20 24 Annual Report & Accounts ELECTRICITY ON DEMAND * * * # 2024 Annual Report # & Accounts ## Nigerian Electricity Regulatory Commission ## Plot 1387 Corastral Zone A00 ## Central Business District ## PMB 1;A, Garki Abuja **[www.nerc.gov.ng](http://www.nerc.gov.ng/)** * * * Our Mission Promote and ensure investor-friendly industry and efficient market structure to meet the needs of Nigeria for safe, adequate, reliable and affordable electricity. Our Vision Core "Electricity on demand" Excellence, transparency, courage and discipline; Our Motto "Keeping the lights on" Making decisions in a fair, transparent and consistent manner, in compliance with the laws of Nigeria and our regulations. * * * ## Preface and Content NERC Annual Report 2024 **NERC©2025** ## NERC Annual Report & Accounts is prepared in compliance with section 56 (1) of ## the Electricity Act 2023, which mandates the Commission to keep proper accounts ## and other records relating to such accounts in respect of all the Commission’s ## activities, funds and property, including such particular account and records as the ## Minister may require. The report presents the Commission’s regulatory and ## corporate activities, audited financial statements and analyses of the state of the ## Nigerian Electricity Supply Industry (NESI) covering operational, technical and ## commercial performances as well as consumer affairs. The Commission presents this ## report to a wide spectrum of stakeholders, including financial and market analysts, ## potential investors, government institutions and the private sector. ## NERC Annual Report & Account is freely available to the Nigerian Electricity Supply ## Industry stakeholders, government agencies and corporations. Individuals, on ## request, can also obtain any particular issue without a charge. Please direct all ## inquiries, comments and suggestions on the report to: ## The Commissioner ## Planning, Research and Strategy ## Nigerian Electricity Regulatory Commission ## Corporate Head Office ## 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) ## Nigerian Electricity Regulatory Commission i * * * Table of Contents Executive Summary ..... 1 Chapter One: Legal and Regulatory Framework ..... 19 1.1 Background to the creation of the Commission ..... 21 1.2 Regulatory Functions ..... 25 1.3 Legal Framework ..... 26 1.4 Reporting Obligations ..... 29 1.4.1 Quarterly Reports ..... 29 1.4.2 Financial Reports ..... 29 Chapter Two: Human Resource Management ..... 30 2.1 Board of Commissioners ..... 32 2.2 Management Staff ..... 34 2.3 Secretary of the Commission ..... 35 2.4 Forum Office Secretaries ..... 35 2.5 Staff Composition ..... 36 2.5.1 Distribution by Division ..... 36 2.5.2 Distribution by Cadre ..... 37 2.5.3 Distribution by Gender ..... 38 2.6 Capacity Development ..... 38 2.7 Promotion, Awards and Retirement ..... 39 Chapter Three: Corporate Govern * * * Preface and Content 5.2.2 Summit on Accelerating Scale-up of RE Resources in Nigeria ..... 108 5.2.3 Other Stakeholder Engagements ..... 110 Chapter Six: Electricity Tariffs ..... 125 6.1 Introduction ..... 126 6.2 Components of Electricity Tariffs ..... 126 6.3 Multi-Year Tariff Order (MYTO) ..... 127 6.3.1 Objectives of the MYTO ..... 127 6.4 Customer Tariffs in 2024 ..... 130 6.4.1 Service-Based Tariff Regime (SBT) ..... 130 Chapter Seven: State of the Nigerian Electricity Supply Industry (NESI) ..... 139 7.1 Operational Report ..... 141 7.1.1 Available Generation ..... 141 7.1.2 Plant Availability Factor (PAF) ..... 142 7.1.3 Total Generation ..... 145 7.1. * * * ## Preface and Content NERC Annual Report 2024 **List of Tables** **Table 2.1: General Managers of the Commission as of December 2024 ... 34** **Table 2.2: Other Management Staff of the Commission ... 34** **Table 2.3: Distribution of the Commission’s Staff by Divisions in 2024 ... 37** **Table 2.4: Distribution of the Commission’s Staff by Cadre in 2024 ... 37** **Table 3.1: Regulatory Instruments issued by the Commission in 2024 ... 47** **Table 4.1: DisCos’ Credit Adjustments and Regulatory Sanction ... 63** **Table 4.2: Reporting requirements on the Operationalisation of MAF ... 68** **Table 4.3: Details of licenced grid-connected Power Plant as of December 2024 ... 80** **Table 4.4: Electricity Distribution Licensees (DisCos) in the NESI ... 82** **Table 4.5: Approved State Electricity Regulatory Bodies in the NESI ... 83** **Table 4.6: Trading Licences issued in 2024 ... 84** **Table 4.7: Licenses, Permits and Certifications Issued by the Commission in 2024 ... 85** **Table 4.8: Summary of enforcement actions carried out by the Commission in 2024 ... 87** **Table 4.9: Hearings conducted by the Commission in 2024 ... 91** **Table 5.1: Town Hall Meetings held in 2024 ... 96** **Table 5.2: Appeals Handled by Forum Offices in 2024 ... 104** **Table 5.3: NESI Meetings held in 2024 ... 107** **Table 5.4: Stakeholder engagements and other activities of the Commission in 2024... 110** **Table 6.1: Parameters considered during Tariff Reviews ... 129** **Table 6.2: Customer Cluster and Expected Service Delivery ... 131** **Table 6.3: Summary of NERC’s Decision on APLE’s Filing ... 132** **Table 6.4: DRO and Average Tariff for Non-MD Customers Across DisCos in 2024 ... 135** **Table 6.5: Comparison of the Average Electricity Tariff in Nigeria & African Countries 136** **Table 7.1: Plant Availability Factor (%) in 2024 ... 143** **Table 7.2: System Collapses in 2019 – 2024 ... 156** **Table 7.3: System collapse incidents in 2024 ... 157** **Table 7.4: Metering Progress as of December 2024 ... 159** **Table 7.5: Meter Deployment by DisCos in 2024 ... 161** **Table 7.6: Meter Installations under the Metering Frameworks ... 162** **Table 7.7: Meter Installations under the NMMP Framework ... 162** **Table 7.8: Energy Offtake Performance in 2024 ... 166** **Table 7.9: Energy Received and Billed by DisCos in 2024 ... 168** **Table 7.10: Revenue Performance of DisCos in 2024 ... 169** **Table 7.11: ATC&C Loss of DisCos in 2024 ... 171** **Table 7.12: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024 ... 173** **Table 7.13: DisCos Remittance Performance to NBET and MO in 2024 ... 175** **Table 7.14: International & Bilateral Customers Invoices & Remittances in 2024 ... 176** ## Nigerian Electricity Regulatory Commission iv * * * ## Preface and Content NERC Annual Report 2024 ## List of Figures **Figure 1.1: Major reforms under the EPSRA 2004 ... 22** **Figure 1.2: Highlights of Reforms in the NESI (2005 – 2024) ... 24** **Figure 2.1: Distribution of the Commission’s Staff by Gender in 2024 ... 38** **Figure 3.1: Structure of the Commission as of December 2024 ... 44** **Figure 3.2: NERC Strategic Plan (SP-III) ... 46** **Figure 5.1: Category of Complaints Received at the Commission’s CCU in 2024 ... 102** **Figure 5.2: Category of Complaints Received by all DisCos in 2024 ... 103** **Figure 5.3: Category of Complaints Received by all Forum Offices in 2024 ... 105** **Figure 6.1: Components of Electricity Tariffs ... 126** **Figure 6.2: FGN subsidy obligation in 2024 ... 134** **Figure 7.1: Average Available Capacity (MW) in 2024 ... 142** **Figure 7.2: Average Hourly Generation (MWh/h) in 2024 ... 146** **Figure 7.3: Average Share (%) of Generation Output by Power Plants in 2024 ... 147** **Figure 7.4: Load Factor of Plants with Highest Dispatch Rate (%) in 2024 ... 148** **Figure 7.5: Actual TLF (%) vs. MYTO TLF Target (%) in 2024 ... 152** **Figure 7.6: Monthly System Frequency (Hz) from Jan – Dec 2024 ... 153** **Figure 7.7: Monthly System Voltage (kV) in 2024 ... 155** **Figure 7.8: DisCos’ Remittance Performance to NBET and MO in 2024 ... 174** ## Nigerian Electricity Regulatory Commission v * * * LIST OF ABBREVIATIONS ADR Alternative Dispute Resolution AEDC Abuja Electricity Distribution Plc ANAN Association of National Accountants of Nigeria ATC&C Aggregate Technical, Commercial & Collection Losses BCR Business Continuity Regulations BEDC Benin Electricity Distribution Plc BPE Bureau of Public Enterprises CA Consumer Affairs CAPEX Capital Expenditure CAPMI Credited Advance Payment for Metering Implementation CEET Compagnie Energie Electrique du Togo CPC Consumer Protection Council DisCos Distribution Companies DSOs Distribution System Operators EA Electricity Act ECN Electricity Corporation of Nigeria EEDC Enugu Electricity Distribution Plc EKEDP Eko Electricity Distribution Plc EPM Engineering Performance and Monitoring EPSRA Electric Power Sector Reform Act FCT Federal Capital Territory FMS Financial and Management Services GenCos Generation Companies GWh Gigawatt hours IBEDC Ibadan Electricity Distribution Plc ICAN Institute of Chartered Accountants of Nigeria IEDN Independent Electricity Distribution Network IE Ikeja Electric Plc IPP Independent Power Plant JED Jos Electricity Distribution Plc KAEDC Kaduna Electricity Distribution Plc KEDCO Kano Electricity Distribution Plc LLC Legal Licencing and Compliance MAN Manufacturers Association of Nigeria MAP Meter Assets Provider MCR Market Competition and Rates MO Market Operator MW Megawatts MWh Megawatt hours MYTO Multi-Year Tariff Order * * * Preface and Content NACCIMA Nigerian Association of Chambers of Commerce Industry, Mines and Agriculture NAEE Nigerian Association for Energy Economics NAEE Nigerian Association for Energy Economics NBA Nigerian Bar Association NBA Nigerian Bar Association NBET Nigerian Bulk Electricity Trading plc NBET Nigerian Bulk Electricity Trading plc NDA Niger Dams Authority NDA Niger Dams Authority NEPA National Electric Power Authority NEPP National Electric Power Policy NEPP National Electric Power Policy NERC Nigerian Electricity Regulatory Commission NERC Nigerian Electricity Regulatory Commission NESCO Nigerian Electricity Supply Company Limited NESCO Nigerian Electricity Supply Company Limited NESI Nigerian Electricity Supply Industry NESI Nigerian Electricity Supply Industry NICE Notice of Intention to Commence Enforcement NICE Notice of Intention to Commence Enforcement NIGELEC Nigerien Electricity Society NIGELEC Nigerien Electricity Society NIM Nigerian Institute of Management NIM Nigerian Institute of Management NIPP National Integrated Power Project NIPP National Integrated Power Project NSE Nigerian Society of Engineers NSE Nigerian Society of Engineers PP Percentage Points PP Percentage Points PHCN Power Holding Company of Nigeria PHED Port Harcourt Electricity Distribution Plc PHED Port Harcourt Electricity Distribution Plc PRS Planning Research and Strategy PRS Planning Research and Strategy REC Regulation on Eligible Customers REC Regulation on Eligible Customers SBEE Société Béninoise d'Energie Electrique SBEE Société Béninoise d'Energie Electrique TCN Transmission Company of Nigeria Plc TCN Transmission Company of Nigeria Plc TLF Transmission Loss Factor YEDC Yola Electricity Distribution Plc TLF Transmission Loss Factor * * * # Executive Summary * * * # A. Legal and Regulatory Framework # B. Human Resource Management # C. Corporate Governance # D. Regulation, Licensing & Compliance # E. Consumer Affairs # F. Electricity Tariffs # G. State of the Nigerian Electricity Supply Industry (NESI) * * * ## Executivs(aummary NERC Annual Report 2024 ## In 2023, the Electricity Act (EA) was enacted, repealing the ## LEGAL AND **REGULATORY** **Electric Power Sector Reform Act (EPSRA) of 2004 and other acts** **FRAMEWORK related to the Nigerian electricity market. The EA aims to create a** **more efficient, competitive, and liberalised market with private** **sector participation and ensure legislative consistency across** **various segments and stakeholders in the sector. It also recognises** **the Nigerian Electricity Regulatory Commission (NERC or the** **‘Commission’) as the apex regulator for the Nigerian power sector** **and further reinforces NERC’s role in driving competition and** **accountability in the electricity market.