (+20.95pp) # and Olorunsogo\_1 (+19.94pp) power plants also increased significantly in 2024/Q3 relative to 2024/Q2. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Table 1: Plant Availability Factor (%) in 2024/Q2 vs. 2024/Q3 | \*Plant | Installed capacity(MW) | Average Available Capacity(MW) | | Plant Availability Factor(%) | | | --- | --- | --- | --- | --- | --- | | 2024/Q2 | 2024/Q3 | 2024/Q2 | 2024/Q3 | | | | Dadin-Kowa\_1 | 40 | 6.42 | 35.72 | 16.05 | 89.29 | | Ikeja\_1 | 110 | 92.78 | 97.48 | 84.35 | 88.62 | | Ihovbor\_2 | 461 | 452.00 | 388.03 | 98.05 | 84.17 | | Jebba\_1 | 578 | 296.68 | 436.87 | 52.05 | 75.58 | | Shiroro\_1 | 600 | 224.89 | 405.81 | 37.48 | 67.63 | | Rivers\_1 | 180 | 65.38 | 116.47 | 36.32 | 64.70 | | Okpai\_1 | 480 | 206.98 | 292.09 | 43.12 | 60.85 | | Zungeru\_1 | 700 | 370.96 | 412.58 | 52.99 | 58.94 | | Afam\_21 | 650 | 275.72 | 330.61 | 42.42 | 50.86 | | Kainji\_1 | 760 | 300.65 | 374.06 | 39.56 | 49.22 | | Olorunsogo\_1 | 335 | 79.53 | 146.35 | 26.16 | 43.68 | | Omotosho\_1 | 335 | 75.97 | 146.14 | 24.99 | 43.62 | | Geregu\_2 | 435 | 183.26 | 185.53 | 42.13 | 42.65 | | Odukpani\_1 | 625 | 300.96 | 265.81 | 47.73 | 42.53 | | Delta\_1 | 900 | 347.33 | 366.12 | 38.59 | 40.68 | | Egbin\_1 | 1,320 | 659.27 | 528.27 | 49.94 | 40.02 | | Omoku\_1 | 150 | 46.14 | 54.30 | 30.76 | 36.20 | | Geregu\_1 | 435 | 150.42 | 141.24 | 34.58 | 32.47 | | Igbafo\_1 | 45 | 18.78 | 16.36 | 31.30 | 36.36 | | Ibom Power\_1 | 190 | 91.67 | 51.47 | 47.99 | 27.09 | | Olorunsogo\_2 | 750 | 14.28 | 92.99 | 1.90 | 12.40 | | Sapele Steam\_1 | 720 | 97.08 | 81.85 | 13.48 | 11.37 | | Ihovbor\_1 | 500 | 0.13 | 44.57 | 0.03 | 8.91 | | Afam\_1 | 726 | 19.19 | 54.12 | 2.64 | 7.45 | | Trans Amadi\_1 | 100 | 18.78 | 4.98 | 18.78 | 4.98 | | Sapele\_2 | 500 | 0.24 | 22.63 | 0.05 | 4.53 | | Omotosho\_2 | 500 | 0.11 | 8.44 | 0.02 | 1.69 | | Alaoji\_1 | 500 | 0.18 | 0.00 | 0.04 | 0.00 | | Total | 13,625.00 | 4,395.77 | 5,100.90 | 32.30 | 37.44 | \*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 * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS **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** # The average hourly generation on the grid in 2024/Q3 was 4,280.24MWh/h, # which translates to a total generation of 9,450.76GWh (equation 2). ## Total generation Ave. hourly generation (MWh/h)×24hrs× number of days in the quarter (2) # The hourly generation increased by +6.51% while the total generation of the grid- **7** **connected power plants increased by +7.68% respectively in 2024/Q3 compared to 2024/Q2; the hourly generation increased from 4,018.57MWh/h recorded in** **2024/Q2 to 4,280.24MWh/h in 2024/Q3 (+261.67MWh/h) while the total generation increased from 8,776.55GWh generated in 2024/Q2 to 9,450.76GWh** # in 2024/Q3 (+674.21GWh). The significant increase in generation is attributable # to the increase in the available capacity of many power plants during the quarter. **The most significant increases in average hourly generation were recorded in Dadin- Kowa\_1 (+461.20%), Olorunsogo\_2 (+249.48%), Afam\_1 (+195.40%),** **Olorunsogo\_1 (+85.28%), Omotosho\_1 (+69.27%), Igbafo\_1 (+67.29%), and Shiroro\_1 (+50.02%) power plants. The average hourly generation of Jebba\_1** **(+38.56%), Afam\_2 (+22.98%), Kainji\_1 (+21.86%), Zungeru\_1 (+6.35%) and Delta\_1 (+1.65%) power plants also increased in 2024/Q3 compared to 2024/Q2** **(Figure 2). Conversely, the average hourly generation of Egbin\_1 (-26.32%), and Ihovbor\_2 (-17.75%) decreased in 2024/Q3 compared to 2024/Q2.** **7** **The percentage change in total generation and average hourly generation is different across 2024/Q3 vs** **2024/Q2 because the number of days in each of the quarters is different (91/92 days). When the number of** **days is the same across the quarters being compared, the net change in total generation and average hourly** **generation will be the same.** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * THIRD QUARTER 2024 Figure 2: Average Hourly Generation (MWh/h) in 2024/Q2 vs. 2024/Q3 Cumulatively, the average hourly generation of the five grid-connected hydropower plants increased by +28.71% (+311.25MWh/h) in 2024/Q3 compared to 2024/Q2. This is a result of the increased feedstock explained earlier and the merit order dispatch implemented by the System Operator (SO); hydropower plants rank high in the merit order because of their relatively lower cost and the need to utilise the water in their reservoir to prevent flooding downstream of the hydro dams. Conversely, the cumulative average hourly generation from thermal plants during the quarter decreased by -1.69% (-49.58MWh/h) compared to 2024/Q2, with nine (9) out of the twenty-three (23) thermal plants recording decreases in their average hourly generation (Table 2). The average hourly generation from Trans Amadi\_1, Sapele Steam\_1, Ibom Power\_1, Geregu\_2, and Egbin\_1 dropped by -67.68%, -41.31%, -30.94%, - 35.42%, and -26.32% respectively between 2024/Q2 and 2024/Q3. These reductions were driven by a combination of gas constraints, mechanical faults and increased generation from hydropower plants based on the merit order dispatch (leading to a displacement of generation from thermal plants). * * * Table 2: Average Hourly Generation (MWh/h) in 2024/Q2 vs. 2024/Q3 | Plant | Average Hourly Generation (MWh/h) | | Change (MWh/h) | Change(%) | | --- | --- | --- | --- | --- | | 2024/Q2 | 2024/Q3 | | | | | Dadin-Kowa\_1 | 6.26 | 35.13 | 28.87 | 461.20 | | Olorunsogo\_2 | 14.54 | 50.81 | 36.27 | 249.48 | | Afam\_1 | 16.91 | 49.95 | 33.04 | 195.40 | | Olorunsogo\_1 | 77.39 | 143.39 | 66.00 | 85.28 | | Omotosho\_1 | 77.02 | 130.37 | 53.35 | 69.27 | | Igbafo\_1 | 10.56 | 17.66 | 7.11 | 67.29 | | Shiroro\_1 | 197.87 | 296.85 | 98.98 | 50.02 | | Okpai\_1 | 172.97 | 250.41 | 77.44 | 44.77 | | Jebba\_1 | 258.93 | 358.78 | 99.86 | 38.56 | | Rivers\_1 | 54.59 | 75.25 | 20.65 | 37.83 | | Afam\_2 | 265.96 | 327.09 | 61.13 | 22.98 | | Kainji\_1 | 284.49 | 346.67 | 62.19 | 21.86 | | Omoku\_1 | 55.83 | 62.87 | 7.04 | 12.61 | | Zungeru\_1 | 336.56 | 357.92 | 21.36 | 6.35 | | Delta\_1 | 335.55 | 341.09 | 5.54 | 1.65 | | Sapele\_2 | 0.00 | 12.02 | 12.02 | 0.00 | | Alaoji\_1 | 0.00 | 0.00 | 0.00 | 0.00 | | Omotosho\_2 | 0.00 | 1.66 | 1.66 | 0.00 | | Ihovbor\_1 | 0.00 | 24.56 | 24.56 | 0.00 | | Ikeja\_1 | 86.57 | 86.38 | -0.19 | -0.22 | | Geregu\_1 | 143.08 | 120.12 | -22.96 | -16.05 | | Ihovbor\_2 | 398.65 | 327.88 | -70.78 | -17.75 | | Egbin\_1 | 621.66 | 458.06 | -163.60 | -26.32 | | Odukpani\_1 | 276.98 | 203.75 | -73.24 | -26.44 | | Ibom Power\_1 | 63.57 | 43.90 | -19.67 | -30.94 | | Geregu\_2 | 156.98 | 101.38 | -55.60 | -35.42 | | Sapele Steam\_1 | 83.97 | 49.28 | -34.69 | -41.31 | | Trans Amadi\_1 | 21.69 | 7.01 | -14.68 | -67.68 | | Total | 4,018.57 | 4,280.24 | 261.67 | 6.51 | 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: 8 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD 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/Q3 was # 83.91%; meaning that on average, 16.09% of available energy (MWh) was not # dispatched during the quarter. The load factor in 2024/Q3 (83.91%) is a -7.51pp # decrease compared to the 91.42% load factor recorded in 2024/Q2. The decrease # in load factor during the period indicates a decrease in the utilisation of available # capacity which is to be expected considering that the rate of increase in average **hourly generation was lower than the rate of increase of available generation between 2024/Q2 and 2024/Q3.** # The load factors of the seven (7) power plants with the highest dispatch rates in # 2024/Q3 are presented in Figure 3. Three (3) power plants (Trans Amadi\_1, # Omoku\_1, and Igbafo\_1) recorded dispatch rates of 100% while six (6) other **power plants recorded dispatch rates above 90%. Dadin-Kowa\_1 (98.36%) and Kainji\_1 (92.68%) hydropower plants recorded dispatch rates >90% while** **Shiroro\_1 (73.15%), Jebba\_1 (82.13%) and Zungeru\_1 (86.75%) hydropower plants recorded dispatch rates <90% which is inconsistent with the Commission’s** **8** # Order No: NERC/182/2019 . The Commission is conducting further investigations # to determine if sanctions should be issued against relevant market participants. **As explained above, 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** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * THIRD QUARTER 2024 Figure 3: Load Factor (%) in 2024/Q2 vs. 2024/Q3 2.1.5 Generation mix The electricity generation mix refers to the combination of fuels used to generate electricity over a period. The composition of the 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 2 3 elements of the energy trilemma: i) Energy Security ; ii) Energy Sustainability ; and 4 iii) Energy Affordability/Equity . The formula for the share of electricity generated by fuel source is given by equation 4: \\mathsf{S h a r e\ o f\ f t u e l:=\\frac{\\mathsf{T o u l l\ e l e c t r i c y\ g e n e r a t e d\ f r o m\ f u e l i\ (G\\mathsf{W W h}})}{\\mathsf{T o t t l\ e l l e c t i i i t\ g e n e r a t e d\ f r o m\ o l l\ f u e l\ s o u r e e s\ (G W h)}}\\times\ 100\ \ \ (4)} The share of electricity generated from different fuel sources in 2024/Q2 and 2024/Q3 are presented in Figure 4. The total generation from hydropower plants (3,080.94GWh) increased by +30.12% (+713.26GWh) in 2024/Q3 compared to 2024/Q2 (2,367.68GWh). This translated to a +5.62pp increase in the contribution of hydropower to the energy mix over the same period; 26.98% (2,367.68GWh out of 8,776.55GWh) in 2024/Q2 to 32.60% (3,080.94GWh out of 9,450.76GWh) in 2024/Q3. The increase in the contribution of hydropower plants × 100 (4) * * * to total generation during the quarter can be attributed to the increase in the available capacities of the hydropower plants reported in section 2.1.1. Figure 4: Electricity Generated by Energy Sources (%) in 2024/Q2 vs. 2024/Q3 2.2 Grid Performance The Transmission Company of Nigeria (TCN) which has the responsibility of transporting energy from power plants to DisCos holds two licenses; 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 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: \\mathsf{T I 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 E x o r r e d}}{\\mathsf{E n e r g y\ S e n t\ u u l\ b y\ a l l\ G e n C o s}}\\right)right\ \\times100 ×100 (5) The average TLF in 2024/Q3 was 9.04% (Figure 5). A TLF of 9.04% indicates that for every 100MWh of energy injected into the grid, 9.04MWh of energy is undelivered to DisCos and international customers due to losses in the transmission network or consumption at the transmission substations. The TLF recorded in 2024/Q3 represents an increase of +1.25pp (decline in performance) relative to the 7.79% recorded in 2024/Q2. The 9.04% TLF recorded in 2024/Q3 represents an underperformance of 2.04pp 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 revenues needed to cover the excess (inefficient) losses. * * * Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) Apr-Sep 2024 2.2.2 Grid frequency Frequency is a crucial power quality parameter that industrial customers are particularly concerned about due to the sensitivity of their heavy-duty machinery. In industrial production assembly lines, the machines are designed to operate only within pre-set frequency limits and therefore often have a low tolerance for frequency fluctuations. 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. * * * of 1.19Hz. Comparatively, in 2024/Q2 the average upper daily system frequency was 50.64Hz, while the average lower daily system frequency was 49.13Hz, which translates to a range of 1.51Hz. The –21.19% (-0.32Hz) decrease in the average quarterly frequency range recorded in 2024/Q3 relative to 2024/Q2 indicates a relatively significant improvement in the operational performance of the National Grid. Figure 6: Monthly System Frequency (Hz) from April – September 2024 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 realtime 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. * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 2.2.3 Voltage fluctuation # To guarantee the quality of electricity delivered to end users, the Grid Code specifies # a nominal system voltage of 330kV with a tolerance range of ±5% (313.50kV to # 346.50kV in the lower and upper bounds respectively). Fluctuations in grid voltage, # including spikes, dips, flickers, and brownouts, can cause significant harm to # 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 April-September 2024 is illustrated in Figure 7. # The average upper and lower operating voltage bounds for the transmission # network in 2024/Q3 were 352.68kV and 299.64kV respectively; both values are # outside the respective allowable limits specified in the Grid Code. # By way of comparison, the range between the Grid’s average upper and lower # operating voltage for 2024/Q3 was 53.04kV which is higher than the 50.77kV # (average upper and lower voltages of 355.13kV and 304.36kV respectively) that was recorded in 2024/Q2. # 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. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Figure 7: Monthly System Voltage (kV) from April - September 2024 2.2.4 System collapse 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 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. 1300k V\\pm5.0%) 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. 