** ## NERC continues to fulfil its principal functions as outlined in ## Sections 34(1) and 34(2) of the EA, positioning itself to provide ## robust regulatory interventions as the power sector transitions to ## a more competitive market structure. ## Reporting Obligations: In compliance with the provisions of ## Section 34(1)(g) of the EA, the Commission published four ## quarterly reports (Q1-Q4) of its activities for 2024. The reports ## analysed the state of the Nigerian electricity supply industry ## (NESI), covering operational and/or commercial performances of ## the grid-connected operators. The reports also contained detailed ## updates on the regulatory functions of the Commission during each ## quarter as well as information on consumer affairs (focused on ## customer complaint management and customer metering). ## Furthermore, in compliance with the provisions of Section 56(2) of ## the EA which mandates the Commission to, “no later than three ## months after the end of the financial year, prepare audited ## financial statements”, the Commission engaged KPMG to audit the ## Commission’s accounts for the year ended 31 December 2024. ## Nigerian Electricity Regulatory Commission * * * HUMAN RESOURCE MANAGEMENT ataff Composition: In 2024, the count of the Commission’s total manpower was two hundred and fifty-four (254) broken down as follows – • Seven (7) Commissioners • Thirty-seven (37) Management staff • One Hundred and Thirty-eight (138) Mid-management staff • Fifty (50) Senior staff • Twenty-two (22) junior staff The members of staff are a mix of experienced professionals from diverse disciplines, including Engineering, Economics, Sciences, Finance, Accounting, Social Sciences, Law and other fields relevant to the needs of the Commission. The Commission’s workforce cadre in 2024 is contained in Table A. It also shows the gender split of the Commission’s workforce, with women representing 31% of the total. In line with the provisions of the EA 2023, the Commission continues to promote equitable female representation within the Commission and the wider NESI. | No | Position | Cadre | Gender representation | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | Male | Female | Total | | | | | | | 1 | General Manager | | | 3 | 1 | 4 | | | 2 | Deputy General Manager | Mgt. Staff | 15% | 5 | 3 | 8 | | | 3 | Assistant General Manager | | | 17 | 8 | 25 | | | 4 | Principal Manager | | | 17 | 16 | 33 | | | 5 | Senior Manager | Mid-Mgt. staff | 56% | 29 | 10 | 39 | | | 6 | Manager | | | 29 | 5 | 34 | | | 7 | Assistant Manager | Senior staff | 20% | 19 | 13 | 32 | | | 8 | Analysts | | | 32 | 18 | 50 | | | 9 | Junior Staff | Junior staff | 9% | 21 | 1 | 22 | | | | Total | | | 172 | 75 | 247 | | Note: The staff’s distribution in this table excludes the Commissioners and their Aides * * * ## Executivs(aummary NERC Annual Report 2024 ## Capacity Development: The Commission places a premium on staff ## capacity development, and on account of this, members of staff ## attended the required regulatory, management and leadership ## courses in 2024. **CORPORATE** **Structure of the Commission: In 2024, the Commission maintained** **GOVERNANCE the same core organisational structure it operated in 2023, with** **its activities being split across seven (7) Divisions, which are listed** **below:** - **Chairman’s Office (CO)** - **Consumer Affairs (CA)** - **Engineering Performance & Monitoring (EPM)** - **Finance & Management Services (FMS)** - **Legal, Licensing & Compliance (LLC)** - **Market Competition & Rates (MCR)** - **Planning, Research & Strategy (PRS)** ## The seven (7) Divisions of the Commission are further subdivided ## into twenty-four (24) Units. Each Division is headed by a ## commissioner, who is responsible for overseeing the affairs of the ## Division. A management staff not lower than the rank of Assistant ## General Manager (AGM) coordinates the day-to-day activities of ## each Division and reports to the Commissioner. ## Strategic Goals: The Strategic Plan III (SP3) sets out the high-level ## aspirations for the NESI as well as the role of NERC in their ## attainment for the years 2024 – 2026. While also building upon ## the progress recorded under the SP II (2021 – 2023), the SP III ## takes particular cognisance of the major shifts expected in the ## NESI arising from the amendment of the 1999 constitution and the ## provisions of the EA 2023. Specifically, the plan provides for the ## realisation of the six (6) pillars listed below: ## 1\. Commercially Viable Electricity Market ## 2\. Technically Robust Infrastructure ## 3\. Market Development & Customer Satisfaction ## 4\. Industry Governance & Coordination ## 5\. Compliance & Enforcement ## 6\. Operational Excellence ## Nigerian Electricity Regulatory Commission * * * ## Executivs(aummary NERC Annual Report 2024 ## These pillars were crafted to align with the overall objectives of ## the Commission as outlined in Section (34) of the EA, while also ## being consistent with the overarching policy directives issued by ## the Federal Government of Nigeria. ## Highlights of the Commission’s activities in 2024: The ## Commission’s activities are guided by its strategic goals as well as ## overarching government policy and macroeconomic trends. The ## highlights of some of the Commission’s activities for the year 2024 ## are summarised below – ## A. Regulatory Instruments/Interventions: In 2024, the Commission ## issued 397 regulatory instruments. Pursuant to its quasi-judicial ## mandate as provided in the EA 2023, the Commission also carried ## out 18 hearings during the year. ## B. External stakeholder engagement: The Commission is committed ## to ensuring that stakeholders of the NESI are kept abreast of key ## initiatives of the Commission as well as performance standards for ## licensees in the NESI. In 2024, the Commission undertook ## targeted campaigns through traditional and social media channels ## covering pertinent industry issues, including capping of estimated ## bills, power sector recovery program, metering, health & safety, ## as well as consumer rights and obligations. The Commission also ## engaged power sector policymakers and relevant civil society ## organisations in capacity development. ## C. Upholding customer care standards and Protection: In 2024, the ## Commission carried out critical activities towards ensuring ## effective consumer protection and engagement. These include: ## i. Customer Education/Town Hall meetings in nine (9) states ## of the federation ## ii. Training of Forum members in April 2024, aimed at ## enhancing members' capacity in handling consumer ## disputes presented at the NERC forum offices in the different **states.** **iii. An experiential Peer Review and Capacity Building** **Workshop for Key Customer Service Staff of DisCos held in** ## Nigerian Electricity Regulatory Commission * * * ## Executivs(aummary NERC Annual Report 2024 ## Jos, Plateau state, from 1A to 17 May 2024, to foster ## knowledge sharing and capacity building among **stakeholders.** **iv. The annual Commission Essay Competition and award** **ceremony for secondary school students aimed at** **promoting consumer rights awareness and engagement.** ## D. Improving health/safety and technical robustness of the grid ## system: Some of the key activities implemented during the year ## include – ## i. Facilitation of IoT metering of all 33kV and 11kV ## feeders in the NESI. ## ii. The establishment of the baseline status of the ## deployment of Advanced Metering Infrastructure ## (AMI) and integration of modules into the DisCos’ **operations.** **iii. Completion of the technical audit of the** **interconnected transmission and distribution** **system.** **iv. Integration of technical standards for renewable** **energy-based power generation in the revised** **Nigerian Electricity Supply and Installations** **Standards (NESIS) Regulations.** **v. Completion of the emergency review of the Grid** **Code.** ## vi. Development of guidelines for conducting safety ## audits by licensees in the NESI. ## Nigerian Electricity Regulatory Commission * * * REGULATION, LICENSING AND COMPLIANCE The breakdown of the regulatory instruments issued by the Commission in 2024 is contained in Table B. Table B: Regulatory Instruments issued by the Commission in 2024 | SN | Regulatory Instruments | Number | | --- | --- | --- | | 1 | Regulations | 2 | | 2 | Orders | 167 | | 3 | Licences/Permits | 168 | | 4 | Rectification Directives | 28 | | 5 | Notice to Commence Enforcement Action | 29 | | 6 | Fines | 3 | | | Total | 397 | Regulations: The Commission issued two (2) new regulations in 2024 as detailed below: • Eligible Customer Regulations (NERC-R-001-2024): The Eligible Customer Regulation was issued in March 2024 and repealed the Eligible Customer Regulations 2017. The changes incorporated by the new Regulation include: revision of licensing procedures; unification of the ECR and the Competition Transition Charge (CTC) guidelines; revision of the threshold for eligibility; revision of the duration for confirmation of non-indebtedness. • NERC Regulations on the Procedure for Electricity Tariff Reviews 2024: The NERC Regulation on the Procedure for Electricity Tariff Reviews 2024 was issued in September 2024\. The objectives of the regulations include: o Provide detailed procedures for conducting electricity o Provide detailed procedures for conducting electricity tariff reviews in Nigeria in line with the provisions of the EA and MYTO methodology * * * Table C: Orders issued by the Commission in 2024 | S/N | Order No | Title of Order | Effective Date | | --- | --- | --- | --- | | 1-11 | NERC/2023/023-033 | Multi-Year Tariff Order (MYTO) 2024 for the Distribution Companies | 01 Jan 2024 | | 12 | NERC/2023/034 | Multi-Year Tariff Order (MYTO) 2024 for the Transmission Company of Nigeria Plc | 01 Jan 2024 | | 13 | NERC/2023/035 | Order on Performance Improvement Plan of the Transmission Company of Nigeria | 01 Jan 2024 | | 14 | NERC/2024/001 | Order on the Regulatory Intervention in Kaduna Electricity Distribution Plc | 01 Jan 2024 | | 15-25 | NERC/2024/004-014 | Order on Non-Compliance with Capping of Estimated Bill by DisCos for the period January - September 2023 | 12 Feb 2024 | | 26 | NERC/2024/039 | Transfer of Regulatory Oversight of the Electricity Market in Enugu State from the Nigerian Electricity Regulatory Commission to the Enugu State Electricity Regulatory Commission (EERC) | 01 May 2024 | | 27 | NERC/2024/040 | Order on the Deregulation of Meter Prices for Meters Deployed under the Meter Asset Provider Scheme | 01 May 2024 | | 28-29 | NERC/2024/041-042 | Transfer of Regulatory Oversight of the Electricity Market in Ekiti State from the Nigerian Electricity Regulatory Commission to the Ekiti State Electricity Regulatory Bureau (EERB) | 01 May 2024 | | 30 | NERC/2024/043 | Transfer of Regulatory Oversight of the Electricity Market in Ondo State from the Nigerian Electricity Regulatory Commission to the Ondo State Electricity Regulatory Bureau (OSERB) | 01 May 2024 | | 31 | NERC/2024/044 | NESI Interim Order on Transmission System Dispatch Operations, Cross-Border Supply and Related Matters 2024 | 01 May 2024 | | 32 | NERC/2024/045 | Order on the Establishment of the Independent System Operator (ISO) | 01 May 2024 | | 33 | NERC/2024/072 | Order on the Operationalisation of Tranche A of the Meter Acquisition Fund (MAF) | 24 June 2024 | | 34 | NERC/2024/073 | Transfer of Regulatory Oversight of the Electricity Market in Imo State from the Nigerian Electricity Regulatory Commission to the Imo State Electricity Regulatory Commission (ISERC) | 01 July 2024 | | 35-45 | NERC/2024/086-096 | Order on Performance Monitoring Framework for the Distribution Companies | 08 July 2024 | | 46 | NERC/2024/097 | Revised Order on the Transition Accounting Treatment of Tariff-Related Liabilities in the Financial Records of Market Participants - July 2024 | 05 July 2024 | | 47 | NERC/2024/058 | Order on the Transition to Bilateral Trading in the NESI | 25 July 2024 | | 48 | NERC/2024/002 | Order on the Nomenclature of Generating Plants | 01 Aug 2024 | | 49 | 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) | 06 Aug 2024 | | 50 | NERC/2024/111 | Transfer of Regulatory Oversight of the Electricity Market in Edo State from the Nigerian Electricity Regulatory Commission to the Edo State Electricity Regulatory Commission (ESERC) | 21 Aug 2024 | | 51 | 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) | 13 Sep 2024 | | 52-53 | NERC/2024/112-113 | Transfer of Regulatory Oversight of the Electricity Market in Lagos State from the Nigerian Electricity Regulatory Commission to the Lagos State Electricity Regulatory Commission (LASERC) | 05 Dec 2024 | | 54 | NERC/2024/162 | Addendum -1 to the Order on Performance Monitoring Framework for Distribution Companies July 2024 | 23 Dec 2024 | | 55-57 | NERC/2024/163-165 | Transfer of Regulatory Oversight of the Electricity Market in Ogun State from the Nigerian Electricity Regulatory Commission to the Ogun State Electricity Regulatory Commission (OGERC) | 24 Dec 2024 | Note: In addition to the Orders contained in Table B, the Commission also issued a total of one hundred and ten (110) MYTO Supplementary Orders to DisCos in 2024. The Supplementary Orders sought to reflect the changes in the pass-through indices (not within the control of licensees) including inflation rates, NGN/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff. * * * Licensing and Permits: Following the satisfactory evaluation of applications, the Commission issued one hundred and sixty-eight (168) licenses, permits and certifications in 2024 as contained in Table D. Table D: Licenses, Permits and Certifications Issued by the Commission in 2024 | SN | License/Permit | Number | | --- | --- | --- | | 1 | On-grid generation | 3 | | 2 | Off-grid generation | 22 | | 3 | System Operator | 1 | | 4 | Trading Licence | 9 | | 5 | Captive power | 24 | | 6 | Mini-grid registration | 7 | | 7 | Mini-grid permit | 27 | | 8 | Meter service providers permit | 36 | | 9 | MAP permit | 39 | | | Total | 168 | Compliance Monitoring and Enforcement: In 2024, the Commission issued twenty-eight (28) Rectification Directives (RD), twenty-nine (29) Notices of Intention to Commence Enforcement Actions (NICE) and three (3) fines against licensees for violations of rules and infractions. These include non-compliance with the Commission’s orders, directives and rulings, failure to comply with forum panel decisions without filing appeals within the stipulated timeframe, as well as health and safety infractions. CONSUMER AFFAIRS AND STAKEHOLDER ENGAGEMENTS Consumer Affairs: The Commission conducted nine (9) town hall/customer complaints resolution meetings in 2024. The meetings were conducted as detailed below: • Kano, Kano State; 07-09 March 2024 • Enugu, Enugu State; 18-20 April 2024 • Abuja, FCT; 19 March 2024 • Calabar, Cross River State; 08-10 August 2024 • Lokoja, Kogi State; 12-14 September 2024 • Osogbo, Osun State; 10-12 October 2024 • Osogbo, Osun State; 10-12 October 2024 * * * ## Executivs(aummary NERC Annual Report 2024 - **Kaduna, Kaduna atate; 12-14 December 2024** ## Customer Complaints: The Customer Protection Regulation issued ## by the Commission in 2023 enumerates the standards and ## procedures for handling customer complaints in line with ## international best practices. The Regulation further provides ## various channels for customers to lodge complaints against their ## service providers. The complaints reporting channels include: - **NERC Customer Complaints Unit (NERC-CCU)** - **DisCo Customer Complaint Unit (DisCo-CCU)** - **NERC Forum Office** - **Power Outage Reporting System (PORS) for customers to** ## report outages in real-time. ## In 2024, the NERC-CCU received 16,882 complaints and 4,858 ## were resolved, corresponding to a 28.78% resolution rate. A ## review of the customer complaints data presented in Figure A ## indicates that metering, billing, service interruption, and customer ## band issues were the most common customer complaints, ## accounting for 89.62% (15,130) of the total complaints at the **NERC-CCU.** **317** **12** **2,.086** **36%** **Metering** **Service Interruption** **146 4,832** **0.86%** **993** **28.62% Voltage interruption** **5.88% Load shedding** **76,** **0.45% Billing** **Non-compliance** **Disconnection** **2,542 Delay in Reconnection** **166 5,670, 33.59% 15.06% Others** **0.98%** **Customer Band** **54** **0.32%** ## Figure A: Category of Complaints Received at the NERC-CCU in **2024** ## The total number of complaints received across all DisCo-CCUs in ## 2024 was 1,183,198. Metering, billing, and service interruption ## were the most common complaints issues accounting for 72.33% ## (855,757) of the total (Figure B). ## Nigerian Electricity Regulatory Commission * * * Figure B. Category of Complaints Received at the DisCo-CCUs in 2024 There was a total of 8,351 active appeals (7,575 new appeals and 776 pending appeals) across all Forum Offices in 2024. The Forum Offices held 308 sittings and resolved 83.06% (6,936) of the total active appeals. Billing and metering were the most prevalent complaints within the year, accounting for 52.81% and 29.77% of the total, respectively (Figure C). There was a total of 8,351 active appeals (7,575 new appeals and 776 pending appeals) across all Forum Offices in 2024. The Forum Offices held 308 sittings and resolved 83.06% (6,936) of the total active appeals. Billing and metering were the most prevalent complaints within the year, accounting for 52.81% and 29.77% of the total, respectively (Figure C). Stakeholder Engagements: The Commission held all four (4) quarterly NESI stakeholder consultation meetings for the year to discuss important industry issues and to review compliance and performance. The Commission also organised workshops to * * * ## Executivs(aummary NERC Annual Report 2024 ## engage stakeholders on the implementation of the new Electricity ## Act 2023. ## In July 2024, the Commission convened a summit on Accelerating ## Scale-up of Renewable and Distributed Energy Resources in ## Nigeria. The summit provided a platform for stakeholders to ## discuss strategies, regulatory frameworks, and financing options ## to drive the adoption and incorporation of renewable and ## distributed energy access in the country. ## Other stakeholder engagement activities of the Commission during ## the year include: - **Capacity building workshop for members of the Nigerian** ## Bar Association (NBA) - **Seminar for judges from the Federal and State High Courts** ## as well as the National Industrial Court - **Capacity building workshop for representatives of Civil** ## Society Organisations (CSO) and Community Based ## Organisations (CBO) - **Workshop on Technical Codes for Operators in the NESI** - **Workshop for NESI stakeholders on feeder naming and** ## other asset nomenclature for the NESI - **Training on Average Participation Method for Regional** ## Electricity Transmission by ECOWAS Regional Electricity ## Regulatory Authority (ERERA). ## Multi-Year Tariff Order (MYTO): In compliance with the provisions **ELECTRICITY** **TARIFFS of Section 116 of the EA 2023, the Commission has since 2007** **adopted the Multi-Year Tariff methodology for the determination** **of tariffs to be charged by electricity distribution companies in the** **NESI.** ## The MYTO is an incentive-based regulation that seeks to reward ## performance above certain benchmarks, reduce technical and ## non-technical/commercial losses and lead to cost recovery as well ## as improved performance standards from all industry operators in ## the NESI. ## Nigerian Electricity Regulatory Commission * * * The MYTO methodology uses a building blocks approach in setting transmission and distribution tariffs, which provides the joint benefit of price cap and incentive-based regulation. The generation tariff is determined using a benchmark Long Run Marginal Cost (LRMC) of the most economically efficient new entrant. The group of parameters which the Commission considers in determining or reviewing tariffs include: • Macroeconomic indices • Aggregate Technical and Commercial Losses (ATC&C) targets and trajectories • Capital Expenditure (CAPEX) • Operational Expenditure (OPEX) • Energy Offtake Tariff Subsidies: When the allowed end-user electricity tariffs (allowed tariff) are lower than the cost-reflective tariff as computed by the Commission, the Government undertakes to cover the resultant gap (between the cost-reflective and allowed tariff) in the form of tariff shortfall funding. In 2024, the gross subsidy obligation of the FGN was ₦1,949.17 billion (Figure D). Figure D: FGN subsidy obligation in 2024 * * * STATE OF THE INDUSTRY Operational report: The operational performance of the NESI is a measure of how effectively available resources are utilised to generate electricity. Optimum operational performance is essential to ensure adequate and safe electricity generation, transmission, and distribution. The summary of the NESI’s operational performance report for 2024 is provided below. Available Capacity and Generation: In 2024, the average daily available generation capacity of the grid-connected power plants was 4,853.69MW. The overall availability factor for all gridconnected plants was 37.43%, which indicates that more than 62% of the installed capacity in the NESI was not available in 2024\. The total generation during the year was 37,093.70GWh, which translates to an average hourly generation of 4,222.87MWh/h. Hydropower plants contributed 11,469.85GWh (30.92%) to the total generation in 2024. Indices on the Performance of the National Grid: The average lower and upper daily system frequencies of the grid in 2024 were 49.28Hz and 50.83Hz, respectively (range of 1.55Hz); these 1 values are within the stress limit specified in the Grid Code (Lower stress limit; 48.75Hz and Upper stress limit; 51.25Hz). The average lower and upper operating voltage of the grid in 2024 were 299.42kV and 352.55kV, respectively (range of 53.13kV); these values are outside the normal operating limits specified in the Grid Code (Lower limit; 313.50kV and Upper limit; 346.50kV) | | No. of Collapses | | | | | | --- | --- | --- | --- | --- | --- | | Category of Collapse | 2020 | 2021 | 2022 | 2023 | 2024 | | Partial Collapses | 0 | 2 | 2 | 0 | 5 | | Total Collapses | 4 | 2 | 4 | 3 | 4 | The NESI also recorded nine (9) incidents of system collapses in 2024\. The data for system collapse incidents between 2020 and 2024 are contained in Table E. Table E: System Collapses in 2020 - 2024 1 The normal operating range specified in the Grid Code is 49.75Hz – 50.25Hz. * * * Metering: As of 31 December 2024, only 6,288,642 (46.57%) of the registered 13,503,342 customers in the NESI were metered. DisCos installed 572,055 end-use customer meters in 2024 using the different metering frameworks as detailed in Table F. metered. DisCos installed 572,055 end-use customer meters in 2024 using the different metering frameworks as detailed in Table Table F: Meter Installations under the Metering Frameworks | S/N | Framework | Meter Installations in 2024 | | --- | --- | --- | | 1 | NMMP | 289 | | 2 | MAF | 4,076 | | 3 | MAP | 508,103 | | 4 | Vendor Financed | 27,965 | | 5 | DisCo Financed | 31,622 | | | Total | 572,055 | The summary of customer metering by respective DisCos is contained in Figure E. • Energy offtake performance of DisCos • Energy billed and billing efficiency • Revenue and collection efficiency Commercial report: The commercial performance of the NESI is a measure of the flow of funds from customers to upstream electricity industry players. The key parameters that are used in evaluating commercial performance include: • Revenue and collection efficiency * * * ## Executivs(aummary NERC Annual Report 2024 - **Remittances by downstream market participants to the** ## Market Operator (MO) and the Nigerian Bulk Electricity ## Trading Company (NBET) ## Energy offtake performance: In 2024, the total energy received ## by DisCos at their trading points was 29,126.27GWh. With the ## Commission’s effort to achieve market maturity and improved ## upstream payments, energy offtake by DisCos transitioned from **2** **the MYTO allocation to the Partial Activation of Contract (PAC)** **regime in July 2022, which enabled the DisCos to determine their** **unconstrained power requirements in absolute Megawatts (MW)** **known as their Partially Contracted Capacity (PCC).** ## The DisCos energy offtake performance in 2024 was 94.55%. All ## DisCos took less energy than their PCC, with Enugu (98.18%) and ## Benin (98.03%) recording the highest offtake performances. Yola ## (85.04%) DisCo, which is the only DisCo with offtake performance ## below 90%, recorded the lowest offtake performance during the **year.** ## Billing and Collection efficiencies: Figure F shows the billing and ## collection efficiencies by all DisCos in 2024. Out of the ## 29,126.27GWh total energy received by all DisCos, ## 23,919.68GWh was billed to the end-users, resulting in a gross ## billing efficiency of 82.12%. ## The total billing to electricity consumers by the DisCos was ₦2,196.71 billion, but only ₦1,659.76 billion was collected, **leaving an outstanding of ₦536.95 billion. This corresponds to a** **collection efficiency of 75.56%.** **2** **Under the MYTO allocation regime, the allocation of energy to DisCos was based solely on the ratios contained** **in the vesting contracts signed upon privatisation. Also, there was limited enforcement of PPA contracts which** **led to the non-recognition of capacity (and its associated payments) for most of the grid-connected power plants.** **Nigerian Electricity Regulatory Commission 9A** * * * ## Executivs(aummary NERC Annual Report 2024 **Billing Efficiency Collection Efficiency** **100%** **90%** **80%** **70%** **60%** **50%** **Efficiency** **40%** **30%** **20%** **10%** **0%** **Abuja Benin Eko Enugu Ibadan Ikeja Jos Kaduna Kano Port Yola** **Harcourt** ## Figure F: DisCos Billing and Collection Efficiencies in 2024 ## Market Remittances by DisCos: In 2024, NBET and MO issued a **3** **gross invoice of ₦1,370.35 billion to all the DisCos for energy** **costs and administrative services. DisCos remitted a gross sum of** ₦1,184.88 billion, leaving a total deficit of ₦185.47 billion. This **translates to an overall remittance performance of 86.47%** ## The disaggregated DisCo’s remittance performances to NBET and ## MO in 2024 are presented in Figure G. ## Eko, Ikeja and Abuja DisCos had the highest remittance ## performances with 99.33%, 94.43% and 90.42% respectively to ## NBET in 2024, while Kaduna achieved the lowest remittance ## performance to NBET (32.77%). The highest remittance ## performances to the MO were recorded by Yola, Ikeja, Eko and ## Abuja at 96.73%, 95.71%, 93.12% and 92.97% respectively, ## while Kaduna recorded the lowest MO remittance performance of **26.29%.** **The NBET portion of the total invoice issued to DisCos is the DisCos Remittance Obligation (DRO).** **Nigerian Electricity Regulatory Commission** * * * Figure G: DisCos’ Remittance Performance in 2024 Market Remittances by Special and Bilateral Customers: In 2024, the NESI continued to provide electricity to 3 international bilateral customers - i) Societe Beninoise d’Energie Electrique; ii) Compagnie Energie Electrique du Togo; iii) Societe Nigerienne d’electricite. Cumulatively, these 3 customers received an invoice of $56.07 million from MO and made a payment of $42.06 million. This corresponds to a remittance performance of 75.01%. There were seventeen (17) active domestic bilateral customers in 2024\. Cumulatively, these customers received a total invoice of ₦7,929.25 million from MO and made a payment of ₦5,970.85 million, corresponding to a remittance performance of 75.30%. * * * # Chapter One: Legal and Regulatory # Framework * * * # 1.1 Background to the creation of the Commission # 1.2 Regulatory Functions # 1.3 Legal Framework # 96 Reporting Obligations * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## 1.1 Background to the creation of the Commission ## Nigerian Electric Power Policy (NEPP) ## In March 2001, the Federal Government of Nigeria (FGN) released the Nigerian ## Electric Power Policy (NEPP) in an attempt to arrest the challenges that had plagued ## the electricity supply in Nigeria over the prior decades and heralded the prevalence ## of rolling blackouts to electricity consumers. These problems were caused by several ## factors, including – - **Gross inadequacy of available generation due to a lack of investments in new** ## generation plants and poor maintenance of installed plants - **Poor and aged transmission and distribution infrastructure arising from limited** ## investments and consequently driving high technical losses along the network - **Overall financial unsustainability and illiquidity of the electricity market** ## caused by a combination of non-cost reflectiveness of tariffs and extreme ## levels of commercial losses. **The NEPP was adopted in 2002 and kick-started the reform efforts of the FGN in the** **power sector which were ultimately geared towards transitioning the electricity** **market from a state-owned vertically integrated monopoly into a competitive,** **liberalised market with significant private sector participation at all steps of the value** **chain.** ## Electric Power Sector Reform Act (EPSRA) ## One of the critical milestones under the reform program of the power sector was the ## enactment of the Electric Power Sector Reform Act (EPSRA) in 2004. The EPSRA ## gave legal authority and support to the reforms and repealed the National Electric ## Power Authority (NEPA) Act of 1972. ## Nigerian Electricity Regulatory Commission * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## The National Electric Power Authority (NEPA) was transitioned to the Power Holding ## Company of Nigeria (PHCN) which was subsequently unbundled into 18 separate ## companies consisting of six (6) Generation, one (1) Transmission and eleven (11) ## Distribution companies; thereby opening the market for private sector **investment/participation.