150H z\\pm0.5% * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS | | | | Table 3: System Collapse in 2024/Q3 | | --- | --- | --- | --- | | SN | Type | Date | Cause | | 1 | Partial collapse during system disturbances. allows it operate as | 06 July 2024 dynamic islands is a fault without triggering a full collapse of the national grid. | The tripping of circuit breakers at Egbin\_1 and Jebba\_1 power stations led to the loss of units ST4 & 6 (at Egbin\_1) and 2G2,1 & 3 (at Jebba\_1) respectively. This caused a drastic drop in the system frequency thereby 9 triggering the collapse of Island 2 . A grid island is a segment of the power system, usually including certain key power plants, that can operate in isolation from the main grid to stabilise local supply Arising from the robustness of Island 1 i.e., Ibom Power\_1, the Commission has mandated the SO to evaluate options for operating the national grid in a way that when needed i.e., interconnected during normal operations but with the ability for every segment to island itself when there | | 9 | | Island 2 consists of all generating plants except Ibom Power\_1 | | ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### THIRD 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/Q3, the following parameters were 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 PCCs10 ## – “Available PCC”. The ratio between a DisCo’s energy offtake and the available **10** **Commencing 2023/Q3, the Commission developed a mechanism whereby Abuja, Eko and Ikeja DisCos get** **their full allocation provided that generation is above 4,100MW which is the minimum grid stability requirement;** **the rest of the capacity is pro-rated based on PCC for the remaining DisCos. When available generation is below** **4,100MW, generation allocation to all the DisCos is pro-rated based on PCC.** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * PCC is known as the “energy offtake performance”. The formula for determining a DisCo’s energy offtake performance is represented by equation 6: \\mathsf{E n e r g y\ O O f l o k e\ p e r f o r m a n c e\ (\ 0%})\\quad=\\quad\\quad(\\begin matrix}{matrix{\\mathsf{E n e r g y\ O O f i a k e}}\ {\\mathsf{A v v i l i b b e\ P C C}}\\end{array})\ times000 ×100 (6) Considering the large disparity between 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., high commercial and collection losses in certain areas. 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 unused 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 offtaken) from customers. In 2024/Q3, the average energy offtake by DisCos at their trading points was 3,445.13MWh/h, which represents an increase of +8.81% (+279.20MWh/h) when compared to 3,165.93MWh/h off-take in 2024/Q2. The increase in the average energy offtake at trading points was due to the increase in energy available for offtake (PCC) which was a result of the increase in generation during the quarter explained in section 2.1.3. The cumulative energy offtake performance of DisCos during the quarter was 90.47%. Only Enugu (98.65%), Benin (98.01%) and Port Harcourt (95.11%) DisCos took >95% of their available PCC during the quarter. All the other DisCos took <95% of available PCC with Yola DisCo (74.61%) recording the worst offtake performance (Table 4). 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 on the DisCos that did not meet the minimum offtake requirement for 2024/Q3. * * * Table 4: DisCo energy offtake performance in 2024/Q2 vs. 2024/Q3 | DisCos | 2024/Q2 | | | 2024/Q3 | | | | --- | --- | --- | --- | --- | --- | --- | | Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance(%) | Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance(%) | | | Abuja | 498.63 | 509.26 | 97.91 | 509.40 | 588.74 | 86.52 | | Benin | 257.81 | 254.79 | 101.19 | 314.46 | 320.83 | 98.01 | | Eko | 431.32 | 439.35 | 98.17 | 445.31 | 491.07 | 90.68 | | Enugu | 225.27 | 235.48 | 95.66 | 288.14 | 292.08 | 98.65 | | Ibadan | 373.68 | 364.16 | 102.61 | 434.05 | 458.33 | 94.70 | | Ikeja | 520.53 | 516.06 | 100.87 | 512.08 | 571.77 | 89.56 | | Jos | 152.33 | 172.91 | 88.10 | 194.26 | 220.44 | 88.12 | | Kaduna | 202.69 | 201.31 | 100.69 | 202.16 | 246.62 | 81.97 | | Kano | 203.45 | 202.48 | 100.48 | 215.57 | 249.50 | 86.40 | | PH | 243.24 | 230.48 | 105.54 | 253.81 | 266.86 | 95.11 | | Yola | 56.99 | 62.16 | 91.68 | 75.89 | 101.72 | 74.61 | | All DisCos | 3,165.93 | 3,188.59 | 99.29 | 3,445.13 | 3,807.98 | 90.47 | 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; 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 total energy offtake by all DisCos in 2024/Q3 was 7,606.84GWh and the total energy billed was 6,249.21GWh, which translates to a billing efficiency of 82.15%. A billing efficiency of 82.15% implies that for every ₦100 worth of energy received by DisCos in 2024/Q3, ₦17.85 was not billed to end users. Comparatively, the total energy received and billed in 2024/Q2 were 6,914.39GWh and 5,693.11GWh respectively, which translated to a billing efficiency of 82.34%. This means that at an aggregate level, DisCos recorded a -0.19pp decrease in billing efficiency between 2024/Q2 and 2024/Q3. ×100 (7) * * * Disaggregated performance of the DisCos shows that Ibadan DisCo recorded the highest billing efficiency of 89.98% while Jos recorded the lowest billing efficiency of 62.66%. A quarter-on-quarter comparison of billing efficiency shows that seven (7) DisCos recorded improvements in their billing efficiencies in 2024/Q3 relative to 2024/Q2 with Kano and Abuja recording the most significant increases of +12.75pp and +4.32pp respectively. Conversely, four (4) DisCos recorded decreases in billing efficiency with Enugu DisCo (-20.35pp) recording the most significant decrease (Table 5). Table 5: Energy received and billing efficiency by DisCos in 2024/Q2 vs. 2024/Q3 | DisCos | 2024/Q2 | | | 2024/Q3 | | | | --- | --- | --- | --- | --- | --- | --- | | Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) | Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) | | | Abuja | 1,089.00 | 835.00 | 76.68 | 1,124.76 | 911.00 | 81.00 | | Benin | 563.05 | 469.29 | 83.35 | 694.32 | 585.07 | 84.27 | | Eko | 942.00 | 845.00 | 89.70 | 983.24 | 878.00 | 89.30 | | Enugu | 492.00 | 469.00 | 95.33 | 636.21 | 477.00 | 74.98 | | Ibadan | 816.11 | 724.29 | 88.75 | 958.37 | 862.31 | 89.98 | | Ikeja | 1,136.83 | 937.49 | 82.47 | 1,130.67 | 952.53 | 84.24 | | Jos | 332.68 | 242.05 | 72.76 | 428.92 | 268.78 | 62.66 | | Kaduna | 442.67 | 279.20 | 63.07 | 446.37 | 285.73 | 64.01 | | Kano | 444.34 | 331.59 | 74.63 | 475.98 | 415.89 | 87.38 | | Port Harcourt | 531.25 | 444.02 | 83.58 | 560.41 | 469.26 | 83.74 | | Yola | 124.46 | 116.17 | 93.34 | 167.57 | 143.65 | 85.73 | | All DisCos | 6,914.39 | 5,693.11 | 82.34 | 7,606.84 | 6,249.21 | 82.15 | 2.3.3 Revenue and collection efficiency 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 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 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: \ \ {\\sf C o l l e c t i o n\ E E f f c c i n n c y}}&{,,,,,,,,,,,,,,{\\sf T o l a l\ B e l i n e d\ A m o u n t\ (\ \ H)},\\times100 ×100 (8) The total revenue collected by all DisCos in 2024/Q3 was ₦466.69 billion out of the ₦626.02 billion that was billed to customers. This translates to a collection efficiency of 74.55%. In comparison, the total revenue collected by all DisCos in 2024/Q2 was ₦431.16 billion out of the ₦543.64 billion billed to customers which translated to a 79.31% collection efficiency. The 74.55% collection efficiency recorded in 2024/Q3 is -4.76pp lower than the collection efficiency recorded in 2024/Q2 (79.31%). The summary of the revenue collection performance of all DisCos is contained in Table 6. Eko and Ikeja DisCos recorded the highest collection efficiencies of 84.40% and 83.78% respectively. Conversely, Kaduna DisCo recorded the lowest collection efficiency at 46.42%. A comparison of DisCos performance shows that only Ibadan (+6.59pp) and Enugu (+2.88pp) DisCos recorded improvements in collection efficiency in 2024/Q3 when compared to 2024/Q2. Conversely, the remaining nine (9) DisCos recorded declines in collection efficiency with Kaduna (-14.20pp) and Jos (-12.09pp) DisCos having the most significant declines over the period. Table 6: Revenue Collection Performance (%) of DisCos in 2024/Q2 vs. 2024/Q3 | DisCos | 2024/Q2 | | | 2024/Q3 | | | | --- | --- | --- | --- | --- | --- | --- | | Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) | Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) | | | Abuja | 84.49 | 70.19 | 83.07 | 99.26 | 78.28 | 78.87 | | Benin | 41.24 | 33.96 | 82.35 | 50.77 | 41.09 | 80.94 | | Eko | 85.46 | 75.23 | 88.03 | 103.11 | 87.02 | 84.40 | | Enugu | 40.88 | 30.39 | 74.35 | 46.71 | 36.07 | 77.23 | | Ibadan | 63.01 | 44.27 | 70.25 | 74.96 | 57.60 | 76.84 | | Ikeja | 92.28 | 87.36 | 94.67 | 99.73 | 83.55 | 83.78 | | Jos | 24.07 | 15.74 | 65.37 | 30.73 | 16.37 | 53.29 | | Kaduna | 24.25 | 14.71 | 60.62 | 24.57 | 11.40 | 46.42 | | Kano | 37.33 | 21.92 | 58.71 | 43.89 | 20.64 | 47.03 | | Port Harcourt | 42.02 | 32.61 | 77.59 | 41.31 | 29.22 | 70.76 | | Yola | 8.63 | 4.78 | 55.67 | 10.98 | 5.41 | 49.31 | | All DisCos | 543.64 | 431.16 | 79.31 | 626.02 | 466.69 | 74.55 | * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # In 2024/Q3, there were decreases in billing (-0.19pp) and collection (-4.76pp) # efficiencies compared to efficiencies recorded in 2024/Q2. Based on historical # trends, it can be deduced that these decreases are partially driven by the increase # in energy offtake by the DisCos between 2024/Q2 and 2024/Q3. This is because # it has been observed when there is a higher energy offtake, DisCos often allocate # the incremental energy to areas where they record higher 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 24th # 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. DisCos are also expected to continue to utilise one or more metering # frameworks provided for in the NERC MAP and NMMP metering regulation (2021) # to improve end-use customer metering in their franchise area. 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 discrepancy in meter reading, erroneous billing, unmetered consumption, or energy theft;** # c. Collection Loss: unpaid bills. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # The formula for ATC&C loss is represented by equation 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/Q3 was # 39.10%, which comprised 18.32% in technical and commercial losses, and 25.45% # in collection loss (Table 7.) The aggregate ATC&C loss of 39.10% recorded in # 2024/Q3 is 14.37pp higher than the allowed aggregate efficient loss target # (24.73%) applied in the computation of the tariffs in the MYTO. This means that **cumulatively, DisCos recorded losses that are 58.12% higher than what was allowed to be recovered from the customers.** # No DisCo achieved its target ATC&C in 2024/Q3 with the widest variance (target # – actual) being recorded by Kaduna (-45.84pp), Kano (-34.82pp) and Jos (- # 34.09pp) DisCos. The excess ATC&C losses (inefficiencies) are not recoverable from # customers and may compromise the long-term financial positions of the affected DisCos. # The average ATC&C loss recorded in 2024/Q3 (39.10%) was +4.40pp greater # (worse performance) than what was recorded in 2024/Q2 (34.70%). Only Ibadan **(-6.79pp) and Abuja (-0.17pp) DisCos recorded improvements in ATC&C loss performance in 2024/Q3 compared to 2024/Q2. Conversely, all the remaining** # nine (9) DisCos recorded declines in their ATC&C loss performances across # 2024/Q3 and 2024/Q2 with Jos DisCo (+14.37pp) recording the worst decline (Table 7). ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Table 7: ATC&C Loss (%) by DisCos in 2024/Q2 vs. 2024/Q3 | DisCo | MYTO Target(%)2024 | ATC&C(%) | | Variance(pp) | | | --- | --- | --- | --- | --- | --- | | 2024/Q2 | 2024/Q3 | 2024/Q2 | 2024/Q3 | | | | Abuja | 25.00 | 36.30 | 36.13 | -11.30 | -11.13 | | Benin | 25.00 | 31.36 | 31.80 | -6.36 | -6.80 | | Eko | 20.07 | 21.03 | 24.62 | -0.96 | -4.55 | | Enugu | 25.00 | 29.12 | 42.89 | -4.12 | -17.89 | | Ibadan | 25.00 | 37.66 | 30.86 | -12.66 | -5.86 | | Ikeja | 18.73 | 21.93 | 29.78 | -3.20 | -11.05 | | Jos | 32.72 | 52.44 | 66.81 | -19.72 | -34.09 | | Kaduna | 25.00 | 61.76 | 70.84 | -36.76 | -45.84 | | Kano | 25.00 | 56.19 | 59.82 | -31.19 | -34.82 | | Port Harcourt | 25.00 | 35.15 | 41.70 | -10.15 | -16.70 | | Yola | 56.00 | 48.04 | 57.05 | 7.96 | -1.05 | | All DisCosMYTO Level | 24.73 | | | | | | Total Technical, Commercial &Collection losses | - | 34.70 | 39.10 | | | | Technical & Commercial losses | - | 17.66 | 18.32 | | | | Collection losses | - | 20.83 | 25.45 | | | 2.3.5 Market Remittance Under the account administration mechanism set up by the CBN in 2013 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. * * * 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 11 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 12 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. Thus, the portion of GenCo invoices not covered by DRO 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/Q3 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 13 obligation of ₦464.12 billion (54.71% of total NBET invoice) in 2024/Q3. Between 2024/Q2 and 2024/Q3, the subsidy obligation of the government increased by +₦84.06 billion, from ₦380.06 billion (52.51% of total GenCo invoice) to ₦464.12 billion (54.71% of 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. Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q3 | DisCos | Total NBET Invoice(N\*billion) | Final Obligation(N\*billion) | | --- | --- | --- | | Abuja | 127.51 | 63.08 | | Benin | 74.51 | 34.17 | | Eko | 109.43 | 59.23 | | Enugu | 69.11 | 30.60 | | Ibadan | 104.23 | 47.10 | 11 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. 12 For the MRO framework, DisCos are invoiced 100% of energy cost but only expected to pay MRO share of 12 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 13 Monthly subsidy obligation during the quarter; Jul - ₦150 billion, Aug - ₦142 billion and Sep - ₦172 billion 13 Monthly subsidy obligation during the quarter; Jul - ₦150 billion, Aug - ₦142 billion and Sep - ₦172 billion 26 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * THIRD QUARTER 2024 | DisCos | Total NBET Invoice(N'billion) | Final Obligation(N'billion) | | --- | --- | --- | | Ikeja | 126.08 | 67.43 | | Jos | 48.36 | 14.92 | | Kaduna | 51.98 | 17.90 | | Kano | 54.96 | 20.06 | | Port Harcourt | 60.83 | 26.58 | | Yola | 20.81 | 1.82 | | All DisCos | 847.02 | 382.90 | In 2024/Q3, the DRO-adjusted invoice from NBET to the DisCos was ₦382.90 14 billion while the total remittance made was ₦324.83 billion, which translates to 84.66% remittance performance. Comparatively, in 2024/Q2, the DRO-adjusted invoice from NBET to DisCos was ₦343.76 billion and the total remittance was ₦271.87 billion, which translated to a 79.09% remittance performance. The +5.57pp increase in remittance performance of DisCos to NBET in 2024/Q3 compared to 2024/Q2 is attributable to the larger increase in remittance (+19.45%) during the quarter relative to the increase in DRO-adjusted invoice (+11.38%) from NBET. Disaggregated remittance performance of the DisCos to NBET in 2024/Q3 shows 15 that Eko (100%), Yola (95%) and Ikeja (94%) DisCos recorded the highest performances. Kaduna and Kano DisCos recorded the lowest remittance performances of 30.23% and 66.73% respectively (Figure 8). A quarter-on-quarter analysis showed that seven (7) DisCos recorded improvements in remittance performance to NBET in 2024/Q3 compared to 2024/Q2. Conversely, Yola (- 15.47pp), Port Harcourt (-5.44pp), Kano (-3.24pp) and Jos (-1.21pp) DisCos recorded declines in their remittance performance to NBET. 14 Total NBET invoice for 2024/Q3 without adjustment for DRO (total bill issued by GenCos) is ₦847.02 billion 15 Ikeja DisCo; ₦2.00 billion out of 2024/Q3 invoices was paid from October 2024 collections 15 Ikeja DisCo; ₦2.00 billion out of 2024/Q3 invoices was paid from October 2024 collections 27 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### THIRD QUARTER 2024 NERC QUARTERLY REPORTS **NBET Invoice NBET Remittances** **)** **Billion** ₦ **(** **Remittances** **82 73** **1\. 1.** **Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano P/Harcourt Yola** **Performance 90% 84% 100% 81% 88% 94% 65% 30% 67% 76% 95%** **Figure 8: DisCos Remittance Performances to NBET in 2024/Q3** # 2.4.5.2 Market Remittance to MO ## The Market Operator issues invoices to DisCos for energy transmission and ## administrative services. In 2024/Q3, DisCos made a total remittance of ₦45.18 ## billion against the cumulative invoice of ₦58.77 billion issued by the MO. This ## payment translates to 76.88% remittance performance and is a -7.00pp decrease ## when compared to 83.88% remittance performance recorded in 2024/Q2 when ## DisCos remitted ₦46.78 billion out of ₦55.77 billion invoice issued by the MO. ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * THIRD QUARTER 2024 Figure 9: DisCos Remittance Performances to MO in 2024/Q3 Disaggregated remittance performance of the DisCos to MO shows that Ikeja, Abuja and Yola DisCos recorded the highest remittance performances of 94.80%, 87.42%, and 86.34% respectively while Kaduna had the lowest remittance performance of 16.94% (Figure 9). Between 2024/Q2 and 2024/Q3, ten (10) DisCos recorded declines in MO remittance performance with Yola (-63.66pp), Port Harcourt (-20.01pp), and Kano (-16.05pp) recording the most significant reductions. 2.4.5.3 Market Remittance to NBET and MO The cumulative DisCos’ remittance to NBET and MO in 2024/Q3 is presented in Table 9. * * * Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q3 | DisCos | DRO Adjusted Invoice(N' Billion) | | | Actual Remittance(N' Billion) | | | RemittancePerformance(%) | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | NBET | MO | NBET+MO | NBET | MO | NBET+MO | 2024/Q2 | 2024/Q3 | | | Abuja | 63.08 | 9.42 | 72.50 | 56.69 | 8.24 | 64.93 | 84.49 | 89.56 | | Benin | 34.17 | 5.01 | 39.18 | 28.72 | 4.03 | 32.75 | 80.61 | 83.59 | | Eko | 59.23 | 7.18 | 66.41 | 59.43 | 6.02 | 65.45 | 98.45 | 98.55 | | Enugu | 30.60 | 4.29 | 34.89 | 24.93 | 3.38 | 28.31 | 79.51 | 81.14 | | Ibadan | 47.10 | 7.23 | 54.33 | 41.42 | 6.21 | 47.63 | 77.52 | 87.67 | | Ikeja | 67.43 | 8.83 | 76.26 | 63.33 | 8.36 | 71.70 | 80.59 | 93.89 | | Jos | 14.92 | 3.63 | 18.55 | 9.67 | 2.04 | 11.71 | 65.34 | 63.13 | | Kaduna | 17.90 | 3.99 | 21.89 | 5.41 | 0.68 | 6.09 | 28.01 | 27.82 | | Kano | 20.06 | 3.68 | 23.74 | 13.39 | 2.05 | 15.44 | 70.24 | 65.04 | | P/Harcourt | 26.58 | 4.01 | 30.59 | 20.10 | 2.87 | 22.97 | 82.63 | 75.09 | | Yola | 1.82 | 1.50 | 3.32 | 1.73 | 1.30 | 3.03 | 131.89 | 91.27 | | All DisCos | 382.90 | 58.77 | 441.67 | 324.83 | 45.18 | 370.01 | 79.76 | 83.77 | 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/Q3 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 $6.49 million against the cumulative invoice of $12.19 million issued by the MO for services rendered in 2024/Q3, translating to a remittance performance of 53.24% (Table 10). The domestic bilateral customers made a cumulative payment of ₦1,566.51 million against the invoice of ₦2,100.79 million issued to them by the MO for services rendered in 2024/Q3 translating to 74.57% remittance performance (Table 10). The special customer (Ajaokuta Steel Co. Ltd and the host community) did not make any payment towards the ₦1.26 billion (NBET) and ₦0.11 billion (MO) invoices received in 2024/Q3. This continues a longstanding trend of non-payment by this customer and the Commission has communicated the need for intervention on this It is however noteworthy that some bilateral customers (both domestic and international customers) made payments during 2024/Q3 for outstanding MO invoices from previous quarters. Odukpani-CEET made a payment of $1.33 million towards outstanding invoices from previous quarters. Similarly, the MO received ₦31.51 million from the domestic bilateral customers (North-South/Star Pipe; ₦9.50 million and Trans-Amadi (OAU/FMPI); ₦22.01 million) towards outstanding invoices from previous quarters. The details of these payments are contained in Appendix VIII. * * * issue to the relevant FGN authorities. A continuation of the non-payment could trigger total disconnection from the grid. Table 10: Invoices and Remittances of Other Customers in 2024/Q3 | | NBET | | | MO | | | | --- | --- | --- | --- | --- | --- | --- | | Invoice(Million)2024/Q3 | Remittance(Million)2024/Q3 | Performance(%)2024/Q3 | Invoice(Million)2024/Q3 | Remittance(Million)2024/Q3 | Performance(%)2024/Q3 | | | International BilateralCustomers | | | | | | | | PARAS-SBEE($) | - | - | - | 2.79 | 1.89 | 67.87 | | PARAS-CEEIT($) | | | | 0.98 | 0.98 | 100.00 | | TRANSCORP-SBEE($)UGHELLI | - | - | - | 0.82 | 0.45 | 54.88 | | TRANSCORP-SBEE($)AFAM3 | | | | 1.39 | 0.85 | 61.21 | | MAINSTREAM-NIGELEC($) | - | - | - | 3.44 | 2.32 | 67.44 | | ODUKPANI-CEEIT($) | - | - | - | 2.77 | 0.00 | 0.00 | | Total | - | - | - | 12.19 | 6.49 | 53.24 | | Local Bilateral Customers | | | | | | | | MSTM/INNER GALAXY(N) | | | | | | | | MSTM/KAM IND.(N) | | | | | | | | MSTM/KAM INT.(N) | - | - | - | 1,278.78 | 1,278.78 | 100.00 | | MAINSTREAM/PRISM(N) | | | | | | | | MSTM ZEBERCED(N) | | | | | | | | MSTM/ADFV(N) | | | | | | | | NDPHC/WEEWOOD(N) | - | - | - | 74.89 | 21.06 | 28.13 | | NORTH SOUTH/STAR P(N) | - | - | - | 32.98 | 22.16 | 67.19 | | TRANS AMADI(OAU)(N) | - | - | - | 28.32 | 11.47 | 40.50 | | TRANS AMADI(FMPI)(N) | - | - | - | 40.35 | 0.00 | 0.00 | | NDPHC/SUNFLAG(N) | - | - | - | 438.82 | 150.00 | 34.18 | | OMOTOSHO II/PULKIT(N) | - | - | - | 158.14 | 83.04 | 52.49 | | ALAOJI GENCO/APLE(N) | - | - | - | 48.51 | 0.00 | 0.00 | | TAOPEX/KAM INT(N) | - | - | - | 1,100.79 | 1,566.51 | 74.57 | | SAPELE/PHOENIX | - | - | - | 112.43 | 0 | 0 | | Total | - | - | - | | | | | Special CustomerAJAOKUTA STEEL(N) | 1,262.65 | 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 * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * #### THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 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.** - **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.** #### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 3.1 Regulations, Orders and Directives ## 3.1.1 Regulations ## The Commission did not issue any new Regulation for the NESI in 2024/Q3. ## 3.1.2 Orders ## During the quarter, the Commission issued fifty (50) Orders to guide the activities of ## licensees. The details of the Orders are outlined below: ## A. Order Nos: NERC/2024/074—NERC/2024/084 (11 Orders issued to 11 ## DisCos) — July 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 July 2024 supplementary Orders (effective ## date - 01 July 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. # Due to the subsistence of the policy direction of the FGN on electricity subsidy # which mandates that tariffs for Band B-E customer categories shall remain frozen # at the rates payable in December 2022 subject to further policy direction by the # government, only customers in Band A experienced a change in their tariffs. **B. Order Nos: NERC/2024/086—NERC/2024/096 (11 Orders issued to 11 DisCos) — Order on Performance Monitoring Framework for the Distribution** ## Companies. The Order became effective on 08 July 2024 and specifies seven **16** ## (7) Key Performance Indicators (KPIs) on which the management of DisCos ## shall be assessed by the Commission. The objectives of the Order include; **i. Hold the top management of DisCos accountable for compliance with reporting requirements and implementation of directives of the** ## Commission in line with the terms and conditions of their licenses. **i) Energy off-take relative to Partial Contracted Capacity (PCC), ii) Revenue recovery rate, iii) Compliance** **with reporting of Uniform System of Account (USoA), iv) Compliance with API feeder streaming, v) Compliance** **with the Order on capping of estimated bills, vi) Compliance with the implementation of forum decisions, vii)** **Compliance with service standards for the resolution of complaints received through the NERC contact centre** **and NERC headquarters** ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # ii. Drive increased operational performance across the DisCos thereby improving energy delivery to customers. **iii. Drive DisCos towards achieving customer-centric operations and enhanced efficiency, which will consequently boost customer satisfaction.** **iv. Reinforce market discipline and ensure that DisCos commercial performance sets them on the path of long-term financial sustainability.** # The top management of DisCos shall be accountable for achieving the KPIs and their # performance shall be assessed periodically based on the review cycle for each KPI # as contained in the Order. Furthermore, the Orders contain the consequential **regulatory intervention which the Commission may exercise when a DisCo fails to comply with the targets set for each KPI.** # C. Order No: NERC/2024/097 — Revised Order on the Transition Accounting # Treatment of Tariff-Related Liabilities in the Financial Records of Market **Participants-July 2024. The Order became effective on 05 July 2024 and the objectives include:** # i. Ensure that no new tariff shortfall liability accrues in the financial records of DisCos. # ii. Completely remove the encumbrances relating to tariff shortfall liabilities # in the books of DisCos to improve their creditworthiness for the purpose # of raising capital towards the improvement of electricity networks and service delivery. # iii. Re-affirm the list of funding sources available to NBET and authorise NBET # to issue credit notes to DisCos against payments made to GenCos covering **17** # tariff shortfall liabilities to include funds provided under various sources : # The incidence of non-cost reflective tariffs in the NESI has over the years resulted in # the accumulation of tariff shortfall liabilities in the financial records of DisCos thereby # eroding their creditworthiness. Tariff-related revenue shortfalls represent the policy # cost of providing subsidies to customers as defined by the FGN. The continued # recognition of this FGN obligation as liabilities in the financial records of DisCos is # therefore considered inappropriate under the current market structure. The Order # provides that NBET shall invoice DisCos for the approved “DisCos’ Remittance **17** **i) Payment Assurance Facility or other funding sources in the PSRP financing plan; ii) Direct budgetary** **appropriation to NBET; iii) Payments made by the Federal Ministry of Finance (FMoF) to GenCos for the purpose** **of settling NBET’s obligation arising from shortfall; iv) Other payments by FMoF from other miscellaneous** **sources; v) Payments made by NBET from any other source not explicitly listed in the Order** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # Obligation” (DRO) as the full and final energy invoice to the DisCos on a monthly **basis and record applicable tariff shortfall portion of the monthly generation invoices as a receivable from the FGN.