** ## Furthermore, section (31) of the EPSRA provided for the establishment of the ## Nigerian Electricity Regulatory Commission (“NERC” or the “Commission”), which ## was mandated to serve as an independent regulatory body to drive the power sector ## reform by ensuring fairness, transparency, and a level playing field for all ## stakeholders. The Commission was officially inaugurated on 31 October 2005, with ## its headquarters in Abuja. **Electric Power Sector Reform Act (2004)** **Nigerian Electricity Regulatory Commission (NERC)** **EPSRA (2004)** **Power Holding Company of Nigeria (PHCN) Unbundling** **Figure 1.1: Major reforms under the EPSRA 2004** ## Nigerian Electricity Regulatory Commission * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## Electricity Act (EA) ## In recognition of the evolution of the Nigerian electricity market following almost a ## decade of privatisation of the generation and distribution segments of the market as ## well as the need to push the market towards more efficient competition, the Electricity ## Act 2023 was enacted in June 2023. The EA 2023 repealed the EPSRA 2004 and ## the four underlisted Acts related to the Nigerian electricity market: - **The Hydroelectric Power Producing Areas Development Commission Act, No.** ## 7, 2010 - **The Hydroelectric Power Producing Areas Development Commission Act,** ## 2010 (Amendment) Act, 2013 - **The Hydroelectric Power Producing Areas Development Commission Act,** ## 2010 (Amendment) Act, 2018 - **The Nigerian Electricity Management Service Agency Act (NEMSA Act)** **2015** ## By consolidating the various Acts that previously governed the sector, the EA 2023 ## seeks to ensure legislative consistency across the various segments and stakeholders ## in the sector. In addition to recognising NERC as the apex regulator for the Nigerian ## power sector, the EA 2023 has given the Commission significantly increased ## enforcement powers. This is essential for allowing the Commission to put in place a ## robust accountability framework with adequate deterrence for all market **participants.** ## Since its inception, the Commission has continued to position itself to give robust ## regulatory interventions as the power sector transitions from a state-owned ## monopoly to a more competitive market structure. The various reforms that sought ## to bring competition and consequently improved service delivery in NESI since 2005 ## are highlighted in Figure 1.2. ## Nigerian Electricity Regulatory Commission * * * Figure 1.2: Highlights of Reforms in the NESI (2005 – 2024) * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## 1.2 Regulatory Functions ## The principal functions of the Commission as outlined under section 34(1) of the EA ## are as follows - ## A. To create, promote, and preserve efficient electricity industry and market ## structures, and ensure the optimal utilisation of resources for the provision of ## electricity services ## B. To maximise access to electricity services by promoting and facilitating ## consumer connections to distribution systems in both rural and urban areas ## C. To ensure that an adequate supply of electricity is available to consumers ## D. To ensure that the prices charged by licensees are fair to consumers and are ## sufficient to allow the licensees to finance their activities and to allow for ## reasonable earnings for efficient operation ## E. To ensure the safety, security, reliability, and quality of service in the ## production and delivery of electricity to consumers ## F. To ensure that regulation is fair and balanced for licensees, consumers, ## investors, and other stakeholders ## G. To present quarterly reports to the President and National Assembly on its **activities** **H. To issue directives and carry out such measures to ensure the gradual** ## development and smooth operation of the various stages of the market ## I. To promote the development and utilisation of renewable energy services and ## increase the contribution of renewable energy in Nigeria’s energy mix ## J. To promote cost-reflective and service-reflective tariffs and ensure gradual ## elimination of cross subsidies within a specified timeframe; and ## Nigerian Electricity Regulatory Commission * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## K. To promote gender mainstreaming and local content requirements within the **NESI** ## 1.3 Legal Framework ## To enable the Commission to achieve its core functions, the EA 2023 has conferred ## various powers on the Commission which are summarised below: ## A. Licensing: Section 34(2)(d) of the EA empowers the Commission to licence ## and regulate persons engaged in the generation, transmission, system ## operation, distribution, supply and trading of electricity. ## B. Enforcement and Sanctioning: Sections (63 and 64) of the EA describe the ## conditions of licences and the Commission's power to regulate the activities ## of its licensees. The Commission is empowered with the legal authority to ## inquire into the activities of a person engaging or seeking to engage in any ## of the activities requiring a licence as defined in the EA. The Commission is ## also authorised to probe violations and impose penalties (including fines, ## imprisonment, forfeiture of undertakings as well as licence cancellation) on ## any licensee who contravenes the terms and conditions of its licences. ## C. Generation of Electricity: Section (80) of the EA 2023 directs the Commission ## to promote electricity generation from renewable energy sources. In granting ## licences, the Commission is mandated to promote embedded generation, ## hybridised generation, co-generation, and electricity generation from ## renewable sources such as solar energy, wind, small hydro, biomass and ## other renewable sources. ## D. Transmission of Electricity: Sections (108 -112) of the Act mandate the ## Commission to oversee electricity transmission in the NESI. In addition to ## specifying the demarcation of the National Control Centre, the Act also ## Nigerian Electricity Regulatory Commission :A * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## specifies the Commission’s powers with respect to third-party investment in the ## national grid as well as independent transmission network operators. The ## Commission is granted clear powers with respect to its role in ensuring the ## economic viability of investments. ## E. Distribution and Supply of Electricity: Sections (113 – 115) of the Act ## mandate the Commission to oversee the Distribution and Supply of Electricity ## in the NESI. Section 113(2) empowers the Commission to conduct biennial ## reviews of distribution licensees, ensuring power source adequacy, ## distribution system maintenance, and effective consumer complaint resolution. ## With respect to Distribution/Supply, the Commission only retains the powers ## conferred by Sections (113-115) pending the establishment of State Electricity ## Regulators (SERCs). Pursuant to the amendment of the constitution, Section ## 230(2) of the EA provides the process for NERC to transfer regulatory ## oversight of intra-state electricity matters to the States of the Federation upon ## the creation of their own electricity market and State electricity regulatory **4** **authority. With the exception of a few instances , electricity distribution** **operates entirely on an intra-state basis, which means that upon the expiration** **of the 180-day transition period provided in the EA, NERC no longer has** **regulatory powers over electricity distribution within any State that has passed** **its electricity law.** **F. Tariffs and Subsidies: The Commission is mandated to oversee tariff regulation** ## and subsidy management in accordance with Sections (116) and (117) of the ## Act, ensuring that licensees operate efficiently and recover their full costs with ## a reasonable return on investment. The activities subject to tariff regulation as **4** **When there is a distribution line crossing state lines, the respective distribution companies are required to install** **boundary meters to measure the volume of electricity trade happening within each state.** ## Nigerian Electricity Regulatory Commission * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## enshrined in the Act include generation, trading, transmission, distribution , ## supply, and system operations. **6** **G. Consumer Protection and Licensee Performance Standards : Sections (119 -** ## 120) of the Act mandate the Commission to develop various consumer ## standards and procedures in collaboration with licensees. These include ## customer service standards, quality of service and supply standards, customer ## complaint handling procedures, assistance procedures for customers facing ## bill payment difficulties, procedures for disconnecting non-paying customers, ## procedures for responding to emergencies, etc. ## H. Competition and Market Power: The Commission plays a pivotal role in ## overseeing competition and market power within the NESI, as outlined in ## Section (121) of the Act. The Commission is mandated to report to the Minister ## of Power, on an annual basis, on the industry's potential for additional ## competition. The Commission is also mandated to prevent the abuse of market ## power through various decision-making processes such as the grant of ## licences, pricing, and approval of mergers or affiliations. In case of identified ## market power abuses, the Commission is empowered to undertake ## enforcement actions such as issuing cease orders and levying fines as it deems **appropriate.** **I. Renewable Energy and Energy Efficiency: Sections (164 - 171) of the Act** ## empower the Commission to actively support and regulate the development **5** **As explained above, the Commission’s oversight of distribution is limited to States that are yet to pass their** **electricity laws. If the Federal Government commits to providing a universal subsidy scheme across all states,** **e.g. PCAF, the Commission may be engaged as the administrator based on the provisions of the EA.** **6** **As explained above, the Commission’s oversight of distribution is limited to States that are yet to pass their** **electricity laws. Consumer protection is a sub-activity within distribution, so once a state takes over regulatory** **oversight of its intrastate electricity market, it will set the consumer protection protocols within the state.** ## Nigerian Electricity Regulatory Commission * * * ## Legal and Regulatory Framework NERC Annual Report 2024 ## and utilisation of renewable energy through measures, including the ## simplification of licensing procedures, issuance of regulations, and ## establishment of technical standards. ## 1.4 Reporting Obligations ## 1.4.1 Quarterly Reports ## Pursuant to Section 34(1)(g) of the EA, which states that - “the Commission shall ## present quarterly reports to the President and the National Assembly on its ## activities”, the Commission has published its four (4) quarterly reports for 2024. The ## reports contain analyses of the state of the Nigerian electricity industry (covering ## both the operational and commercial indices), regulatory functions, and consumer **affairs.** ## 1.4.2. Financial Reports ## The financial activities of the Commission and the associated reporting requirements ## are governed by sections 56(1) and 56(2) of the EA 2023. Section 56(1) stipulates ## that “the Commission shall ensure that proper accounts and other records relating ## to such accounts are kept in respect of all the Commission's activities, funds and ## property, including such particular accounts and records as the Minister may ## require”. Section 56(2) of the EA states that “the Commission shall, not later than ## three months, after the end of the financial year, prepare and submit to the Auditor ## General of the Federation and National Assembly, a statement of accounts in ## respect of that financial year.” ## In compliance with the provisions above, the Commission engaged KPMG to audit ## the Commission's accounts for the year that ended on 31 December 2024. The ## audited statements of the report for 2024 are provided in Chapter 8. ## Nigerian Electricity Regulatory Commission * * * # Chapter Two: Human Resource # Management * * * 2.1 Board of Commissioners 2.2 Management Staff 2.3 aecretary of the Commission 2.4 Forum Ofqs(aecretaries 2.5 ataff Composition 2.6 Capacity Development 2.7 Promotion, Awards and Retirement * * * ## Human Resource Management NERC Annual Report 2024 ## 2.1 Board of Commissioners ## Nigerian Electricity Regulatory Commission * * * ## Human Resource Management NERC Annual Report 2024 ## Nigerian Electricity Regulatory Commission * * * 2.2 Management Staff The Management cadre for staff of the Commission is composed of the General Manager (GM), Deputy General Manager (DGM), and Assistant General Manager (AGM) levels. The GM is the highest attainable for full time staff of the Commission. GMs (or the most senior staff) usually act as the administrative heads of the division and work closely with the Commissioners, who provide executive oversight to the Division. In a Commissioner’s absence, the designated division head may take over some of the executive responsibilities of the Commissioner. As of 31 December 2024, the Commission had a total of thirty-seven (37) staff in the management cadre- GM: 4, DGM: 8, AGM: 25. Table 2.1: General Managers of the Commission as of December 2024 | S/N | Name | Designation | Date Appointed | | --- | --- | --- | --- | | 1 | Dr Usman Abba-Arabi mni | GM, Public Affairs, Chairman's Office(CO) | 01 January 2018 | | 2 | Abdulkadir B. Shettima | GM, Consumer Affairs | 01 January 2018 | | 3 | Zubairu T. Ahmadu | GM, Legal Licencing & Compliance (LLC) | 01 January 2021 | | 4 | Maryam Y. Abubakar(Mrs) | GM, Finance and Management Services(FMS) | 01 January 2021 | Table 2.2: Other Management Staff of the Commission | S/N | Name | Position | Unit and Division | | --- | --- | --- | --- | | 1 | Ada Ozoemena | DGM | Chairman's Office | | 2 | Abba I. Terab | DGM | Tariff & Rates, MCR | | 3 | Abdussalam Yusuf | DGM | Research, PRS | | 4 | Abdullah Adamu | DGM | ICT, FMS | | 5 | Sule Friday E. | DGM | Human Resources, FMS | | 6 | Hafsat Abdullahi Mustafa | DGM | Public Affairs, CO | | 7 | Hauwa Yakubu | DGM | Compliance, LLC | | 8 | Abu Kadiri | DGM | Engineering&Standards,EPM | | 9 | Arit Uya | AGM | Licensing,LLC | | 10 | Michael Faloseyi | AGM | Public Affairs,CO | | 11 | Kanneng Gwon | AGM | Human Resources,FMS | | 12 | Zubair B.Zubair | AGM | Consumer Affairs,CA | | 13 | Ene Effiom | AGM | Consumer Complaints,CA | * * * Human Resource Management | 14 | John D. Joseph | AGM | Engineering & Standards, EPM | | --- | --- | --- | --- | | 15 | Jonathan Okoronkwo | AGM | Health, Safety & Environment, EPM | | 16 | Mary Anahve | AGM | Public Affairs, CO | | 17 | Rasheed Busari | AGM | General Administration, FMS | | 18 | Habib Kidaji | AGM | Corporate Planning & Strategy, PRS | | 19 | Saidu Lawal | AGM | Customer Complaints, CA | | 20 | Regina Osuagwu | AGM | Consumer Affairs, CA | | 21 | Umar Mohammed | AGM | Renewable & DMU, PRS | | 22 | Emeka Onyegbule | AGM | Market Competition and Rates | | 23 | Ahmed Ndanusa | AGM | Chairman's Office, CO | | 24 | Anthony Essien | AGM | Consumer Affairs, CA | | 25 | Okpale Daisy | AGM | Licensing, LLC | | 26 | Imam Mohammed | AGM | Health, Safety & Environment, EPM | | 27 | Ntui Colombus | AGM | Legal, Licencing & Compliance | | 28 | Bala Ado Shehu | AGM | Finance and Accounts, FMS | | 29 | Iloeje Chukwuemeka | AGM | ICT, FMS | | 30 | Azikiwe Chigozie V | AGM | Market Analysis, MCR | | 31 | Ebehijele Edeh | AGM | RFRA, MCR | | 32 | Mary-Anne Oragunye | AGM | Finance and Accounts, FMS | | 33 | Pius Bako | AGM | Consumer Affairs, CA | 2.3 Secretary of the Commission Pursuant to sections 43(9) and 44(1) of the 2023 Customer Protection Regulation (CPR 2023), the Commission operated twenty-seven (27) forum offices across the Country as of 31 December 2024. Forum offices are intended to provide redress for customers in instances where their complaints are not satisfactorily addressed at the DisCo Customer Complaint Unit (DisCo-CCU). Each Forum Office is managed by the forum secretary, while the hearings are conducted by five (5) forum panel Ada Ozoemena (Mrs) DGM, Secretariat, CO 2.4 Forum Office Secretaries * * * ## Human Resource Management NERC Annual Report 2024 ## members who are not staff of the Commission, pursuant to the provisions of the CPR ## 2023\. The list of the Commission’s forum secretaries as of 31 December 2024 is ## contained in Appendix A.1. ## 2.5 Staff Composition ## The total manpower of the Commission in 2024 was two hundred and fifty-four (254) ## persons, inclusive of the seven (7) commissioners. The Commissioners and members ## of staff are experienced professionals from diverse backgrounds and disciplines ## ranging from Engineering, Law, Sciences, Economics, Accounting and Finance, ## amongst others. The detailed distribution of staff by Division, cadre and gender is ## presented in the sections below: ## 2.5.1 Distribution by Division ## The distribution of staff in the year across the different Divisions is presented in Table ## 2.3. The Finance & Management Services Division had the highest number of staff- ## sixty-five (65), representing 26.32% of the total Commission’s staff, while the ## Planning, Research & Strategy Division only represented 6.48% of the Commission’s ## staff strength-sixteen (16) staff. **7** **The composition of the forum panel is as follows:** **1\. A legal practitioner with experience in alternative dispute resolution nominated by the Nigerian Bar** **Association (NBA).** **2\. A financial expert nominated by either the Manufacturers Association of Nigeria, Nigerian Association** **of Chambers of Commerce, Industry, Mines and Agriculture (NACCIMA) or any other reputable** **organisation.** **3\. A qualified electrical engineer nominated by either the Council for Regulation of Engineering in Nigeria** **(COREN) or the Nigerian Society of Engineers (NSE).** **4\. A nominee of the Federal Competition and Consumer Protection Commission (FCCPC).** **5\. A representative of an NGO based in the distribution company’s operating area nominated by the** **Commission.** ## Nigerian Electricity Regulatory Commission;A * * * Table 2.3: Distribution of the Commission’s Staff by Divisions in 2024 | S/N | Divisions | Number of Staff | Percentage Share | | --- | --- | --- | --- | | 1 | Chairman's Office | 31 | 13% | | 2 | Consumer Affairs | 61 | 25% | | 3 | Engineering, Performance & Monitoring | 22 | 9% | | 4 | Finance&Management Services | 65 | 26% | | 5 | Legal,Licensing&Compliance | 28 | 11% | | 6 | Market,Competition&Rates | 24 | 10% | | 7 | Planning,Research&Strategy | 16 | 6% | | | Total | 247 | 100% | Note: 1. The staff distribution excludes the seven Commissioners and their aides 2.5.2 Distribution by Cadre The distribution of staff by cadre as of 31 December 2024 is presented in Table 2.4. The Commission had thirty-seven (37) management staff, one hundred and thirtyeight (138) mid-management staff, fifty (50) senior staff and twenty-two (22) junior staff, representing 15%, 56%, 20% and 9%, respectively, of the total staff count. Table 2.4: Distribution of the Commission’s Staff by Cadre in 2024 | S/N | Position | Number of Staff | Cadre | Total Number of Staff | Percentage Share | | --- | --- | --- | --- | --- | --- | | 1 | General Manager | 4 | Management Staff | 37 | 15% | | 2 | Deputy General Manager | 8 | | | | | 3 | Assistant General Manager | 24 | | | | | 4 | Principal Manager | 33 | Mid-management staff | 138 | 56% | | 5 | Senior Manager | 39 | | | | | 6 | Manager | 34 | | | | | 7 | Assistant Manager | 32 | Senior Staff | 50 | 20% | | 8 | Analyst I | 31 | | | | | 9 | Analyst II | 19 | | | | | 10 | Junior Staff | 22 | Junior Staff | 22 | 9% | | | Total | 247 | All | 247 | 100% | Note: The staff distribution excludes the seven Commissioners and their Aides * * * ## Human Resource Management NERC Annual Report 2024 ## 2.5.3 Distribution by Gender ## The distribution of staff by gender as of 31 December 2024, as illustrated in Figure ## 2.1 shows that approximately 31% of the professional workforce of the Commission ## is female, which aligns with the Commission’s commitment to gender balance. **Figure 2.1: Distribution of the Commission’s Staff by Gender in 2024** ## 2.6 Capacity Development ## The Commission places a high premium on the capacity development of its staff as ## it recognises that the quality of personnel impacts significantly on the quality of its ## operations and activities. In 2024, the Commission continued the implementation of ## its capacity-building strategy by providing training to staff based on skill gaps. Staff ## were also sponsored to attend workshops, conferences, and meetings on issues ## pertinent to the discharge of the Commission’s functions. ## Members of staff of the Commission were sponsored to attend annual conferences ## of their respective professional bodies which included the CIPM- Chartered Institute ## of Personnel Management of Nigeria, NIPR- Nigerian Institute of Public Relations, ## NIM- Nigerian Institute of Management, ICAN- Institute of Chartered Accountants ## Nigerian Electricity Regulatory Commission * * * ## Human Resource Management NERC Annual Report 2024 ## of Nigeria, ANAN- Association of National Accountants of Nigeria, NSE- Nigerian ## Society of Engineers and the NBA- Nigerian Bar Association. ## 2.7 Promotion, Awards and Retirement ## In pursuit of a merit-based work environment that incentivises excellence among its ## staff, the Commission conducts transparent promotion exercises annually for eligible **staff based on the provisions of the “Conditions of Service”. At the end of the 2024** **exercise, staff who satisfied the stipulated requirements were duly promoted.** ## The Commission also held an award ceremony to recognise staff who had exhibited ## excellence in the delivery of their duties. Long-service awards were also presented ## to staff who had achieved notable milestones in the number of years of meritorious ## service they have delivered to the Commission. ## Over the course of 2024, six (6) people exited the services of the Commission– five ## (5) retirements and one (1) resignation. ## Nigerian Electricity Regulatory Commission * * * # Chapter Three: Corporate Governance * * * # 3.1 Structure of the Commission # 3.2 NERC Strategic Plan 2024-28:A(0aP-III) # 3.3 Highlights of the Commission’s activities in 2024 * * * ## Corporate Governance NERC Annual Report 2024 ## 3.1 Structure of the Commission ## The Commission maintained the same core organisational structure as of 2023, with ## seven (7) divisions and 24 units. ## Nigerian Electricity Regulatory Commission * * * ## Corporate Governance NERC Annual Report 2024 ## This structure has been put in place to enhance the adequate flow of responsibility ## and authority along functional lines and staffing with professionally qualified ## personnel with the requisite skills and experiences to carry out their functions **appropriately.** ## The current organisational structure of the Commission is represented in Figure 3.1. ## Each unit is tasked with unique roles and responsibilities that culminate in divisional ## functions to drive the actualisation of the Commission’s goals. ## Nigerian Electricity Regulatory Commission * * * Corporate Governance Figure 3.1: Structure of the Commission as of December 2024 Nigerian Electricity Regulatory Commission * * * ## Corporate Governance NERC Annual Report 2024 ## 3.2 NERC Strategic Plan 2024-2026 (SP-III) **The Strategic Plan III (SP3) sets out the high-level aspirations for the NESI as well as** **the role of NERC in their attainment for the years 2024 – 2026. While also building** **upon the progress recorded under the SP II (2021 – 2023), the SP III takes particular** **cognisance of the major shifts expected in the NESI arising from the amendment of** **the 1999 constitution and the provisions of the EA 2023. The six (6) strategic pillars** **that underpin the SP III are summarised below:** ## 1\. Commercially viable electricity market: Improve liquidity, enable a cost- ## reflective electricity market, efficient subsidy management and reasonable ## returns on investments. ## 2\. Technically robust infrastructure: Ensure the quality, integrity and adequacy ## of infrastructure across all spectrum of the market. ## 3\. Market Development & Customer Satisfaction: Ensure increased access and ## availability of electricity through the promotion of innovation, customer ## satisfaction and effective energy supply approaches and enabling the ## diversity and efficacy of the energy mix. ## 4\. Industry governance and coordination: Collaborate with stakeholders across ## the NESI to ensure a collaborative and impactful development of the ## electricity sector and drive the implementation of the EA 2023. ## 5\. Compliance & Enforcement: Enforce compliance with technical and ## commercial standards. ## 6\. Operational Excellence: Optimise processes, technology and capabilities and ## adopt an agile operating model to become a performance-driven **organisation.** **The initiatives for each of the pillars are highlighted in Figure 3.2. For the year 2024,** **the strategic plan focused on strengthening NERC’s corporate capacity to ensure** **that the Commission is well placed to lead the sectoral reforms which the SP III seeks** **to achieve.** **Nigerian Electricity Regulatory Commission** * * * Figure 3.2: NERC Strategic Plan (SP-III) * * * 3.3 Highlights of the Commission’s activities in 2024 At all times, the Commission’s activities are guided by the provisions of EA 2023, the 2024 -2026 strategic plan as well as overarching government policy and macroeconomic trends. To this end, highlights of some of the Commission’s activities for the year 2024 are summarised below - At all times, the Commission’s activities are guided by the provisions of EA 2023, 2026 strategic plan as well as overarching government policy and macroeconomic trends. To this end, highlights of some of the Commission’s activities for the year 2024 are summarised below - A. Regulatory Instruments/Interventions: In 2024, the Commission issued 397 regulatory instruments, as detailed in Table 3.1. Pursuant to its quasi-judicial mandate as provided in the EA 2023, the Commission also carried out 18 hearings during the year. A. Regulatory Instruments/Interventions: In 2024, the Commission issued 397 regulatory instruments, as detailed in Table 3.1. Pursuant to its quasi-judicial mandate as provided in the EA 2023, the Commission also carried out 18 Table 3.1: Regulatory Instruments issued by the Commission in 2024 | SN | Regulatory Instruments | Number | | --- | --- | --- | | 1 | Regulations | 2 | | 2 | Orders | 167 | | 3 | Licences/Permits | 168 | | 4 | Rectification Directives | 28 | | 5 | Notice to Commence Enforcement Action | 29 | | 6 | Fines | 3 | | | Total | 397 | B. External stakeholder engagement: The Commission is committed to ensuring that stakeholders of the NESI are kept abreast of key initiatives of the Commission as well as performance standards for licensees in the NESI. In 2024, the Commission undertook targeted campaigns through traditional and social media channels covering pertinent industry issues, including capping of estimated bills, power sector recovery program, metering, health & safety as well as consumer rights and obligations. The Commission also engaged power sector policymakers and relevant civil society organisations in capacity development. The external stakeholder engagements conducted by the Commission during 2024 include: * * * ## Corporate Governance NERC Annual Report 2024 ## ii. Quarterly NESI meetings – x4 ## iii. Seminar in collaboration with the National Judicial Institute (NJI) ## for justices of the Supreme Court and the Court of Appeal ## iv. Engagement with the staff of the Federal Competition and ## Consumer Protection Commission (FCCPC), the Nigerian Bar ## Association (NBA), and the Nigerian Data Protection Commission **(NDPC)** **v. Peer review meetings with regulatory compliance officers of** **licensees** ## vi. Radio jingles and social media campaigns ## C. Upholding customer care standards and Protection: In 2024, the Commission ## carried out critical activities towards ensuring effective consumer protection ## and engagement. These include: ## i. Customer Education/Town Hall meetings in nine (9) states of the **federation** **ii. Training of Forum members in April 2024, aimed at enhancing** **members' capacity in handling consumer disputes.