** # D. Order No: NERC/2024/058 — Order on the Transition to Bilateral Trading in # the NESI. The Order became effective on 25 July 2024 and was driven by the # recognition that the global best practice for bulk energy trading involves the # execution of fully effective PPAs between GenCos and DisCos, backed by **effective fuel supply agreements and bank guarantees to cover payment obligations to ensure an electricity market with certainty in performance** # obligations. The objectives of the Order include: **i. Steer the electricity market towards bilateral contracting for energy and capacity between generation and/or trading licensees with distribution** **licensees thus limiting the fiscal exposure of the Federal Government to market risks.** **ii. Foster a more competitive market structure as envisioned by the EA by** **repositioning NBET from its current role as the sole bulk electricity trader in the NESI.** **iii. Transition the contractual framework for bulk energy trading in the NESI to “take-or-pay” contracts thereby fostering increased certainty and** # market discipline among market participants. iv. Allow DisCos to explore opportunities for increased optimisation/firming # up of their wholesale energy offtake, and a reduction of their vesting **contract capacity with NBET for take-and-pay PPAs, thus providing certainty of availability of generation and improvement in quality of** # supply to end-users. # E. Order No: NERC/2024/002 — Order on the Nomenclature of Generating # Plants. The Order became effective on 01 August 2024 and provides that all # generation licensees shall ensure that their records are updated in accordance # with the new nomenclature and the SO shall update all its data gathering and # reporting platforms to ensure compliance with the nomenclature. The objectives of the Order include; **i. Establish a clear and standardised methodology to identify different power-generating plants to make it easier for stakeholders, including utility** **companies, grid operators, and the public to recognise and distinguish between various types of power plants.** ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## ii. Achieve standardisation in the nomenclature of generation assets within ## the NESI to allow for easy identification and network data reporting. **iii. Develop a naming convention that can be seamlessly deployed into the Supervisory Control and Data Acquisition (SCADA) platform, thereby** ## enhancing the safety and efficiency of operations in NESI. ## iv. Ensure the alignment of references by operators in the industry and ## enhance the safe operation of the transmission network with all apparatus connected to the grid. ## F. Order Nos: NERC/2024/098—NERC/2024/108 (11 Orders issued to 11 ## DisCos) — August 2024 Supplementary Order to the Multi-Year Tariff Order for ## the DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which ## provides for monthly tariff reviews, the August 2024 supplementary Orders ## which became effective on 01 August 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. # Due to the subsistence of the policy direction 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. ## G. Order Nos: NERC/2024/110 — Transfer of Regulatory Oversight of the **Electricity Market in Oyo State from the Nigerian Electricity Regulatory Commission to the Oyo State Electricity Regulatory Commission (OSERC). The** ## Order became effective on 06 August 2024 and has the following objectives; ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Oyo State from the Commission to OSERC ## in accordance with the Constitution of the Federal Republic of Nigeria (CFRN) and EA. ## ii. Provide a transition plan for the transfer of regulatory oversight for the **intrastate electricity market in Oyo State from the Commission to OSERC 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 Oyo State from the Commission to OSERC. ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * | | | THIRD QUARTER 2024 | NERC QUARTERLY REPORTS | | --- | --- | --- | --- | | I. | i. ii. iii. 38 | from IBEDC. Edo State Electricity Regulatory Commission effective on 21 August 2024 and has the following objectives; accordance with the CFRN and EA. accordance with the CFRN and the EA. Commission to ESERC. The Order mandates Benin Electricity Distribution Plc from BEDC. Order Nos: price for the determination of cost-reflective tariff. 2024, all end-use customer tariffs remain unchanged. | The Order mandates Ibadan Electricity Distribution Plc (IBEDC) to incorporate within 60 days, a subsidiary under the CAMA for the assumption of responsibilities for intrastate supply and distribution of electricity in Oyo State H. Order No: NERC/2024/111 — Transfer of Regulatory Oversight of the Electricity Market in Edo State from the Nigerian Electricity Regulatory Commission to the (ESERC). The Order became Commence the process of the transfer of regulatory oversight for the intrastate electricity market in Edo State from the Commission to ESERC in Provide a transition plan for the transfer of regulatory oversight for the intrastate electricity market in Edo State from the Commission to ESERC in Address ensuing transitional matters arising from the transfer of regulatory oversight for the intrastate electricity market in Edo State from the (BEDC) to incorporate within 60 days, a subsidiary under the CAMA for the assumption of its responsibilities for intrastate supply and distribution of electricity in Edo State NERC/2024/114—NERC/2024/124 (11 Orders issued to 11 DisCos) — September 2024 Supplementary Order to the Multi-Year Tariff Order for the DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which provides for monthly tariff reviews, the September 2024 supplementary Orders which became effective on 01 September 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 Due to the subsistence of the policy direction of the FGN on electricity subsidy which mandates a freeze on tariffs across all bands (A-E) at rates payable in July \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] | * * * ### THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## J. Order No: NERC/2024/125 — Transfer of Regulatory Oversight of the Electricity ## Market in Kogi State from the Nigerian Electricity Regulatory Commission to the **Kogi State Electricity Regulatory Commission (KSERC). The Order became effective on 13 September 2024 and has the following objectives;** ## iv. Commence the process of the transfer of regulatory oversight for the **intrastate electricity market in Kogi State from the Commission to KSERC in accordance with the CFRN and EA.** ## v. Provide a transition plan for the transfer of regulatory oversight for the **intrastate electricity market in Kogi State from the Commission to KSERC in accordance with the CFRN and the EA.** ## vi. Address ensuing transitional matters arising from the transfer of regulatory ## oversight for the intrastate electricity market in Kogi State from the Commission to KSERC. ## The Order mandates Abuja Electricity Distribution Plc (AEDC) to incorporate ## within 60 days, a subsidiary under the CAMA for the assumption of its ## responsibilities for intrastate supply and distribution of electricity in Kogi State from AEDC. ## 3.1.3 Directives ## The Commission did not issue any Directive to licensees in 2024/Q3. However, the **Commission continued to monitor compliance with the provisions of other existing regulations, orders, and standards governing the NESI.** # 3.2 Licences Issued or Renewed ## In 2024/Q3, the Commission issued six (6) new off-grid generation licences \[gross\ \ **18** **capacity of 30.06MW\], one (1) on-grid generation licence \[gross capacity of 39.00MW\] and two (2) new trading licences (Table 11).** **Table 11: Licences issued by the Commission in 2024/Q3** ### SN Licensee Location Capacity License Type Fuel Type **(MW)** **1 Daybreak power Solutions Ogun State 2.00 Off-grid Solar** **2 Daybreak power Solutions Ogun State 2.25 Off-grid Solar** **3 Daybreak power Solutions Ogun State 2.41 Off-grid Solar** **The on-grid generation licence was a renewal for Mabon Limited** **\[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]** * * * THIRD QUARTER 2024 NERC QUARTERLY REPORTS | SN | Licensee | Location | Capacity(MW) | License Type | Fuel Type | | --- | --- | --- | --- | --- | --- | | 4 | Daybreak power Solutions | Lagos State | 4.20 | Off-grid | Solar | | 5 | TIS Renewable Energy Limited | Lagos State | 6.00 | Off-grid | Gas | | 6 | Golden penny Power Ltd | Ogun State | 13.20 | Off-grid | Gas | | 7 | Mabon Limited | Gombe State | 39.00 | On-grid | Hydro | | 8 | Damcrest Energy Limited | FCT, Abuja | NA | Trading | N/A | | 9 | Zenith point limited | Lagos State | NA | Trading | N/A | 3.3 Captive Power Generation Permits 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 eleven (11) applicants (gross capacity of 63.36MW) as detailed in Table 12. Table 12: Captive Generation Plants approved in 2024/Q3 | S/N | Company Name | Location/State | Capacity(MW) | | --- | --- | --- | --- | | 1 | University of Abuja | Gwagwalada,Abuja | 3.00 | | 2 | University of Calabar&Teaching Hospital | Cross River State | 7.00 | | 3 | University of Agriculture Micheal Okpara | Umetuke,Abia State | 3.00 | | 4 | University of Maiduguri&Teaching Hospital | Main Campus,Borno State | 12.00 | | 5 | Federal University of Agriculture,Abeokuta | Main Campus,Ogun State | 3.00 | | 6 | Federal University Gashuwa | Sabon Gari,Yobe State | 1.50 | | 7 | Nigerian Defence Academy | Kaduna State | 2.50 | | 8 | Nigeria Breweries Plc(Aba Breweries) | Aba,Abia State | 5.60 | | 9 | Nigeria Breweries Plc(Ibadan Breweries) | Ibadan,Oyo State | 7.20 | | 10 | Nigeria Breweries Plc(Ama Breweries) | Ama-Eke Ngwo,Enugu State | 10.59 | | 11 | Nigeria Breweries Plc(Aba Malting Plant) | Obingwa,Abia State | 7.97 | * * * 3.4 Mini-grid Permits and Registration Certificates 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 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 distribution capacity above 100kW and generation capacity up to 1MW. The Commission also issues registration certificates to developers for one or more systems with distribution capacity below 100kW. In 2024/Q3, the Commission issued one (1) registration certificate to Cross boundary Energy Access Nigeria Assets Limited. 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. The Commission certified seven (7) MSPs – five (5) meter installer companies, and two (2) meter manufacturers in 2024/Q3. The Commission also issued twenty-two (22) permits for MAP. Details of the certified MSPs and MAP are contained in Table 13. Table 13: Meter Service Providers certified in 2024/Q3 | S/N | Name | Authorisation Type | | --- | --- | --- | | | Meter Service Providers | | | 1 | Bee-Springs Services Ltd | Installer A1 | | 2 | Armese Consulting Ltd | Installer A1 | | 3 | Shimi H & F Ltd | Installer A1 | | 4 | Integrated Power Nigeria Limited | Installer A1 | | 5 | Meter Service Hub | Installer A1 | * * * THIRD QUARTER 2024 NERC QUARTERLY REPORTS | S/N | Name | Authorisation Type | | --- | --- | --- | | 6 | Amal Technologies Ltd | Manufacturer | | 7 | Sabrud Consortium Nigeria Ltd | Manufacturer | | | Meter Asset Providers | | | 1 | Wellsun Intelligent Technology Ltd | MAP | | 2 | Kiggs Meters and Systems Ltd | MAP | | 3 | Skyrun Elec. Smart Metering System | MAP | | 4 | Paktim Engineering Consultants MGT | MAP | | 5 | Skipper Nigeria Limited | MAP | | 6 | Amal Tech Ltd | MAP | | 7 | Morgan Energy Limited | MAP | | 8 | Beacon Energy Development Services Ltd | MAP | | 9 | Anietronic Limited | MAP | | 10 | Utility Performance Limited | MAP | | 11 | Ams Smart Tech Solutions Nig. Ltd | MAP | | 12 | Susej Nigeria Limited | MAP | | 13 | Phisbond Nigeria Limited | MAP | | 14 | Marks & Adams Investment Ltd | MAP | | 15 | Chris Omonri Nigeria Enterprises Ltd | MAP | | 16 | TSL Engineering Limited | MAP | | 17 | BTS Power Limited | MAP | | 18 | Chintech Electro Nigeria Limited | MAP | | 19 | Domtech Consult Limited | MAP | | 20 | Dari Investment Limited | MAP | | 21 | Mahashakti Nigeria Limited | MAP | | 22 | Metub Services Limited | MAP | 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 * * * 19 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. During the quarter (2024/Q3) the Commission conducted administrative proceedings in the form of hearings to consider the petitions filed by different stakeholders on issues pertaining to the provision and utilisation of electricity services. The details of the hearings are contained in Table 14. Table 14: Hearings conducted by the Commission in 2024/Q3 | S/N | Parties | Petition | Date of Hearing | Update | | --- | --- | --- | --- | --- | | 1 | Ikeja Electric Plc, Eko Electricity Distribution Plc, Incorporated Trustees of Hotel Owners and Managers | Petition against the April and May 2024 Supplementary Orders to the Multi-Year Tariff Order | 11 July 2024 | A ruling has been issued | | 2 | Abuja Electricity Distribution Plc, Zeberced Quarry Limited, Mainstream Energy Services Limited, TCN | Petition filed by AEDC against Zeberced Quarry Limited to regularise its contractual relationship and pay for loss of revenue. | 23 July 2024 | A ruling has been issued | | 3 | Incorporated Trustees of Royal Garden Estate, Eko Electricity Distribution Company, Trojan Estates Limited, Solar Gardens Projects Limited | The Estate Association filed an application against bulk billing | 07 August 2024 | The petition is Sub judice | | 4 | NBET | Hearing on NBET's application for renewal of its license | 12 September 2024 | Completed. The licence has been renewed. | | 5 | Ibadan Electricity Distribution Company, Phoenix Steel Mills | Petition against the grant of eligible customer | 15 September 2024 | A ruling has been issued | Pursuant to the provisions of Section 76 of the EA 2023, the Commission issued six (6) Rectification Directives (RD) and ten (10) Notices of Intention to Commence 3.7 Compliance and Enforcement 19 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. 