** **iii. An experiential Peer Review and Capacity Building Workshop for** **Key Customer Service Staff of DisCos held in Jos, Plateau state,** **from 16 to 17 May 2024, to foster knowledge sharing and capacity** **building among stakeholders.** **iv. The annual Commission Essay Competition and award ceremony** **for secondary school students aimed at promoting consumer rights** **awareness and engagement.** **D. Improving health/safety and technical robustness of the grid system: Some of** ## the key activities implemented during the year include – ## i. Facilitation of IoT metering of all 33kV and 11kV feeders in the **NESI.** ## Nigerian Electricity Regulatory Commission * * * ii. The establishment of the baseline status of the deployment of Advanced Metering Infrastructure (AMI) and integration of modules into the DisCos’ operations. iii. Completion of the technical audit of the interconnected transmission and distribution system. iv. Integration of technical standards for renewable energy-based power generation in the revised Nigerian Electricity Supply and Installations Standards (NESIS) Regulations. v. Completion of the emergency review of the Grid Code. vi. Development of guidelines for conducting safety audits by licensees in the NESI. E. Enhanced transparency and stakeholder involvement: Pursuant to the provisions of the EA 2023 and NERC Regulations on the Procedure of Electricity Tariff Reviews in the NESI 2014, in evaluating the tariff review applications made by DisCos, the Commission introduced the rate-case hearings. This is consistent with international best practice in rate-setting and provides a platform for customers, customer advocacy groups and intervenors (industry experts and representatives of established organisations related to the power sector) to interrogate the submissions made by the DisCos in support of their applications. Following a formal application for a review of its allowed tariffs, the Commission conducted a rate case hearing for Aba Power Limited Electric (APL) in December 2024. * * * # Chapter Four: Regulation, Licensing & # Compliance * * * 69 Regulations, Orders and Directives 4.2 Regulations 4.3 Orders 6 Directives 4.5 Licensing 6A Permits and Certificates 6B Compliance Monitoring and Enforcement 4.8 Hearings and Alternative Dispute Resolution among Market Participants * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## 4.1 Regulations, Orders and Directives ## Section 34 of the Electricity Act 2023 (EA 2023, the Act) 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 Nigerian Electricity Supply ## Industry (NESI) through selected regulatory instruments as prescribed by law. The ## regulatory instruments utilised by the Commission include – ## A. Regulations: these 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. ## B. Orders: these 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. ## C. Licences: these 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. ## D. Permits: these 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 * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## E. Guidelines: these are advisory documents, instructions, or rules issued by the ## Commission pursuant to sections 64 and 215 of the Electricity Act, that ## recommend practices and standards to sector participants, and licensees on **the procedure or process for a thing or an activity to be done or carried out** **to achieve best practices and maintain consistency in operations.** **F. Directives: these are enforceable orders 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. ## G. Rules: these are binding principles, instructions, and directives issued by the ## Commission pursuant to sections 10, 64, and 215 of the Electricity Act, that ## outline mandatory procedures, requirements, and standards for sector ## participants and or licensees which must be adhered to. ## H. Codes: these are comprehensive sets of rules, principles, guidelines and ## technical standards issued or approved by the Commission pursuant to ## sections 10, 34(2)(b), 64 and 215 of the Electricity Act, governing various ## aspects of the electricity sector, including safety, reliability, and performance, ## ensuring uniformity and high standards in technical and operational practices ## across the sector. ## In issuing regulatory instruments to licensees, the Commission is guided by the ## provisions of the EA 2023, NERC business rules regulation (NERC-R-0306) and ## other extant rules. Regulatory instruments are used to steer the NESI in the direction ## of overarching government policy, taking due cognisance of the changes in the ## macroeconomic environment. ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## 4.2 Regulations ## Section 227 of the EA 2023 empowers the Commission to “make regulations ## prescribing all matters which by this Act are required or permitted to be prescribed ## or which, in the opinion of the Commission, are necessary or convenient to be **prescribed for carrying out or giving effect to the Act”. Regulations are a set of rules** **that the Commission may issue periodically to optimise the performance of licensees** **to give effect to the object of the EA 2023. The Commission issued two (2) new** **regulations in 2024, as summarised below:** ## A. The Eligible Customer Regulations 2024. ## B. The NERC Regulations on the Procedure for Electricity Tariff Reviews 2024. ## A. NERC-R-001-2024: The Eligible Customer Regulations 2024 (ECR) was issued in ## March 2024 and repealed the Eligible Customer Regulations 2017. The highlight of ## the changes contained in the new Regulation is contained below: ## a. Unification of the ECR and the Competition Transition Charge (CTC) ## Guidelines: The ECR and the CTC guidelines have been unified into a ## single document for ease of reference and information retrieval. ## b. Revised Threshold for Eligibility: The minimum consumption threshold to ## qualify as a prospective eligible customer has been reviewed from ## 2MWh/h to 6MWh/h-20MWh/h, depending on the class of eligible ## customer. The 5 classes of eligible customers along with their respective ## consumption thresholds are: ## i. Point-to-Point Connection (6MWh/h) ## ii. New Connection to 33kV Network (10MWh/h) ## iii. Existing DisCo’s Customer Transitioning to Eligibility **(10MWh/h)** ## Nigerian Electricity Regulatory Commission * * * iv. Existing Customer Connected to Transmission Network (20MWh/h) v. New Connection to Transmission Network (20MWh/h) c. Under the new ECR, the CTC will now be calculated as the difference between the actual tariff payable by the potential EC under the prevalent MYTO Order and the approved weighted end-user tariff of the DisCo until the time when there is a major tariff review for the DisCo to reset key MYTO parameters. CTC/kWh Actual tariff payable by the EC applicant – (Weighted average tariff for Non-MD customers of the DisCo x Collection efficiency for the DisCo’s Non-MD customers) The monthly amount payable as CTC shall be computed as CTC/kWh multiplied by the average monthly energy billed to the customer during the 90 days (i.e., 3 months) preceding the application. d. Revision of the EC application process: The stages in the application for eligible customers have been reviewed to ensure the sequence of application conforms with market norms. The new processes also sought to reduce the administrative costs for the applicants until the project is cleared to have met critical requirements. As part of this, the execution of a market participation agreement between the prospective eligible customer and the market operator has been made a condition subsequent (post-approval documentation) for an eligible customer after the permit has been granted by the Commission. The revised stages of eligible customer application are: i. Eligibility Status (Pre-approval) requirements * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## ii. Eligibility Approval requirements ## iii. Post-Approval documentation ## e. Confirmation of Non-Indebtedness: The DisCo serving an applicant for ## eligibility status has now been mandated to respond to an official request ## for a letter of non-indebtedness within 21 working days. If the DisCo fails ## to respond within the timeline, the EC applicant shall be deemed not to be ## indebted to the DisCo by the Commission. ## f. Redefinition of voltage threshold for qualification as EC: Customers ## supplied by 11kV lines are no longer eligible for an EC permit. The phase ## II of the ECR implementation which seeks to allow a customer or group of ## end users whose consumption is more than 2MWh/h over a month, and ## connected to a metered 11kV delivery point, to apply for an EC permit ## has been expunged. This is primarily because the minimum threshold for ## eligible customers has been revised to 6MWh/h and the maximum load ## on an 11kV line is 5MW; hence, an eligible customer cannot be supplied ## by an 11kV line. ## B. NERC-R-002-2024: The NERC Regulation on the Procedure for Electricity Tariff ## Reviews 2024 was issued in September 2024. The objectives of the regulations **include:** **i. Provide detailed procedures for conducting electricity tariff reviews in** ## Nigeria in line with the provisions of the EA and MYTO methodology ## ii. Provide clarity on the responsibilities of parties regarding the tariff review ## processes, filing arrangements, timelines, fees and documentation ## required for the tariff review process in the NESI. ## The regulation seeks to establish clear procedures and timelines for electricity tariff ## reviews and ensure that the commercials of the NESI are predictable for both ## Nigerian Electricity Regulatory Commission * * * investors and electricity consumers. The regulation specifies three (3) types of tariff reviews in the NESI, each serving a unique purpose. The types of tariff reviews include: i. Minor review or other short period the Commission may determine: This is conducted monthly or other shorter periods as may be determined by the Commission. Minor reviews seek to adjust tariffs to accommodate major changes in macroeconomic indices and other tariff review parameters, including generation fuel costs, inflation rates, and exchange rate fluctuations. This is to ensure that tariffs remain reflective of prevailing economic conditions without undergoing a comprehensive tariff review. ii. Major review: The MYTO methodology provides for a major review of electricity tariffs every five (5) years, where all tariff assumptions are subject to a comprehensive review in a bid to ensure the viability and efficiency of the NESI. This includes a review of operational costs, capital expenditure, and efficiency levels of licensees. iii. Extra-Ordinary review: This is an unscheduled review prompted by events that substantially impact the operations of licensees such as natural disasters, economic crises/recession, significant policy shifts, etc. 4.3 Orders A. NERC/2024/001 — Order on the Regulatory Intervention in Kaduna Electricity Distribution Plc. The Order became effective on 01 January 2024 and sought to; Orders are a series of directions/instructions that the Commission issues to licensees to perform certain actions or desist from acting in a particular manner. Orders issued to licensees are situational and immediate in their impact and compliance. The Commission issued one hundred and sixty-seven (167) Orders to licensees in 2024. The summary of the Orders issued by the Commission in 2024 is provided below: * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## i. Intervene in Kaduna DisCo’s pervasive failure and non-performance. ## ii. Dissolve the board of directors of Kaduna DisCo pursuant to section ## 75(2)(a) of the EA 2023. ## iii. Appoint an administrator and special directors to manage the affairs ## of Kaduna DisCo pursuant to section 75(2)(a) of the EA. ## iv. Invoke the powers conferred on the Commission for the sale of the ## undertaking on the basis of the highest and best price offered for the **undertaking.** ## Prior to the issuance of the Order, Kaduna DisCo had consistently failed to ## meet its obligations to the market in contravention of the EA 2023 as well as ## the terms and conditions of its electricity distribution licence issued by the ## Commission. The Commission had several engagements with the ## management, board and shareholders of Kaduna DisCo to address the ## utility’s failing performance, but these meetings did not yield improvements in ## the performance of the DisCo. ## In addition, the Chief Finance Officer of Kaduna DisCo confirmed via a letter **to the Commission that the utility was not in a position to comply with the basic** **market requirement of providing a bank guarantee in favour of NBET in** **compliance with the Market Rules and subsisting Orders of the Commission.** **Consequently, pursuant to Section 75 of the EA 2023, all directors of Kaduna** **DisCo were removed from office, and the board of directors dissolved. A new** **administrator was appointed by the Commission who shall be responsible for** **the management of the day-to-day affairs of the Kaduna DisCo pending the** **finalisation of the sale of 60% of the shares in the undertaking to a new core** **investor.** ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## B. NERC/2023/023 – NERC/2023/033 — Multi-Year Tariff Order (MYTO) 2024 ## for the Distribution Companies (11 Orders issued to 11 DisCos). The Orders ## became effective on 01 January 2024 and sought to; ## i. Ensure that prices charged by DisCos are fair to customers and are ## sufficient to allow DisCos to fully recover the efficient cost of operation, ## including a reasonable return on the capital invested in the business in ## accordance with Section 116 of the EA. ## ii. Reset industry parameters and performance obligations to incentivise the ## improvement of efficiency and service experience of electricity **consumers.** **iii. Ensure sustained improvement in meter deployment and quality of supply** **in line with the DisCos’ proposal and service improvement commitment.** **iv. Ensure that tariffs payable by customers are commensurate and aligned** **with the quality and availability of power supply committed to customer** **clusters by the DisCos.** **v. Provide a framework for the settlement of imbalances between TCN and** ## DisCos on delivery and off-take of available energy in accordance with ## the Market Rules, Vesting Contracts and other industry documents. ## vi. Support payment securitisation of market contracts and market discipline. ## vii. Support transition to bilateral contracts and procurement of bulk energy ## to meet the supply needs of customers. ## A major change under these Orders was the increase in the frequency of minor ## tariff reviews from half-yearly (every 6 months) to monthly. This transition was ## necessitated by the need for near real-time adjustment of macro-economic indices ## in tariff determination, thereby minimising the risk of financial imbalances across ## the NESI value chain over extended periods. Consequently, starting March ## Nigerian Electricity Regulatory Commission * * * 2024, the Commission issued monthly MYTO supplementary Orders to the DisCo 8 to adjust their tariffs in response to changes in macroeconomic indices . C. NERC/2023/034 — Multi-Year Tariff Order (MYTO) 2024 for the Transmission Company of Nigeria Plc. The Order became effective on the 1st of January 2024 and has the following objectives; i. Ensure sustained improvement in service delivery through the implementation of the performance improvement plan of the TCN for 2024-2027. ii. Ensure that prices charged by the TCN are fair to customers and are sufficient to allow TCN to recover the efficient cost of operation, including a reasonable return on the capital invested in the business in line with Section 116 of the EA. iii. Provide appropriate incentives towards ensuring continuous improvement in the TCN’s performance in reducing network losses. iv. Steer the market to gradually transition to cost-reflective tariffs and activate market contracts in line with the requirements of the Market Rules. v. Reaffirm the obligation of the System Operation Division of the TCN to comply with the economic merit order dispatch prescribed in this Order. vi. Reaffirm the obligation of the Transmission System Provider under the TCN for the payment of generation capacity charge and loss of revenue 8 The Commission issued a total of one hundred and ten (110) MYTO Supplementary Orders to DisCos in 2024. The Orders sought to reflect the changes in the pass-through indices (not within the control of licensees) including inflation rates, NGN/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff. However, 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 any change in their tariffs between May and July 2024. Furthermore, all end-use customer tariffs remained unchanged between July and December 2024 in line with 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. * * * to DisCos based on the deviation between energy delivered to a DisCo and the MYTO allocation from the TCN’s inability to deliver power to the affected DisCo. vii. Reaffirm the obligation of DisCos for the payment of lost revenue in favour of the TCN in line with the provisions of the executed service agreement. D. NERC/2023/035 — Order on Performance Improvement Plan of the Transmission Company of Nigeria. The Order became effective on 01 January 2024 and sought to approve a performance improvement plan for the TCN to undertake the needed interventions towards the improvement of network performance requirements in alignment with the current and future energy demands of the NESI. Over the period 2024 – 2026, the proposed interventions were developed to achieve the following; i. Efficient dispatch of generation and reduced transmission losses ii. Complete short- and medium-term system visibility iv. Improve network reliability and frequency control v. Improve the meter management system vi. Improve long-term network visibility, communication and SCADA vii. Enhance network protection systems ix. Empower employees with quality training and competitive remuneration. viii. Improve grid safety and security * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## i. Reduce transmission loss factor to 6.50% in 2026 ## ii. Reduce network interruptions (partial/full grid collapse) from an ## annual average of nine (9) to one (1). ## iii. Meet 100% of the DisCos’ energy needs as approved by the **Commission.** **iv. Achieve improved system reliability and eliminate system collapse** **v. Achieve 100% visibility of the grid through the implementation of** **SCADA** ## vi. Achieve 100% energy accountability ## vii. Reduce accidents and improve safety and protection in grid **operations** **viii. Automated control of the grid and TCN processes.** ## E. NERC/2024/004 – NERC/2024/014 — Order on Non-Compliance with ## Capping of Estimated Bill by DisCos for the period January – September 2023 ## (11 Orders issued to 11 DisCos). The Order became effective on 12 February ## 2024 with the following objectives; ## i. Ensure rectification of DisCos’ billing above the approved monthly ## caps and application of appropriate credit adjustments to the ## customers’ accounts. ## ii. Ensure that DisCos act with diligence and integrity by promptly ## adjusting any estimated billing that exceeds the approved capping **limit.** **iii. Strengthen transparency and accountability in the billing processes** **within the NESI.** ## Nigerian Electricity Regulatory Commission * * * iv. Establish a framework to publicly disclose the list of beneficiaries from the rectification process, which will empower customers to assert their rights and verify the accuracy of their bills. The DisCos were mandated by the Commission to reconcile customers’ accounts during the February 2024 billing cycle and issue credit adjustments for customers who were overbilled between January and September 2023. In addition, a deduction of 10% of the naira value of the total overbilling for the period was applied to DisCos’ annual operating expenses over 12 months. The summary of credit adjustments and regulatory sanctions for the DisCos is contained in Table 4.1. Table 4.1: DisCos’ Credit Adjustments and Regulatory Sanction | DisCos | No. of Overbilled Customers | Credit Adjustments(N'Million) | DisCo OpEx Deduction(N'Million) | | --- | --- | --- | --- | | Abuja | 300,013 | 17,874.61 | 1,787.46 | | Benin | 198,309 | 10,497.60 | 1,049.76 | | Eko | 64,043 | 14,137.66 | 1,413.76 | | Enugu | 302,062 | 11,866.26 | 1,186.62 | | Ibadan | 69,628 | 333,680.58 | 33,368.05 | | Ikeja | 300,079 | 20,951.66 | 2,095.16 | | Jos | 466,621 | 13,319.60 | 1,331.96 | | Kaduna | 27,027 | 1,145.27 | 114,527.71 | | Kano | 25,644 | 196,975.09 | 19,697.50 | | Port Harcourt | 249,532 | 14,187.63 | 1,418.76 | | Yola | 18,955 | 541,888.62 | 54,188.86 | | Total | 2,021,913 | 105,052.86 | 10,505.28 | F. NERC/2024/039 — Transfer of Regulatory Oversight of the Electricity Market in Enugu State from the Nigerian Electricity Regulatory Commission to the Enugu State Electricity Regulatory Commission (EERC). The Order became effective on 01 May 2024 with the following objectives; * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Enugu State from the Commission to ## EERC 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 Enugu State from the Commission to ## EERC 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 Enugu State ## from the Commission to EERC. ## The Order mandated Enugu Electricity Distribution Company (EEDC) to ## incorporate, within 60 days, a subsidiary under the Companies and Allied ## Matters Act (CAMA) for the assumption of its responsibilities for intrastate supply ## and distribution of electricity in Enugu State. ## G. NERC/2024/040 — Order on the Deregulation of Meter Prices for Meters ## Deployed under the Meter Asset Provider Scheme. The Order became effective ## on 01 May 2024 and sought to deregulate the prices of meters deployed under ## the MAP scheme. ## The Order provides that prices of meters under the MAP scheme shall be ## determined through a competitive bidding process, and customers will be ## provided with a choice of authorised meter vendors. The Order provided for the ## following meter to be deployed under the MAP scheme-basic electronic meters, ## Internet of Things (IoT) meters, DIN Rail meters. Current Limiters are also allowed ## by the Order but are subject to full compliance with the NESI Metering Code ## and the requirements/specifications of the DisCos. ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## H. NERC/2024/041 and NERC/2024/042 — Transfer of Regulatory Oversight of ## the Electricity Market in Ekiti State from the Nigerian Electricity Regulatory ## Commission to the Ekiti State Electricity Regulatory Bureau (EERB). The Orders ## became effective on 01 May 2024 with the following objectives; ## i. Commence the process of the transfer of regulatory oversight for ## the intrastate electricity market in Ekiti State from the Commission ## to EERB in accordance with the CFRN and EA. ## ii. Provide a transition plan for the transfer of regulatory oversight for ## the intrastate electricity market in Ekiti State from the Commission ## to EERB 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 Ekiti State ## from the Commission to EERB. ## The Orders mandated Benin Electricity Distribution Company (NERC/2024/041) ## and Ibadan Electricity Distribution PLC (NERC/2024/042) to incorporate within ## 60 days, a subsidiary each under the CAMA for the assumption of responsibilities ## for intrastate supply and distribution of electricity in their respective franchise ## areas in Ekiti State. ## I. NERC/2024/043 — Transfer of Regulatory Oversight of the Electricity Market in ## Ondo State from the Nigerian Electricity Regulatory Commission to the Ondo ## State Electricity Regulatory Bureau (OSERB). The Order became effective on 01 ## May 2024 with the following objectives; ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Ondo State from the Commission to ## OSERB in accordance with the CFRN and EA. ## Nigerian Electricity Regulatory Commission * * * ii. Provide a transition plan for the transfer of regulatory oversight for the intrastate electricity market in Ondo State from the Commission to OSERB 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 Ondo State from the Commission to OSERB. The Order mandated Benin Electricity Distribution Company (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 Ondo State. J. NERC/2024/044 — NESI Interim Order on Transmission System Dispatch Operations, Cross-Border Supply and Related Matters 2024. The Order became effective on 01 May 2024 and sought to; i. Serve as an interim measure to guide the operations of the System Operator (SO) and the TCN to implement SOPs, operational support tools and other requirements to improve transparency and fairness of grid operations in delivering better services to all customers of the transmission system. ii. Place interim caps on capacities supplied to international customers for 6 months from the effective date of the Order, thus minimising the displacement and impact on domestic supply obligations by GenCos and overall risks to the Nigerian Electricity Market, even when there is a limitation in generation. * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## compromised DisCo’s ability to deliver on the SBT committed service levels. The ## Commission noted the SO’s practice of managing generation availability by ## limiting DisCos' load offtake/allocation while prioritising international off-takers ## and eligible customers. This Order thus sought to ensure an equitable adjustment ## to load allocation for all off-takers (DisCos, international customers and eligible ## customers) in the event of a drop in generation and other grid imbalance **situations.** ## K. NERC/2024/045 — Order on the Establishment of the Independent System ## Operator (ISO). The Order became effective on 01 May 2024 with the following **objectives;** ## i. Ensure compliance with the provisions of the EA on the incorporation ## of the ISO. ## ii. Provide clear directives on the timelines for the incorporation of the **ISO.** **iii. Outline the procedure for the transfer of the assets and liabilities of the** **market and system operations portion of the business that currently** **vests in the TCN to the ISO.