43 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Enforcement (NICE) for different breaches/defaults in 2024/Q3 (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. Table 15: Compliance and Enforcement Actions of the Commission in 2024/Q3 | SN | RD/NICE/Fine | Licensee | Date of Issuance | Deadline | | --- | --- | --- | --- | --- | | Rectification Directive | | | | | | 1 | Failure to meter 15 customers within the prescribed 10-day period after payment | IBEDC | 20 August 2024 | 03 September 2024 | | 2 | Failure to file audited financial statements | Various off-grid licensees20 | 30 August 2024 | 13 September 2024 | | 3 | Failure to adequately show compliance with post-incident remedial actions directed by the Commission | TCN | 09 September 2024 | 23 September 2024 | | 4 | Failure to submit 2024/Q2 accident prevention/reduction strategy | EKEDC, Nigerian Agip Oil Company Limited, Shell Petroleum Development Company Limited | 18 September 2024 | 25 September 2024 | | 5 | Non-compliance with forum decision | Ikeja DisCo | 06 September 2024 | 13 September 2024 | 20 The licensees include ABV Utility Limited, African Oxygen & Industrial Gases Limited, Aggreko Projects Limited, Ariaria IPP Limited, Babcock consulting Limited, Bayshore Technologies Limited, Central Electricity & Utilities Limited, CET Power Projects Limited, CKS Power Nigeria Limited, Constant Independent Electric Power Distribution Company, Contour Global Solutions (Nig.) Limited, CPGN Limited, Cross-boundary energy Nigeria Limited, Daybreak Power Solutions Limited, Eko utilities limited, Elektron Energy, Energy Company of Nigeria Plc., Gateway Electricity Limited, GEL Utility Limited, Genco Atlantic power Company Limited, Geometric, Power Aba Limited, Green Energy International Limited, Hamakang Global Services Limited, Haske Solar Company Limited, Ibom Utility Company Limited, Income Electrix Limited, Isolo Power Gen Limited, Kano Hydro & Energy, Development Company Limited, Konexa Solar 1 limited, Ladol Integrated logistics, Freezone Enterprise, LBL Power & Gas Company Limited, MBH Power Limited, Notore Power & Infrastructure Limited, Otakikpo Independent electricity, Distribution Company, Pulkit Powers Limited, PZ Power Company Limited, Quest Oil & Engineering Services limited, Shoreline Power Company Limited, Tofu Energy & Power Company Nigeria Limited, Tower Power utility Limited, Unipower Agbara Limited, Uraga Power Distribution Company Limited, Viathan Engineering Limited, Wedotebary Nigeria Limited, Westcom Tech. & Energy Services Limited. * * * THIRD QUARTER 2024 NERC QUARTERLY REPORTS | 6 | Non-compliance with the Commission's decision regarding complaint by KYC estate | Abuja DisCo | 24 September 2024 | 30 September 2024 | | --- | --- | --- | --- | --- | | Notice of Intention to Commence Enforcement(NICE) | | | | | | 7 | Non-compliance with the Commission's directives against bulk-billing | Enugu DisCo | 13 September 2024 | 27 September 2024 | | 8 | Non-metering of MD customers | Port Harcourt and Enugu DisCos | 08 July 2024 | 15 July 2024 | | 9 | Decommissioning of 7,319 meters without the Commission's prior consent | Ibadan DisCo | 05 July 2024 | 19 July 2024 | | 10 | Health and safety infractions | Kano DisCo | 20 August 2024 | 03 September 2024 | | 11 | Non-compliance with the Commission's post-incident recommendations | Enugu DisCo | 09 September 2024 | 23 September 2024 | | 12 | Failure to submit reports on standardisation of network infrastructure for 2024/Q2 | Enugu and Eko DisCos | 30 August 2024 | 13 September 2024 | | 13 | Health and safety infractions | Ibadan DisCo | 05 September 2024 | 19 September 2024 | | 14 | Non-compliance with the Commission's directives on faulty transformer replacement | Abuja DisCo | 21 August 2024 | 05 September 2024 | | 15 | Non-compliance with the Commission's directives against bulk-billing | Eko DisCo | 13 September 2024 | 27 September 2024 | | 16 | Health and safety infractions | Kano DisCo | 11 September 2024 | 25 September 2024 | * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * | | | THIRD QUARTER 2024 | NERC QUARTERLY REPORTS | | --- | --- | --- | --- | | and | enlighten processes. • • • 47 | issues including: • • • • • • • • • • | 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 consumers/stakeholders on the Commission’s activities, regulatory instruments, consumer rights and obligations and to ensure swift resolution of complaints. These fora also provide avenues for the Commission to gather feedback from consumers which is beneficial to the Commission in its decision-making As part of its routine activities, the Commission also engages relevant stakeholders 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 Consumer rights and obligations Service delivery standards NESI performance factsheets Regulatory instruments issued by the Commission Summary of the statutory reports of the Commission In 2024/Q3, the Commission held two (2) town hall meetings in Gombe (18-20 July 2024 and Calabar (08-10 August 2024). Some of the major issues that were discussed at the town hall meetings include: Serviced Based Tariff (SBT) provisions Capping of estimated bills for unmetered customers Electricity customer rights and obligations Electricity customer redress mechanisms Unauthorised electricity access \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] | * * * • 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 30th September 2024, 6,156,726 (46.15%) out of the 13,339,635 registered electricity customers across the twelve (12) DisCos were metered (breakdown contained in Table 16). Table 16: Metering Progress as of 2024/Q3 | DisCos | Total No.of Registered Customers | No. of Metered Customers | Metering Rate(%) | | --- | --- | --- | --- | | Aba | 202,523 | 76,052 | 37.55 | | Abuja | 1,263,483 | 896,753 | 70.97 | | Benin | 1,402,484 | 689,122 | 49.14 | | Eko | 724,213 | 455,496 | 62.90 | | Enugu | 1,396,440 | 654,770 | 46.89 | | Ibadan | 2,582,740 | 1,114,609 | 43.16 | | Ikeja | 1,249,385 | 956,469 | 76.56 | | Jos | 752,943 | 253,792 | 33.71 | | Kaduna | 881,749 | 214,113 | 24.28 | | Kano | 883,742 | 214,650 | 24.29 | | Port Harcourt | 1,179,194 | 512,429 | 43.46 | | Yola | 820,739 | 118,471 | 14.43 | | Total | 13,339,635 | 6,156,726 | 46.15 | \*Metering rate: Red <50, Amber 50≤70, Green ≥70 During 2024/Q3, 184,507 end-user customers were metered across all the DisCos with Ikeja, Ibadan and Abuja DisCos recording the highest number of meter installations – they accounted for 25.45%, 21.48% and 14.61% respectively, of the total installations. Relative to 2024/Q2 when 51,826 customers were metered, there was a +256.01% increase in the total number of customers metered in 2024/Q3. * * * All DisCos except Aba (-43.90%), Kaduna (-24.69%) and Jos (-9.31%) recorded improvements in the number of meter installations. Eko, Ibadan, Ikeja and Benin DisCos recorded the greatest improvements of +2,120%, +575.60%, +417.40%, and +389.32% respectively in the number of meter installations compared to 2024/Q2 (Table 17). Table 17: Meter Deployment by DisCos 2024/Q3 vs. 2024/Q2 | DisCos | Total No.of metered customers as of2024/Q3 | No.of customers metered in2024/Q3 | No.of customers metered in2024/Q2 | Change in metering(%) | | --- | --- | --- | --- | --- | | Aba | 76,052 | 4,928 | 8,784 | -43.90 | | Abuja | 896,753 | 26,951 | 11,733 | 129.70 | | Benin | 689,122 | 17,175 | 3,510 | 389.32 | | Eko | 455,496 | 17,982 | 810 | 2,120.00 | | Enugu | 654,770 | 19,075 | 4,241 | 349.78 | | Ibadan | 1,114,609 | 39,624 | 5,865 | 575.60 | | Ikeja | 956,469 | 46,959 | 9,076 | 417.40 | | Jos | 253,792 | 2,824 | 3,114 | -9.31 | | Kaduna | 214,113 | 1,845 | 2,450 | -24.69 | | Kano | 214,650 | 767 | 418 | 83.49 | | Port Harcourt | 512,429 | 6,377 | 1,825 | 249.42 | | Yola | 118,471 | - | - | - | | Total | 6,156,726 | 184,507 | 51,826^{21}$ | 256.01 | Out of the 184,507 end-use customers metered in 2024/Q3, 178,715 (96.86%) of customers were metered under the MAP framework, 3,508 (1.90%) were metered under the Vendor Financed framework, and 2,298 (1.24%) were metered under 22 the DisCo Financed framework. Further details on the metering progress under the 21 Upon data reconciliation, the number of meters installed across all metering schemes in 2024/Q2 was 51,826 as against 49,188 reported in the 2024/Q2 report. 22 There are 5 metering frameworks contained in the Commission’s updated MAP & NMMP Regulations (NERC- R-113-2021). They are: • Meter Asset Provider: This framework aims to provide for the provision and maintenance of end-user meters as a service by third-party investors on which customers benefitting from such meters pay a Metering Service Charge (MSC) to cover the cost of metering service. • National Mass Metering Programme: This is a policy intervention with support from the CBN for the provision of long-term (10-year tenure) single-digit interest loans to DisCos strictly for the provision of locally manufactured/assembled meters to customers. • Vendor Finance: This is a mutual agreement between a DisCo and a Local Meter • Vendor Finance: This is a mutual agreement between a DisCo and a Local Meter Manufacturer/Assembler (LMMA) or Meter Asset Provider (MAP) on a deferred payment arrangement where the base cost of meters shall not exceed the regulated price approved by the Commission. * * * NMMP, MAP as well as Vendor and DisCo financed frameworks are presented in appendices X, XI and XII respectively. Under the MAP framework, a total of 178,715 meters were installed in 2024/Q3 representing a +399.55% increase compared to the 35,775 MAP meter installations recorded in 2024/Q2. Ikeja (46,819), Ibadan (39,603) and Abuja (26,376) DisCos recorded the highest number of installations under the MAP framework during the quarter with 26.20%, 22.16% and 14.76% of the total installations respectively. 23 During the quarter, there was no meter installation under the NMMP framework. Abuja, Eko, Ibadan, Ikeja, Jos and Port Harcourt DisCos have exhausted their meter allocations under the NMMP phase 0 and hence have achieved a 100% utilisation rate. Benin, Kaduna and Yola still have significant allocations under the NMMP which they are yet to utilise (Table 18). Table 18: Meter Installations under the National Mass Metering Programme (NMMP) | DisCos | Meters Contracted | Total Installations | Utilisation Rate(%) | | --- | --- | --- | --- | | Abuja | 100,475 | 100,475 | 100.00 | | Benin | 90,870 | 80,156 | 88.21 | | Eko | 79,178 | 79,010 | 99.79 | | Enugu | 92,381 | 91,512 | 99.06 | | Ibadan | 117,379 | 117,379 | 100.00 | | Ikeja | 111,703 | 111,703 | 100.00 | | Jos | 96,096 | 95,765 | 99.66 | | Kaduna | 69,152 | 47,907 | 69.28 | | Kano | 87,747 | 83,480 | 95.14 | | Port Harcourt | 82,720 | 82,720 | 100.00 | | Yola | 85,376 | 53,003 | 62.08 | | Total | 1,013,077 | 943,110 | 93.09 | • Self-funded by DisCos: This involves procurement of meters from other sources outside the MAP and NMMP framework. The allowable costs of meters, accessories, installation and warranties should not exceed the regulated pricing approval by the Commission and the terms of supply should not be in conflict with terms of existing MAP and NMMP contracts. • Other External Efficient Meter Financing: The Commission has also approved other external meter conflict with terms of existing MAP and NMMP contracts. • Other External Efficient Meter Financing: The Commission has also approved other external meter financing that are efficient, cost-effective, and in tune with the terms of existing MAP and NMMP contracts. 23 With the winding down of Phase 0 of the NMMP, meter installations under the framework will no longer be reported. Reporting will be resumed when the Federal Government commences any new national metering scheme/initiative. 50 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ### THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 4.3 Customer Complaints ## In furtherance of its mandate as contained in section 119(1)(c) of the EA 2023 which ## states that “the Commission shall develop in consultation with licensees, the customer # complaints handling standard and procedure”, the Commission provides various ## channels for customers to lodge complaints against their service providers. The ## primary channels available for customers to lodge complaints in the NESI are: ## A. NERC Customer Complaint Unit (NERC-CCU): This is a unit at the Consumer ## Affairs Division of the Commission dedicated to the resolution of complaints received ## directly from customers. Customers can lodge complaints at the NERC-CCU via ## emails, letters or phone calls (through the NESI Call Centre). ## B. DisCo Customer Complaint Unit (DisCo-CCU): This is a department in a DisCo that ## is dedicated to the receipt and resolution of complaints from customers. DisCos **submit monthly customer complaints reports which the Commission reviews to identify cases where regulatory intervention is necessary.** ## 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. As of 30th September 2024, the ## Commission had thirty-three (33) operational Forum Offices in thirty-one (31) states ## and the FCT, Abuja. The details including names, addresses and contacts of the ## Commission’s Forum Offices are contained in Appendix XVI. ## 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. ### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 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). **5\. A representative of an NGO based in the distribution company’s operating area nominated by the 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/Q3, 5,287 complaints were received at the Commission’s CCU and 1,647 # were resolved corresponding to a 31.15% resolution rate. This resolution rate # represents a +8.77pp increase compared to the 22.38% resolution rate recorded # in 2024/Q2. Customers of Ikeja and Eko DisCos lodged 2,401 and 1,073 # complaints accounting for 45.41% and 20.30% respectively of the total complaints # lodged at NERC-CCU. Conversely, Aba Power had the lowest number of complaints # with 10 (0.19%). The Commission notes the poor resolution rate (31.15%) of **complaints lodged at the NERC-CCU in 2024/Q3 and is taking steps to improve the speediness of complaints resolution by DisCos.** # During the quarter, customer complaints about billing constituted 34.37% of the total **complaints. Other common issues among the 5,287 complaints received were metering (29.98%), tariff band (13.60%) and service interruption (12.24%). These** # four (4) complaints categories cumulatively accounted for 90.18% of the total # complaints in the quarter (Figure 10). The complaints on billing that were resolved **during the quarter resulted in a credit adjustment on customers' bills to the tune of** ₦207,442,190 (Appendices XIV and XV). ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Figure 10: Category of complaints received at the Commission’s CCU in 2024/Q3 4.3.2 DisCo-CCUs The number of complaints received by DisCos in 2024/Q2 and 2024/Q3 are contained in Table 19. The total number of complaints received in 2024/Q3 was 328,696 across all DisCos; this translates to a +14.35% increase compared to the 287,441 received in 2024/Q2. Eko DisCo received the highest number of complaints (64,987) representing 19.77% of total complaints received. Yola DisCo received the least number of complaints (2,583) representing 0.79% of total complaints received. | DisCos | No. of complaints received in2024/Q2 | No. of complaints received in2024/Q3 | Change in No.of complaints received | Change in No.of complaints received(%) | | --- | --- | --- | --- | --- | | Aba | 4,279 | 4,933 | 654 | 15.28 | | Abuja | 25,893 | 31,407 | 5,514 | 21.30 | | Benin | 6,020 | 11,809 | 5,789 | 96.16 | | Eko | 53,377 | 64,987 | 11,610 | 21.75 | | Enugu | 22,020 | 20,769 | -1,251 | -5.68 | | Ibadan | 51,718 | 56,597 | 4,879 | 9.43 | | Ikeja | 20,536 | 22,971 | 2,435 | 11.86 | | Jos | 20,013 | 20,782 | 769 | 3.84 | | Kaduna | 6,546 | 7,405 | 859 | 13.12 | | Kano | 18,073 | 27,511 | 9,438 | 52.22 | | PH | 56,928 | 56,942 | 14 | 0.02 | | Yola | 2,038 | 2,583 | 545 | 26.74 | | Total | 287,441 | 328,696 | 41,255 | 14.35 | Benin (+96.16%), Kano (+52.22%), Yola (+26.74%), Eko (+21.75%) and Abuja (+21.30%) DisCos recorded the most significant increase in the number of customer complaints received in 2024/Q3 compared to 2024/Q2. Only Enugu (-5.68%) DisCo recorded a decrease in the number of customer complaints received between 2024/Q2 and 2024/Q3. The most common issues among the 328,696 complaints received by DisCos in 2024/Q3 were metering (41.95%), billing (21.28%), and service interruption (7.05%). These three (3) complaints categories cumulatively accounted for 70.28% of the total complaints in the quarter (Figure 11). Figure 11: Category of complaints received by DisCos in 2024/Q3 4.3.3 Forum Offices The summary of the appeals received across the Forum Offices is presented in Table 20\. Through 2024/Q3, there were 3,202 active appeals (1,035 pending appeals from 2024/Q2 and 2,167 new appeals in 2024/Q3) across the 33 Forum Offices. * * * This represents a +21.98% increase compared to the 2,625 active appeals in the previous quarter (2024/Q2). Compared to 2024/Q2, the pending appeals carried over in the quarter (2024/Q3) increased by 130 (+14.36%) while new appeals increased by 447 (+25.99%). The Forum Offices serving Ibadan DisCo have the highest number of active appeals (1,032); representing 32.23% of the total while the Forum Office serving Aba has the fewest (6) in 2024/Q3. The total number of Forum sittings in 2024/Q3 increased by +2.67% from 75 sittings in 2024/Q2 to 77. Cumulatively, the Forum Offices recorded an increase of +4.00pp in appeal resolution rate between 2024/Q2 and 2024/Q3; 54.90% vs. 58.90%. The increase in complaint resolution rate despite the significant increase in active appeals between 2024/Q2 and 2024/Q3 can be attributed to the increase in number of sittings and the increased effectiveness of the forum at resolving complaints. The Commission will continue efforts to ensure that the forum panels sit regularly to increase the resolution rate and reduce the number of pending appeals carried over across quarters. The total number of Forum sittings in 2024/Q3 increased by +2.67% from 75 sittings to 77. Cumulatively, the Forum Offices recorded an increase of +4.00pp in appeal resolution rate between 2024/Q2 and 2024/Q3; 54.90% vs. 58.90%. The increase in complaint resolution rate despite the significant increase in active appeals between 2024/Q2 and 2024/Q3 can be attributed to the increase in number of sittings and the increased effectiveness of the forum at resolving complaints. The Commission will continue efforts to ensure that the forum panels sit regularly to increase the resolution rate and reduce the number of pending appeals Table 20: Appeals handled by Forum Offices in 2024/Q3 | DisCos | Forum Offices | Appeals Received¹ | Appeals Resolved² | Appeals Pending³ | No. of Sittings | | --- | --- | --- | --- | --- | --- | | Abuja | Abuja, Lafia & Lokoja | 93 | 59 | 34 | 7 | | Aba | Umuahia | 6 | 0 | 6 | 0 | | Benin | Asaba & Benin | 128 | 74 | 54 | 5 | | Eko | Eko | 270 | 175 | 95 | 6 | | Enugu | Abakaliki, Akwa, Enugu, Owerri, & Umuahia | 471 | 332 | 139 | 19 | | Ibadan | Ibadan, Abeokuta, Ilorin & Osogbo | 1,032 | 491 | 481 | 20 | | Ikeja | Ikeja | 719 | 414 | 305 | 6 | | Jos | Bauchi, Gombe, Jos & Makurdi | 70 | 30 | 38 | 1 | | Kaduna | Gusau, Kaduna, Kebbi & Sokoto | 47 | 26 | 19 | 3 | | Kano | Jigawa, Kano & Katsina | 29 | 16 | 9 | 1 | | P/Harcourt | Calabar, Port Harcourt & Uyo | 308 | 256 | 49 | 9 | | Yola | Yola, Damaturu | 29 | 13 | 16 | 0 | | All DisCos | All Forum Offices | 3,202 | 1,886 | 1,234 | 77 | | $ ^{1}$ Appeals received include outstanding appeals from the preceding quarter. $ ^{2}$ Appeals resolved excludes 64 appeals rejected and 18 appeals withdrawn. $ ^{3}$ Appeals are still within the regulatory timeframe of 2 months to resolve. | | | | | | 1 2. Appeals received include outstanding appeals from the preceding quarter. Appeals resolved excludes 64 appeals rejected 3\. and 18 appeals withdrawn. Appeals are still within the regulatory timeframe of 2 months to resolve. The breakdown of the various categories of active appeals at the Forum Offices in 2024/Q3 is contained in Figure 12. Similar to 2024/Q2, appeals related to billing were the most prevalent, accounting for 50.21% of the total appeals received * * * (2024/Q2 – 55.93%). Appeals related to metering and disconnection represented 31.98% and 6.09% of the appeals, respectively. The Commission is working on interventions to improve the quality of customer complaint resolution at the DisCo- CCU to resolve effectively and reduce the number of appeals filed at the Forum Offices. Figure 12: Category of Complaints Received by Forum Offices in 2024/Q3 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/Q3, out of the 99 mandatory health and 24 safety reports expected to be received from licensees, only 96 reports were received. 96^{24} 24 The licensee with outstanding report is Paras Energy with one outstanding report each for July, August and September. 56 \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * Statistics of accidents in the NESI for 2024/Q3 are presented in Table 21. Relative to 2024/Q2, the number of accidents decreased by -11.11% (63 to 56), the number of fatalities decreased by -14.71% (34 to 29) but the number of injuries increased by +64.71% (17 to 28). Table 21: Health and Safety (H&S) Reports in 2024/Q2 vs. 2024/Q3 | Item | 2024/Q2 | 2024/Q3 | Net Change | | --- | --- | --- | --- | | Number of Accidents | 63 | 56 | -7 | | Number of fatalities (employees&third parties) | 34 | 29 | -5 | | Number of Injuries | 17 | 28 | +11 | During the quarter (2024/Q3), only Egbin recorded a casualty among the GenCos while among the DisCos, NESCO was the only DisCo that did not record any 25 casualty. Out of the fifty-seven (57) casualties reported in the quarter, the licensees with the highest number of casualties were Ibadan (11), Kaduna (10) and Abuja (7) DisCos which represented 19.30%, 17.54%, and 12.28% of the total respectively. As observed in previous quarters, DisCos continue to account for the majority of the safety challenges experienced in NESI. Cumulatively, they accounted for 92.98% of causalities recorded in 2024/Q3 having accounted for 98.48%, 96.30% and 100% in 2023/Q4, 2024/Q1 and 2024/Q2 respectively. Furthermore, TCN (22) and Jos (1) DisCo recorded damage to property/infrastructure due to explosions, fire outbreaks or acts of vandalism in 2024/Q3. The accident report showing licensees with casualties during the quarter is detailed in Figure 13. 25Casualty refers to the count of injuries and deaths arising from any safety accident/incident. * * * Figure 13: Accident Report for 2024/Q3 The breakdown of the causes of causalities arising from the accidents reported in 2024/Q3 is contained in Table 22. Table 22: Causes of casualties recorded in 2024/Q3 | Cause of Casualty | Number of Fatalities | Number of Injuries | | --- | --- | --- | | Wire snaps | 14 | 4 | | Illegal/unauthorised access | 4 | 2 | | Vandalism | 4 | 1 | | Unsafe acts/conditions | 6 | 18 | | Falls from height | 1 | 2 | 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, * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS # 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. # In addition, the Commission oversees settlement processes between licensees and # 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/Q3, the Commission oversaw the successful conclusion of three # (3) compensation negotiations between licensees and families of victims of accidents. ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\] * * * 5.0 Appendix Appendix I: Definition of Terms | Term | Definition | | --- | --- | | Accident | This is an incident that happens unexpectedly and unintentionally, typically resulting in damage, injury, or fatality | | Available Capacity | This is the maximum rated output (MW) of a power plant over a specified period declared by the operator when restricted by factors such as feedstock availability, mechanical availability, environmental conditions, etc. | | Bilateral customers | These are customers who purchase electricity directly from GenCos without a middleman (e.g., bulk trader). | | Cost-reflective tariff | This is a tariff that if charged to consumers will allow for 100% recovery of the costs incurred in the production, transmission, distribution, and supply of electricity as well as guaranteeing regulatory approved profit margin for the operators. | | Energy offtake | This is the process by which distribution companies receive and supply energy to end-use consumers | | Feedstock | This refers to the type of fuel (e.g., gas, water) required to power a generating plant | | Installed capacity | This is the maximum rated output of a power plant under specific conditions designated by the manufacturer | | Load factor | This is a measure of the utilisation of a power plant's 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). | | Mini-grid | This is an electricity supply system with its own power generation capacity, supplying electricity to more than one customer and which can operate in isolation from or be connected to a distribution network | | Orders | A series of directives/instructions issued by the Commission to Licensees in response to a particular event/situation | | Plant Availability Factor | This is a parameter that measures the proportion of a plant's installed capacity which is available for the generation of electric energy. | | Regulations | A set of rules that the Commission may issue from time to time to optimise the performance of licensees to give effect to the object of the EA 2023 | | Service-based tariff | Service-based tariff is a pricing system under which consumers are charged varying tariffs dependent on the average number of hours of supply they receive per day. | | Total Energy Generated | This refers to the total energy generated (GWh) by a power plant during the period under review | * * * Appendix II: 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 III: Energy Generation in 2024/Q2 vs. 2024/Q3 | GenCos | Available Capacity(MW) | | Average Daily Generation(MWh) | | Quarterly Generation(GWh) | | | --- | --- | --- | --- | --- | --- | --- | | 2024/Q2 | 2024/Q3 | 2024/Q2 | 2024/Q3 | 2024/Q2 | 2024/Q3 | | | Afam\_1 | 19.19 | 54.12 | 405.84 | 1,198.86 | 36.93 | 110.29 | | Afam\_2 | 275.72 | 330.61 | 6,383.00 | 7,850.09 | 580.85 | 722.21 | | Alaoji\_1 | 0.18 | 0.00 | 0.00 | - | 0.00 | - | | Ihovbor\_2 | 452.00 | 388.03 | 9,567.64 | 7,869.02 | 870.65 | 723.95 | | Dadin-Kowa\_1 | 6.42 | 35.72 | 150.24 | 843.12 | 13.67 | 77.57 | | Delta\_1 | 347.33 | 366.12 | 8,053.25 | 8,186.21 | 732.85 | 753.13 | | Egbin\_1 | 659.27 | 528.27 | 14,919.90 | 10,993.52 | 1,357.71 | 1,011.40 | | Geregu\_1 | 150.42 | 141.24 | 3,433.86 | 2,882.79 | 312.48 | 265.22 | | Geregu\_2 | 183.26 | 185.53 | 3,767.40 | 2,433.01 | 342.83 | 223.84 | | Ibom Power\_1 | 91.67 | 51.47 | 1,525.56 | 1,053.49 | 138.83 | 96.92 | | Ihovbor\_1 | 0.13 | 44.57 | 0.00 | 589.47 | 0.00 | 54.23 | | Jebba\_1 | 296.68 | 436.87 | 6,214.26 | 8,610.79 | 565.50 | 792.19 | | Kainji\_1 | 300.65 | 374.06 | 6,827.68 | 8,320.17 | 621.32 | 765.46 | | Odukpani\_1 | 300.96 | 265.81 | 6,647.56 | 4,889.91 | 604.93 | 449.87 | | Okpai\_1 | 206.98 | 292.09 | 4,151.31 | 6,009.93 | 377.77 | 552.91 | | Olorunsogo\_1 | 79.53 | 146.35 | 1,857.32 | 3,441.33 | 169.02 | 316.60 | | Olorunsogo\_1 | 14.28 | 92.99 | 348.90 | 1,219.34 | 31.75 | 112.18 | | Omoku\_1 | 46.14 | 54.30 | 1,339.92 | 1,508.92 | 121.93 | 138.82 | | Omotosho\_1 | 75.97 | 146.14 | 1,848.49 | 3,128.92 | 168.21 | 287.86 | | Omotosho\_2 | 0.11 | 8.44 | 0.00 | 39.86 | 0.00 | 3.67 | | Ikeja\_1 | 92.78 | 97.49 | 2,077.68 | 2,073.18 | 189.07 | 190.73 | | Rivers\_1 | 65.38 | 116.47 | 1,310.25 | 1,805.92 | 119.23 | 166.14 | | Sapele\_2 | 0.24 | 22.63 | 0.00 | 288.56 | 0.00 | 26.55 | * * * Appendix IV: Monthly energy offtake and energy billed by DisCos in 2024/Q2 and 2024/Q3 | DisCos | Energy Offtake(GWh) | | | | | | Energy Billed(GWh) | | | | | Billing Efficiency | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2(%) | 2024/Q3(%) | | | Apr | May | June | July | Aug | Sept | Apr | May | June | July | Aug | Sept | | | | | Abuja | 361 | 399 | 329 | 378 | 380 | 365 | 277 | 276 | 282 | 307 | 312 | 292 | 76.68 | 81.00 | | Benin | 170 | 202 | 191 | 223 | 227 | 242 | 143 | 167 | 160 | 187 | 192 | 206 | 83.35 | 84.27 | | Eko | 302 | 353 | 287 | 315 | 315 | 352 | 273 | 314 | 258 | 280 | 284 | 314 | 89.70 | 89.30 | | Enugu | 163 | 169 | 160 | 203 | 212 | 214 | 149 | 167 | 153 | 151 | 165 | 161 | 95.33 | 74.98 | | Ibadan | 243 | 310 | 264 | 310 | 318 | 329 | 211 | 276 | 237 | 279 | 288 | 296 | 88.75 | 89.98 | | Ikeja | 373 | 417 | 347 | 355 | 372 | 402 | 308 | 336 | 293 | 299 | 320 | 333 | 82.47 | 84.24 | | Jos | 114 | 107 | 112 | 142 | 143 | 146 | 83 | 79 | 80 | 84 | 94 | 91 | 72.76 | 62.66 | | Kaduna | 140 | 157 | 146 | 158 | 152 | 135 | 86 | 101 | 93 | 93 | 96 | 97 | 63.07 | 64.01 | | Kano | 143 | 167 | 134 | 165 | 154 | 155 | 103 | 122 | 106 | 137 | 138 | 141 | 74.63 | 87.38 | | P/Harcourt | 171 | 187 | 173 | 188 | 184 | 187 | 144 | 155 | 145 | 153 | 154 | 162 | 83.56 | 83.74 | | Yola | 48 | 28 | 48 | 57 | 54 | 54 | 46 | 26 | 44 | 45 | 50 | 49 | 93.94 | 85.73 | | All DisCos | 2,227 | 2,497 | 2,190 | 2,499 | 2,522 | 2,584 | 1,824 | 2,019 | 1,851 | 2,014 | 2,092 | 2,143 | 82.34 | 82.15 | * * * Appendix V: Monthly revenue performance and collection efficiency by DisCos in 2024/Q2 and 2024/Q3 | DisCos | Total Billing(N'Billion) | | | | | | Revenue Collected(N'Billion) | | | | | Collection Efficiency | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2(%) | 2024/Q3(%) | | | Apr | May | June | July | Aug | Sept | Apr | May | June | July | Aug | Sept | | | | | Abuja | 28.70 | 27.84 | 27.94 | 31.05 | 33.44 | 34.77 | 22.92 | 22.97 | 24.29 | 23.86 | 26.18 | 28.24 | 83.07 | 78.87 | | Benin | 13.29 | 14.23 | 13.71 | 15.50 | 16.82 | 18.45 | 11.03 | 10.65 | 12.27 | 12.83 | 13.45 | 14.80 | 82.35 | 80.94 | | Eko | 27.41 | 30.87 | 27.16 | 31.99 | 32.85 | 38.28 | 24.93 | 23.92 | 26.37 | 28.05 | 28.71 | 30.30 | 88.03 | 84.40 | | Enugu | 12.02 | 15.09 | 13.75 | 14.14 | 15.83 | 16.75 | 9.09 | 10.18 | 11.11 | 11.16 | 12.65 | 12.25 | 74.35 | 77.23 | | Ibadan | 18.27 | 23.91 | 20.82 | 24.27 | 24.59 | 26.10 | 14.50 | 14.74 | 15.02 | 17.88 | 18.39 | 21.32 | 70.25 | 76.84 | | Ikeja | 29.99 | 32.31 | 29.96 | 29.44 | 33.91 | 36.38 | 29.40 | 26.92 | 31.02 | 24.69 | 26.13 | 32.71 | 94.67 | 83.78 | | Jos | 8.92 | 7.15 | 7.99 | 8.78 | 10.32 | 11.63 | 6.05 | 4.71 | 4.96 | 6.06 | 5.61 | 4.70 | 65.37 | 53.29 | | Kaduna | 8.07 | 8.63 | 7.54 | 8.29 | 8.06 | 8.22 | 5.01 | 4.67 | 5.01 | 4.00 | 3.61 | 3.78 | 60.62 | 46.42 | | Kano | 12.53 | 13.25 | 11.54 | 14.92 | 14.02 | 14.95 | 6.66 | 6.83 | 8.41 | 9.30 | 8.03 | 3.30 | 58.71 | 47.03 | | P/Harcourt | 14.01 | 14.36 | 13.64 | 13.97 | 13.09 | 14.25 | 10.78 | 10.35 | 11.46 | 11.28 | 9.63 | 8.30 | 77.59 | 70.76 | | Yola | 3.54 | 1.98 | 3.08 | 3.15 | 3.79 | 4.04 | 1.10 | 1.81 | 1.87 | 1.66 | 1.89 | 1.85 | 55.67 | 49.3% | | All DisCos | 176.79 | 189.65 | 177.18 | 195.50 | 206.71 | 223.81 | 141.51 | 137.80 | 151.83 | 150.77 | 154.31 | 161.60 | 79.31 | 74.55 | * * * Appendix VI: DisCos monthly invoices & remittances to NBET in 2024/Q2 and 2024/Q3 | DisCos | Invoice(N'Billion) | | | | | | Remittance(N'Billion) | | | | | Remittance Performance | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2(%) | 2024/Q3(%) | | | Apr | May | June | July | Aug | Sept | Apr | May | June | July | Aug | Sept | | | | | Abuja | 18.14 | 19.76 | 19.81 | 21.98 | 20.68 | 20.41 | 15.59 | 16.20 | 16.18 | 17.42 | 18.84 | 20.43 | 83 | 90 | | Benin | 7.93 | 9.32 | 10.23 | 11.57 | 10.99 | 11.62 | 7.21 | 6.38 | 8.32 | 8.96 | 9.23 | 10.53 | 80 | 84 | | Eko | 16.59 | 19.13 | 18.82 | 19.99 | 18.67 | 20.58 | 16.59 | 18.09 | 19.17 | 20.04 | 18.76 | 20.62 | 99 | 100 | | Enugu | 6.77 | 8.23 | 9.17 | 10.17 | 10.39 | 10.04 | 5.21 | 6.31 | 7.51 | 7.88 | 8.67 | 8.38 | 79 | 81 | | Ibadan | 11.07 | 13.74 | 13.95 | 15.95 | 15.53 | 15.63 | 9.87 | 9.44 | 10.18 | 12.96 | 13.04 | 15.42 | 76 | 88 | | Ikeja | 20.29 | 22.38 | 22.39 | 22.46 | 21.94 | 23.04 | 16.57 | 17.04 | 18.08 | 18.35 | 21.77 | 23.20 | 79 | 94 | | Jos | 4.48 | 3.40 | 4.00 | 4.77 | 6.08 | 4.07 | 3.59 | 2.17 | 2.08 | 3.67 | 3.44 | 2.57 | 66 | 65 | | Kaduna | 5.69 | 6.63 | 6.92 | 7.56 | 6.72 | 3.62 | 1.81 | 1.81 | 1.99 | 2.05 | 1.74 | 1.62 | 29 | 30 | | Kano | 6.11 | 7.37 | 6.82 | 8.33 | 7.62 | 4.12 | 4.17 | 4.11 | 5.92 | 6.47 | 5.33 | 1.59 | 70 | 67 | | Port Harcourt | 7.34 | 7.88 | 8.50 | 9.26 | 8.60 | 8.72 | 6.15 | 6.76 | 6.32 | 7.96 | 6.58 | 5.56 | 81 | 76 | | Yola | 0.80 | 0.02 | 0.05 | 0.60 | 0.90 | 0.31 | 0.27 | 0.14 | 0.55 | 0.60 | 0.82 | 0.31 | 111 | 95 | | All DisCos | 105.21 | 117.88 | 120.67 | 132.63 | 128.11 | 122.16 | 87.02 | 88.50 | 96.34 | 106.36 | 108.21 | 110.24 | 79 | 85 | 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 VII: DisCos monthly invoices & remittances to MO in 2024/Q2 and 2024/Q3 | DisCos | Invoice(℗'Billion) | | | | | | Remittance(℗'Billion) | | | | | | RemittancePerformance | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2 | | | 2024/Q3 | | | 2024/Q2(%) | 2024/Q3(%) | | | Apr | May | June | July | Aug | Sept | Apr | May | June | July | Aug | Sept | | | | | Abuja | 3.07 | 3.54 | 2.53 | 2.97 | 3.36 | 3.09 | 2.64 | 3.95 | 1.93 | 2.26 | 3.00 | 2.98 | 93 | 87 | | Benin | 1.44 | 1.77 | 1.31 | 1.57 | 1.80 | 1.63 | 1.31 | 1.59 | 0.97 | 1.14 | 1.45 | 1.44 | 86 | 81 | | Eko | 2.64 | 2.14 | 2.14 | 2.40 | 2.66 | 2.12 | 2.55 | 3.21 | 0.87 | 1.60 | 2.48 | 1.94 | 96 | 84 | | Enugu | 1.38 | 1.61 | 1.20 | 1.02 | 1.67 | 1.60 | 1.06 | 1.56 | 0.89 | 0.75 | 1.35 | 1.29 | 84 | 79 | | Ibadan | 2.02 | 2.64 | 1.83 | 2.19 | 2.56 | 2.48 | 1.81 | 2.60 | 1.18 | 1.69 | 2.08 | 2.43 | 86 | 86 | | Ikeja | 3.15 | 3.53 | 2.45 | 2.84 | 3.10 | 2.89 | 2.58 | 3.67 | 1.85 | 2.68 | 2.94 | 2.74 | 89 | 86 | | Jos | 1.00 | 1.24 | 0.94 | 1.14 | 1.30 | 1.19 | 0.80 | 0.90 | 0.21 | 0.79 | 0.60 | 0.65 | 63 | 56 | | Kaduna | 1.18 | 1.40 | 1.03 | 1.31 | 1.41 | 1.27 | 0.38 | 0.31 | 0.10 | 0.16 | 0.11 | 0.40 | 22 | 17 | | Kano | 1.19 | 1.44 | 0.87 | 1.26 | 1.39 | 1.03 | 0.81 | 1.00 | 0.70 | 0.92 | 0.89 | 0.24 | 72 | 56 | | Port Harcourt | 1.44 | 1.49 | 1.13 | 1.36 | 1.34 | 1.31 | 1.20 | 1.78 | 0.74 | 1.12 | 0.96 | 0.78 | 92 | 72 | | Yola | 0.40 | 0.20 | 0.43 | 0.50 | 0.55 | 0.45 | 0.13 | 1.10 | 0.33 | 0.46 | 0.38 | 0.45 | 150 | 86 | | All DisCos | 18.90 | 21.01 | 15.86 | 18.57 | 21.13 | 19.06 | 15.26 | 21.66 | 9.86 | 13.59 | 16.23 | 15.35 | 84 | 77 | 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 VIII: Domestic and international bilateral customers invoices & remittances to MO in 2024/Q3 | | July-24 | | Aug-24 | | Sept-24 | | 2024/Q3 | | 2024/Q3 | Other Remittances (million) | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Invoice (million) | Remittance (million) | Invoice (million) | Remittance (million) | Invoice (million) | Remittance (million) | Invoice (million) | Remittance (million) | Remittance Performance (%) | | | | | International Customers | | | | | | | | | | | | | PARAS-SBEE ($) | 1.18 | 1.18 | 0.70 | 0.70 | 0.89 | 0.00 | 2.79 | 1.89 | 67.87 | 0.00 | | | PARAS-CEEET ($) | 0.00 | 0.00 | 0.33 | 0.33 | 0.65 | 0.65 | 0.98 | 0.98 | 100.00 | 0.00 | | | TRANSCORP-SBEE (UGHELI) | 0.44 | 0.44 | 0.00 | 0.00 | 0.37 | 0.00 | 0.82 | 0.45 | 54.88 | 0.00 | | | TRANSCORP-SBEE (AFAM3) | 0.31 | 0.31 | 0.54 | 0.53 | 0.53 | 0.00 | 1.39 | 0.85 | 61.21 | 0.00 | | | MAINSTREAM-NIGLEEC ($) | 1.17 | 1.17 | 1.14 | 1.14 | 1.11 | 0.00 | 3.44 | 2.32 | 67.44 | 0.00 | | | ODUKPANI-CEET ($) | 0.99 | 0.00 | 0.87 | 0.00 | 0.89 | 0.00 | 2.77 | 0.00 | 0.00 | 1.32 | | | Total | 4.09 | 1.92 | 3.58 | 1.14 | 4.43 | 0.00 | 12.19 | 6.49 | 53.24 | 1.32 | | | Bilateral Customers | | | | | | | | | | | | | MSTM/INNER GALAXY (N) | | | | | | | | | | | | | MSTM/KAM IND. (N) | | | | | | | | | | | | | MSTM/KAM INT. (N) | | | | | | | | | | | | | MAINSTREAM/PRISM (N) | 426.41 | 426.41 | 438.50 | 438.50 | 413.66 | 413.66 | 1,278.78 | 1,278.78 | 100.00 | 0.00 | | | MSTM ZEBERCED (N) | | | | | | | | | | | | | MSTM/ADFV (N) | | | | | | | | | | | | | NDPHC/WEEWOOD (N) | 21.94 | 0.00 | 31.87 | 0.00 | 21.06 | 21.06 | 74.89 | 21.06 | 28.13 | 0.00 | | | NORTH SOUTH/STAR P (N) | 11.16 | 11.16 | 11.00 | 11.00 | 10.81 | 0.00 | 32.98 | 22.16 | 67.21 | 9.50 | | | TRANS AMADI/OAU | 10.65 | 10.65 | 9.62 | 0.81 | 8.04 | 0.00 | 28.32 | 11.47 | 40.50 | 22.01 | | | TRANS AMADI/FMPI | | | | | | | | | | | | | NDPHC/SUNFLAG (N) | 13.29 | 0.00 | 13.05 | 0.00 | 14.00 | 0.00 | 40.35 | 0.00 | 0.00 | 0.00 | | | OMOTOSHO II/PULKIT (N) | | | | | | | | | | | | * * * Appendix IX: Meter installation for all Frameworks (MAP, NMMP, Vendor and DisCo Financed) | DisCos | Meters contracted | Meters installed in 2019 | 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 | Total installations since 2019 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Aba | 24,000 | - | - | - | - | 9,917 | 7,817 | 8,784 | 4,928 | 31,446 | | Abuja | 1,000,475 | 63,925 | 105,253 | 87,987 | 83,494 | 105,154 | 21,493 | 11,733 | 26,951 | 505,990 | | Benin | 664,646 | 1,169 | 11,154 | 72,838 | 6,771 | 34,344 | 10,455 | 3,510 | 17,175 | 157,416 | | Eko | 283,178 | 5,422 | 32,353 | 64,618 | 44,577 | 36,484 | 4,637 | 810 | 17,982 | 206,883 | | Enugu | 713,926 | 17,410 | 54,603 | 96,836 | 57,751 | 73,256 | 13,932 | 4,241 | 19,075 | 337,104 | | Ibadan | 1,106,294 | 4,771 | 38,403 | 94,309 | 146,044 | 139,138 | 25,551 | 5,865 | 39,624 | 493,705 | | Ikeja | 1,186,114 | 22,876 | 160,469 | 125,460 | 145,364 | 151,197 | 27,795 | 9,076 | 46,959 | 689,196 | | Jos | 606,096 | 15 | 4,673 | 88,827 | 19,190 | 12,937 | 3,649 | 3,114 | 2,824 | 135,229 | | Kaduna | 519,152 | 43 | 8,258 | 17,942 | 34,385 | 10,039 | 3,027 | 2,450 | 1,845 | 77,989 | | Kano | 562,747 | 22 | 3,314 | 80,969 | 3,476 | 2,056 | 199 | 418 | 767 | 91,221 | | Port Harcourt | 220,044 | 7,775 | 36,546 | 92,543 | 33,549 | 48,989 | 6,278 | 1,825 | 6,377 | 233,882 | | Yola | 749,376 | - | 478 | 5,955 | 30,386 | 19,295 | 831 | - | - | 56,945 | | Total | 7,636,048 | 123,428 | 455,504 | 828,284 | 604,987 | 642,806 | 125,664 | 51,826 | 184,507 | 3,017,006 | * * * Appendix X: Meter installation through the NMMP Framework as of 2024/Q3 | DisCos | Meters contracted | Meters installed in 2019 | 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 | Total installations since 2020 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Aba | - | - | - | - | - | - | - | - | - | - | | Abuja | 100,475 | - | 17,777 | 82,698 | - | - | - | - | - | 100,475 | | Benin | 90,870 | - | - | 71,734 | 6,108 | 2,314 | - | - | - | 80,156 | | Eko | 79,178 | - | 69 | 56,915 | 15,694 | 6,328 | - | - | - | 79,006 | | Enugu | 92,381 | - | - | 91,238 | 274 | - | - | - | - | 91,512 | | Ibadan | 117,379 | - | 4,985 | 93,761 | 18,626 | 7 | - | - | - | 117,379 | | Ikeja | 111,703 | - | 24 | 111,679 | - | - | - | - | - | 111,703 | | Jos | 96,096 | - | - | 86,474 | 8,709 | 529 | - | - | - | 95,512 | | Kaduna | 69,152 | - | 1,621 | 15,175 | 30,724 | 99 | 24 | 264 | - | 47,907 | | Kano | 87,747 | - | 11 | 80,969 | 2,500 | - | - | - | - | 83,480 | | Port Harcourt | 82,720 | - | 14,212 | 68,508 | - | - | - | - | - | 82,720 | | Yola | 85,376 | - | 88 | 5,955 | 30,386 | 16,574 | - | - | - | 53,003 | | Total | 1,013,076 | - | 38,787 | 765,106 | 113,021 | 25,851 | 24 | 264 | - | 943,053 | * * * Appendix XI: Meter installation through the MAP Framework as of 2024/Q3 | DisCos | Meters contracted | Meters installed in2019 | Meters installed in2020 | Meters installed in2021 | Meters installed in2022 | Meters installed in2023 | Meters installed in2024/Q1 | Meters installed in2024/Q2 | Meters installed in2024/Q3 | Total installations since 2019 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Aba | 12,000 | - | - | - | - | 8,475 | 1,346 | 301 | 2,135 | 12,257 | | Abuja | 900,000 | 63,925 | 87,476 | 5,289 | 82,293 | 103,200 | 21,440 | 10,717 | 26,376 | 400,716 | | Benin | 573,776 | 1,169 | 11,154 | 1,104 | 422 | 29,181 | 10,419 | 3,510 | 17,175 | 74,134 | | Eko | 204,000 | 5,422 | 32,298 | 7,703 | 28,883 | 30,156 | 4,637 | 810 | 17,982 | 127,891 | | Enugu | 621,545 | 17,212 | 54,752 | 5,405 | 57,372 | 73,256 | 13,932 | 4,241 | 19,075 | 245,245 | | Ibadan | 988,915 | 4,771 | 33,418 | 548 | 127,418 | 125,752 | 25,551 | 5,828 | 39,603 | 362,889 | | Ikeja | 1,074,411 | 23,265 | 160,616 | 13,781 | 145,364 | 147,741 | 25,281 | 5,732 | 46,819 | 568,599 | | Jos | 500,000 | 13 | 3,769 | 27 | 3,317 | 12,151 | 1,165 | 283 | 547 | 21,272 | | Kaduna | 450,000 | 129 | 7,352 | 2,767 | 3,565 | 9,887 | 3,003 | 2,186 | 1,845 | 30,734 | | Kano | 475,000 | 22 | 3,303 | - | 976 | 2,056 | 199 | 322 | 781 | 7,659 | | Port Harcourt | 137,324 | 7,775 | 22,334 | 24,035 | 33,549 | 48,989 | 6,278 | 1,825 | 6,377 | 151,162 | | Yola | 664,000 | - | - | - | - | 2,721 | 831 | - | - | 3,552 | | Total | 6,600,971 | 123,703 | 416,472 | 60,659 | 483,159 | 593,565 | 114,082 | 35,775 | 178,715 | 2,006,110 | * * * Appendix XII: Meter installation through Vendor and DisCo Finance Frameworks as of 2024/Q3 | DisCos | Vendor Finance | | | | | | DisCo Finance | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Meters installed in 2024/Q3 | Total installations | Meters installed in 2019 | 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 | Total installations since 2019 | | | | Aba | - | 1,442 | 6,471 | 8,483 | 2,793 | 17,747 | | | | | - | - | - | - | - | - | | Abuja | 1,201 | 1,954 | 53 | 1,016 | 575 | 4,844 | - | - | - | - | - | - | - | - | - | - | | Benin | 241 | 2,849 | 36 | - | - | 3,126 | - | - | - | - | - | - | - | - | - | - | | Eko | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | | Enugu | - | - | - | - | - | - | 106 | 193 | 193 | 105 | - | - | - | - | - | 597 | | Ibadan | - | - | - | - | - | - | - | - | - | - | 13,379 | - | 37 | 21 | 13,437 | | | Ikeja | - | 3,456 | 2,514 | 3,344 | 140 | 9,454 | - | - | - | - | - | - | - | - | - | - | | Jos | - | - | - | - | - | - | - | - | 2,326 | 7,164 | 257 | 2,484 | 2,831 | 2,277 | 17,339 | | | Kaduna | - | - | - | - | - | - | - | - | - | 96 | 53 | - | - | - | 149 | | | Kano | - | - | - | - | - | - | - | - | - | - | - | - | 96 | - | 96 | | | Port Harcourt | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | | Yola | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | - | | Total | 1,442 | 9,701 | 9,074 | 12,843 | 3,508 | 35,171 | 106 | 193 | 2,519 | 7,365 | 53 | 2,484 | 2,964 | 2,298 | 31,618 | | * * * Appendix XIII: Category of complaints received by DisCos in 2024/Q3 | DisCos | Complaints Received | Complaint Categories | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | | | | Aba | 31,407 | 3,030 | 157 | 30 | 4 | 844 | 69 | 8 | 791 | | Abuja | 4,933 | 11,784 | 1,101 | 150 | 66 | 1,056 | 2,754 | 0 | 14,496 | | Benin | 11,809 | 250 | 961 | 78 | 102 | 1,277 | 85 | 2 | 9,054 | | Eko | 20,769 | 33,489 | 5,632 | 595 | 0 | 3,578 | 0 | 0 | 21,693 | | Enugu | 64,987 | 15,054 | 1,475 | 254 | 6 | 2,418 | 185 | 118 | 1,259 | | Ibadan | 56,597 | 5,861 | 1,209 | 115 | 0 | 44914 | 136 | 0 | 4,362 | | Ikeja | 22,971 | 10,422 | 2,339 | 348 | 89 | 2,997 | 89 | 197 | 6,490 | | Jos | 20,782 | 10,479 | 1,867 | 459 | 1 | 5,681 | 213 | 0 | 2,082 | | Kaduna | 7,405 | 2,116 | 3,799 | 608 | 9 | 468 | 180 | 7 | 218 | | Kano | 27,511 | 26,125 | 531 | 49 | 0 | 787 | 9 | 0 | 10 | | Port Harcourt | 56,942 | 17,859 | 3,332 | 1,072 | 0 | 5,895 | 446 | 502 | 27,836 | | Yola | 2,583 | 1,412 | 777 | 295 | - | 40 | 16 | 2 | 41 | | All DisCos | 328,696 | 137,881 | 23,180 | 4,053 | 277 | 69,955 | 4,182 | 836 | 88,332 | * * * THIRD QUARTER 2024 Appendix XIV: Category of complaints received at the Commission’s CCU in 2024/Q3 | DisCos | Complaints Received | Complaints Resolved | Credit Adjustment(N'000) | Complaint Categories | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | Band | Non-compliance | | | | | | Aba | 1 | 0 | - | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | | Abuja | 147 | 70 | 372.66 | 30 | 12 | 0 | 0 | 53 | 9 | 0 | 3 | 34 | 6 | | Benin | 13 | 1 | 71,606.23 | 0 | 6 | 0 | 0 | 3 | 2 | 0 | 1 | 0 | 1 | | Eko | 17 | 12 | 619.99 | 2 | 1 | 0 | 0 | 8 | 1 | 0 | 2 | 3 | 0 | | Enugu | 18 | 3 | - | 2 | 2 | 0 | 0 | 4 | 4 | 0 | 0 | 1 | 5 | | Ibadan | 7 | 1 | 1,925.63 | 3 | 2 | 0 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | | Ikeja | 33 | 4 | 585.24 | 6 | 2 | 0 | 0 | 9 | 1 | 0 | 0 | 2 | 13 | | Jos | 3 | 1 | - | 0 | 1 | 0 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | | Kaduna | 2 | 0 | - | 0 | 2 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | Kano | 0 | 0 | - | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | Port Harcourt | 5 | 2 | - | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 3 | 0 | | Yola | 1 | 0 | - | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | | All DisCos | 247 | 94 | 75,109.78 | 43 | 28 | 0 | 0 | 82 | 17 | 0 | 6 | 46 | 25 | * * * THIRD QUARTER 2024 Appendix XV: Category of complaints received at the NESI Call Centre in 2024/Q3 | DisCos | Complaints Received | Complaints Resolved | Credit Adjustment(N'000) | Complaint Categories | | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | Tariff Band | | | | | | | Aba | 9 | 4 | - | 2 | 2 | 0 | 0 | 5 | 0 | 0 | 0 | 0 | 0 | | Abuja | 711 | 195 | - | 119 | 128 | 9 | 1 | 114 | 41 | 1 | 7 | 291 | | | Benin | 90 | 32 | 27,252.62 | 16 | 23 | 4 | 0 | 35 | 5 | 0 | 1 | 6 | | | Eko | 1,056 | 363 | 8,944.56 | 393 | 165 | 6 | 2 | 270 | 43 | 5 | 18 | 154 | | | Enugu | 183 | 103 | 13,635.87 | 37 | 31 | 2 | 1 | 80 | 13 | 2 | 4 | 13 | | | Ibadan | 317 | 20 | 510.57 | 125 | 41 | 3 | 0 | 89 | 13 | 1 | 12 | 33 | | | Ikeja | 2,368 | 737 | 76,283.63 | 797 | 140 | 13 | 7 | 1,049 | 159 | 4 | 47 | 152 | | | Jos | 47 | 38 | 5,705.11 | 8 | 14 | 4 | 0 | 10 | 1 | 0 | 1 | 9 | | | Kaduna | 29 | 12 | - | 7 | 11 | 0 | 2 | 4 | 1 | 0 | 0 | 4 | | | Kano | 20 | 12 | - | 1 | 8 | 0 | 0 | 3 | 3 | 0 | 2 | 3 | | | Port Harcourt | 177 | 25 | - | 33 | 40 | 3 | 0 | 68 | 18 | 2 | 6 | 7 | | | Yola | 33 | 12 | - | 4 | 16 | 1 | 0 | 8 | 3 | 0 | 0 | 1 | | | All DisCos | 5,040 | 1,553 | 132,332.40 | 1,542 | 619 | 45 | 13 | 1,735 | 300 | 15 | 98 | 673 | | * * * Appendix XVI: List and addresses of NERC Forum Offices as of September 2024 | S/N | Forum Office | Location | Telephone | Email | | --- | --- | --- | --- | --- | | 1 | Abakaliki, Ebonyi State | 3, Ezekua 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, Abeokuta | 9139381008 | [abekukiforum@nerc.gov.ng](mailto:abekukiforum@nerc.gov.ng) | | 3 | Abujia, FCT | 14, Road 131, Gwarinpa, Federal Capital Territory, Abujia | 8146862225 | [abujiforum@nerc.gov.ng](mailto:abujiforum@nerc.gov.ng) | | 4 | Ado-Ekiti, Ekiti State | Km 5, Iwokoro Road, Ado Ekiti, Ekiti State | 9169978242 | [ado-ekitiforum@nerc.gov.ng](mailto:ado-ekitiforum@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 | Plot 80, Aroma Junction Layout, Opp. CBN, Awka, Anambra State | 9037808594 | [awkaiforum@nerc.gov.ng](mailto:awkaiforum@nerc.gov.ng) | | 7 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bauchi, Bauchi State | 9062924607 | [bauchiforum@nerc.gov.ng](mailto:bauchiforum@nerc.gov.ng) | | 8 | Benin, Eda State | 34, Akpakpava Street, Benin City, Eda State | 9037808592 | [beniniforum@nerc.gov.ng](mailto:beniniforum@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 | Plot 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 Jibim Extension, Off Potiskum Road, Damaturu, Yobe State | 9169978243 | [damuturuforum@nerc.gov.ng](mailto:damuturuforum@nerc.gov.ng) | | 12 | Dutse, Jigawa State | Dutse G.R.A, Dutse, Jigawa State | 7031704827 | [jigawaforum@nerc.gov.ng](mailto:jigawaforum@nerc.gov.ng) | | 13 | Eko, Lagos State | 61, Odunlami Street, Off Marina, Lagos Island, Lagos State | 8108607261 | [ekoforum@nerc.gov.ng](mailto:ekoforum@nerc.gov.ng) | | 14 | Enugu, Enugu State | John Anichukwu Close, Plot 7 Mkupkiti Pocket Layout, Enugu, Enugu State | 8148622330 | [enuguuforum@nerc.gov.ng](mailto:enuguuforum@nerc.gov.ng) | | 15 | Gombe, Gombe State | Government Layout 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 Daiji, J. B. Yakubu Road, Gusau, Zamfara State | 9062863163 | [gusauforum@nerc.gov.ng](mailto:gusauforum@nerc.gov.ng) | | 17 | Ibadan, Oyo State | Jibowu Street, Opp. Magara Police Station, Iyaganku, G.R.A, Oadan, Oyo State | 8148622522 | [ibadantorum@nerc.gov.ng](mailto:ibadantorum@nerc.gov.ng) | | 18 | Ikegja, Lagos State | 199, Obatefimi Awolowo Way, Alausa, Ikegja, Lagos State | 8108607298 | [ikegjaforum@nerc.gov.ng](mailto:ikegjaforum@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, Ray-field Road, Jos, Plateau State | 9037808597 | [josforum@nerc.gov.ng](mailto:josforum@nerc.gov.ng) | | 21 | Kaduna, Kaduna State | 22, Ahmadu Bello Way, Opposite NNDC Building, Kaduna, Kaduna State | 8108607299 | [kadunaforum@nerc.gov.ng](mailto:kadunaforum@nerc.gov.ng) | | 22 | Kano, Kano State | Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 8148622222 | [kanoforum@nerc.gov.ng](mailto:kanoforum@nerc.gov.ng) | | 23 | Katsina, Katsina State | 7, Abuja Crescent, Off Hassan Usman Katsina Road, Katsina, Katsina State | 7031704821 | [katsinaforum@nerc.gov.ng](mailto:katsinaforum@nerc.gov.ng) | | 24 | Lafia, Narsarawa State | Manyi Street, Off Jos Road, Bukan Sidi, Lafia, Narsarawa State | 9062924599 | [lafiaforum@nerc.gov.ng](mailto:lafiaforum@nerc.gov.ng) | * * * Appendix XVII: Appeals handled by Forum Offices in 2024/Q2 and 2024/Q3 | S/N | Forum Offices | 2024/Q2 | | | | 2024/Q3 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Appeals Received | Appeals Resolved | Appeals Pending | Appeals Received | Appeals Resolved | Appeals Pending | | | | | | 1 | Abakaliki, Ebonyi State | 66 | 42 | 18 | 63.64 | 64 | 57 | 6 | 89.06 | | 2 | Abeokuta, Ogun State | 152 | 14 | 63 | 9.21 | 180 | 90 | 30 | 50.00 | | 3 | Abuja, FCT | 45 | 30 | 15 | 66.67 | 65 | 48 | 17 | 73.85 | | 4 | Ado-Ekiti | 19 | 11 | 8 | 57.89 | 24 | 17 | 7 | 70.83 | | 5 | Asaba, Delta State | 51 | 34 | 15 | 66.67 | 55 | 38 | 17 | 69.09 | | 6 | Awka, Anambra State | 149 | 103 | 46 | 69.13 | 168 | 94 | 74 | 55.95 | | 7 | Bauchi, Bouchi State | 3 | 3 | 0 | 100.00 | 6 | 6 | 0 | 100.00 | | 8 | Benin, Edo State | 60 | 53 | 7 | 0.00 | 49 | 19 | 30 | 0.00 | | 9 | Damaturu, Yobe State | 3 | 2 | 1 | 66.66 | 5 | 3 | 2 | 0.00 | | 10 | Calabar, C/Rivers State | 26 | 19 | 7 | 73.08 | 31 | 20 | 11 | 64.52 | | 11 | Dutse, Jigawa State | 4 | 2 | 2 | 50.00 | 3 | 2 | 1 | 66.67 | | 12 | Eko, Lagos State | 218 | 155 | 63 | 71.10 | 270 | 175 | 94 | 64.81 | | 13 | Enugu, Enugu State | 204 | 83 | 76 | 40.69 | 186 | 151 | 26 | 81.18 | | 14 | Gombe, Gombe State | 13 | 1 | 12 | 7.69 | 20 | 1 | 18 | 5.00 | | 15 | Gusau, Zamfara State | 10 | 10 | 0 | 100.00 | 7 | 1 | 6 | 14.29 | | 16 | Ibadan, Oyo State | 104 | 65 | 39 | 62.50 | 220 | 59 | 161 | 26.82 | | 17 | Ikeja, Lagos State | 642 | 320 | 322 | 49.84 | 719 | 414 | 305 | 57.58 | | 18 | Ilorin, Kwara State | 96 | 62 | 34 | 64.58 | 159 | 129 | 30 | 81.13 | | 19 | Jos, Plateau State | 17 | 13 | 4 | 76.47 | 38 | 23 | 15 | 60.53 | | 20 | Kaduna, Kaduna State | 28 | 17 | 0 | 60.71 | 29 | 24 | 4 | 82.76 | | 21 | Kano, Kano State | 23 | 17 | 0 | 73.91 | 21 | 10 | 7 | 47.62 | | 22 | Katsina, Katsina State | 4 | 3 | 1 | 75.00 | 5 | 4 | 1 | 80.00 | * * * Appendix XVIII: Category of appeals received by Forum Offices in 2024/Q2 and 2024/Q3 | Forum Office | 2024/Q2 | | | | | | | | 2024/Q3 | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others | Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others | | | 43 | 0 | 0 | 1 | 1 | 0 | 0 | 0 | 46 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | | Abakaliki, Ebonyi State | 60 | 2 | 0 | 1 | 22 | 19 | 0 | 15 | 55 | 8 | 0 | 0 | 32 | 4 | 1 | 17 | | Abeokuta, Ogun State | 4 | 0 | 0 | 0 | 30 | 0 | 0 | 3 | 2 | 0 | 0 | 0 | 41 | 0 | 0 | 7 | | Abuja, FCT | 7 | 0 | 0 | 0 | 5 | 0 | 0 | 1 | 8 | 2 | 0 | 2 | 3 | 0 | 1 | 0 | | Ado-Ekiti, Ekii State | 21 | 0 | 0 | 0 | 5 | 0 | 0 | 4 | 30 | 1 | 0 | 0 | 5 | 0 | 0 | 4 | | Asaba, Delta State | 81 | 6 | 0 | 0 | 17 | 0 | 0 | 0 | 104 | 7 | 0 | 0 | 10 | 0 | 0 | 1 | | Awka, Anambra State | 1 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 1 | 0 | 0 | 3 | | Bauchi, Bauchi State | 36 | 1 | 0 | 0 | 2 | 0 | 0 | 5 | 31 | 0 | 1 | 0 | 5 | 0 | 0 | 5 | | Benin, Edo State | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 3 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | | Dameturu, Vibe State | 2 | 0 | 0 | 0 | 4 | 0 | 0 | 2 | 16 | 1 | 0 | 0 | 5 | 0 | 0 | 2 | | Calabar, C/Rivers State | 7 | 3 | 0 | 0 | 4 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 2 | | Dutse, Jigawa State | 2 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | Eko, Lagos State | 68 | 10 | 0 | 13 | 65 | 0 | 1 | 16 | 93 | 2 | 0 | 13 | 77 | 0 | 1 | 21 | | Enugu, Enugu State | 107 | 9 | 0 | 0 | 13 | 3 | 0 | 4 | 82 | 12 | 0 | 0 | 16 | 0 | 0 | 0 | | Gombe, Gombe State | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 3 | 0 | 0 | 0 | 5 | 0 | 0 | 0 | | Gusau, Zamfara State | 0 | 2 | 1 | 0 | 1 | 0 | 0 | 0 | 4 | 1 | 1 | 0 | 1 | 0 | 0 | 0 | * * * ## THIRD QUARTER 2024 NERC QUARTERLY REPORTS ## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]