** ## The Order mandated the Bureau of Public Enterprises (BPE) to incorporate a ## private company limited by shares to carry out market and system operation ## functions stipulated in the EA. The Order specified that the name of the company ## shall be the Nigerian Independent System Operator of Nigeria Limited (NISO) ## and it will be responsible for managing all assets and liabilities pertaining to ## market and system operation as well as carry out all market and system ## operation-related contractual rights and obligations novated to it by the TCN. ## The Order further stated that the initial subscribers to the NISO shall be the BPE ## and the Ministry of Finance Incorporated (MOFI). ## Nigerian Electricity Regulatory Commission * * * L. NERC/2024/072 — Order on the Operationalisation of Tranche A of the Meter Acquisition Fund (MAF). The Order became effective on 24 June 2024 with the following objectives; i. Provide a transparent and functional framework for operationalising the first tranche of metering under the MAF scheme. ii. Provide the eligibility conditions for access to the first tranche of funding under MAF. iii. Provide the terms of payment, monitoring and evaluation, and other conditions for manufacturers and MAPs participating in the scheme. The Order provided that DisCos shall utilise the first tranche of disbursement from the MAF scheme based on contributions made by DisCos as of the April 2024 market settlement to procure and install meters for unmetered Band A customers within their franchise areas. The Order also specified the reporting requirements of the various parties to the Commission with respect to the operationalisation of the MAF (Table 4.2). Table 4.2: Reporting requirements on the Operationalisation of MAF | Reporting Party | Type of Report | Frequency | Receiving Party | | --- | --- | --- | --- | | Fund Manager(FM) | Fund Performance Report | Quarterly | NERC | | Risk Management Report | One-off | NERC | | | DisCo | Meter Deployment Plan | One-off | NERC/FM | | Monthly Meter Deployment Report | Monthly | NERC/FM | | | MAPs/LMMAs | Meter Installation Report | Weekly | DisCo/FM/NERC | LMMAs - Local meter manufacturer or assembler * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## M. NERC/2024/073 — Transfer of Regulatory Oversight of the Electricity Market in ## Imo State from the Nigerian Electricity Regulatory Commission to the Imo State ## Electricity Regulatory Commission (ISERC). The Order became effective on 01 ## July 2024 with the following objectives; ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Imo State from the Commission to ISERC in ## accordance with the CFRN and EA. ## ii. Provide a transition plan for the transfer of regulatory oversight for the ## intrastate electricity market in Imo State from the Commission to ISERC 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 Imo State from ## the Commission to ISERC. ## The Order mandated EEDC to incorporate within 60 days a subsidiary under the ## CAMA for the assumption of its responsibilities for intrastate supply and ## distribution of electricity in Imo State. ## N. NERC/2024/086 — NERC/2024/096-Order on Performance Monitoring ## Framework for the Distribution Companies (11 Orders issued to 11 DisCos). The ## Order became effective on 08 July 2024 and specifies seven (7) Key **9** **Performance Indicators (KPIs) on which the management of DisCos shall be** **assessed by the Commission. The objectives of the Order include;** **9** **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)** ## Nigerian Electricity Regulatory Commission * * * 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. 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 order provided that 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. O. 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. Compliance with service standards for the resolution of complaints received through the NERC contact centre and NERC headquarters 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 tariff shortfall liabilities to include funds provided under various 10 sources. Over the years, the incidence of non-cost reflective tariffs in the NESI has 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 Obligation” (DRO) as the full and final energy invoice to the DisCos on a monthly basis and record the applicable tariff shortfall portion of the monthly generation invoices as a receivable from the FGN. P. 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. The PPAs are 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 10 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 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. Q. NERC/2024/002 — Order on the Nomenclature of Generating Plants. The Order became effective on 01 August 2024 and was developed to standardise the naming convention of all licensed generation licensees in the NESI. The Order specified the names by which generation licensees shall be identified in all formal records by the SO. 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. ii. Achieve standardisation in the nomenclature of generation assets within the NESI to allow for easy identification and network data reporting. * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## 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. ## R. 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 with 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. ## The Order mandated 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. ## S. NERC/2024/111 — Transfer of Regulatory Oversight of the Electricity Market in ## Edo State from the Nigerian Electricity Regulatory Commission to the Edo State ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## Electricity Regulatory Commission (ESERC). The Order became effective on 21 ## August 2024 with the following objectives; ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Edo State from the Commission to ESERC ## in accordance with the CFRN and EA. ## ii. Provide a transition plan for the transfer of regulatory oversight for the ## intrastate electricity market in Edo State from the Commission to ESERC ## 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 Edo State from ## the Commission to ESERC. ## The Order mandated Benin Electricity Distribution Plc (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. ## T. 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 with the following objectives; ## i. 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. ## ii. 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. ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## iii. 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 mandated 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. ## U. NERC/2024/112 and NERC/2024/113 — Transfer of Regulatory Oversight of ## the Electricity Market in Lagos State from the Nigerian Electricity Regulatory ## Commission to the Lagos State Electricity Regulatory Commission (LASERC). The ## Orders became effective on 05 December, 2024 with the following objectives: ## i. Commence the process of the transfer of regulatory oversight for the ## intrastate electricity market in Lagos State from the Commission to ## LASERC in accordance with the CFRN and EA. ## ii. Provide a transition plan for the transfer of regulatory oversight for the ## intrastate electricity market in Lagos State from the Commission to ## LASERC in accordance with the CFRN and the EA. ## iii. Address ensuing transitional matters arising from the transfer of ## regulatory oversight for the intrastate electricity market in Lagos State ## from the Commission to LASERC. ## The Orders mandated Eko Electricity Distribution Plc (NERC/2024/112) and ## Ikeja Electric Plc (NERC/2024/113) to each incorporate within 60 days, a ## subsidiary under the CAMA for the assumption of the responsibilities for ## intrastate supply and distribution of electricity in their respective franchise areas ## in Lagos State. ## Nigerian Electricity Regulatory Commission * * * V. NERC/2024/162 — Addendum -1 to the Order on Performance Monitoring Framework for Distribution Companies July 2024. The Order became effective on 23 December 2024 and has the following objectives: i. Improve regulatory efficiency by aligning the frequency of KPI evaluations with data availability, ensuring timely and effective interventions. ii. Enhance compliance and enforcement measures by refining the regulatory framework to support DisCos in achieving performance targets. The Commission noted that the evaluation of compliance with two (2) Key Performance Indicators (Energy offtake relative to PCC and Compliance with Reporting of Uniform System of Accounts) is dependent on data which are available only at the end of the market cycle which may delay the implementation of consequential regulatory interventions. Thus, this order sought to adjust the evaluation frequency and the associated consequential regulatory interventions for non-compliance with the aforementioned KPIs. W. NERC/2024/163, NERC/2024/164 and NERC/2024/165 — Transfer of Regulatory Oversight of the Electricity Market in Ogun State from the Nigerian Electricity Regulatory Commission to the Ogun State Electricity Regulatory Commission (OGERC). The Orders became effective on 24 December 2024 with the following objectives; i. Commence the process of the transfer of regulatory oversight for the intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and EA. * * * ii. Provide a transition plan for the transfer of regulatory oversight for the intrastate electricity market in Ogun State from the Commission to OGERC in accordance with the CFRN and the EA. iii. Address ensuing transitional matters arising from the transfer of regulatory oversight for the intrastate electricity market in Ogun State from the Commission to OGERC. The Orders mandated Eko Electricity Distribution Company (NERC/2024/163), Ikeja Electric Plc (NERC/2024/164) and Ibadan Electricity Distribution Company (NERC/2024/165) to each incorporate within 60 days, a subsidiary under the CAMA for the assumption of the responsibilities for intrastate supply and distribution of electricity in their respective franchise areas in Ogun State. 4.4 Directives Regulatory directives issued by the Commission are designed to ensure compliance with laws, policies, and regulations within the NESI. In 2024, the Commission issued one (1) directive, as detailed below: A. NERC/2024/003 — Directive to Independent System Operator for the utilisation of Zungeru Hydro Electricity Generation Company Limited for managing grid imbalances caused by insufficient generation. The directive was to be effective from 16 May 2024 until 31 August 2024. * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## grid pending the finalisation of its long-term contractual arrangements with ## prospective off-takers. ## 4.5 Licensing **Section 63 (1) of the EA 2023 states that “without prejudice to the right of the States** **of the Federation to make laws and establish markets for the generation,** **transmission, system operation, distribution and supply of electricity within their** **respective territories, no person, except in accordance with a licence issued pursuant** **to the provisions of this Act or deemed to have been issued under section 213 (b)** **or as provided under this Act, shall construct, own, operate an undertaking other** **than an undertaking specified under subsection (2) of this section, or in any way** **engage in the business of: “** ## A. Electricity generation, excluding captive generation ## B. Electricity transmission ## C. Electricity distribution ## D. Electricity supply ## E. Electricity trading ## F. System operation ## The Commission as empowered by the EA 2023 regulates activities in the NESI and ## grants licences for electricity generation, transmission, distribution, trading and ## system operations in the NESI. The various types of licences granted by the ## Commission include: ## A. Generation Licence: This type of licence grants the holder the right to construct, ## own, operate and maintain a generation station for the generation and supply of ## electricity. The holder of a generation licence can sell electricity and ancillary ## services to approved licensees including electricity trading companies, distribution ## Nigerian Electricity Regulatory Commission * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## companies, eligible customers, single buyers etc. There are three (3) types of ## generation licences: ## i. On-grid electricity licence: This licence allows the holder to generate ## electricity and connect to the national grid for sale to any of the licensee ## groups provided for in the Act. The holder is required to enter into a ## connection agreement with the Transmission Company of Nigeria. ## ii. Embedded generation licence: This licence grants the licensee the right to ## electricity generation and evacuation through an existing distribution ## facility system or an independent distribution licensee. The embedded ## generator licensee is required to enter into a power purchase agreement ## with an electricity distribution licensee (DisCo), or the operator of an ## independent electricity distribution network. Unlike grid-connected ## generators, energy from embedded generation plants is evacuated at ## 33kV or lower. ## iii. Off-grid electricity generation licence: This authorises a licensee to ## generate and sell power to a single buyer (or community) without ## connection to the national grid. ## As of December 2024, the total nameplate capacity of the thirty (30) operational ## grid-connected power plants licensed by the Commission was 14,039MW. Five (5) ## out of the thirty (30) power plants are hydropower plants while the remaining are ## gas-fired thermal plants. Further details about the licenced grid-connected power ## plants are contained in Table 4.3. ## Nigerian Electricity Regulatory Commission * * * Table 4.3: Details of licenced grid-connected Power Plant as of December 2024 | SN | Old Plant Name | New Plant Name | Location | Ownership$^{11}$ | Turbine Type$^{12}$ | Installed Capacity(MW) | Fuel Type | | --- | --- | --- | --- | --- | --- | --- | --- | | 1 | AES | AES\_1 | Lagos | IPP | OC | 294 | Gas | | 2 | Afam IV-V | Afam\_1 | Rivers | Privatised | OC | 726 | Gas | | 3 | Afam VI | Afam\_2 | Rivers | IPP | CC | 650 | Gas | | 4 | Alaoji | Alaoji\_1 | Abia | NIPP | CC | 500 | Gas | | 5 | Azura IPP | Ihovbor\_2 | Benin | IPP | OC | 461 | Gas | | 6 | Odukpani | Odukpani\_1 | Cross River | NIPP | OC | 625 | Gas | | 7 | Egbin | Egbin\_1 | Lagos | Privatised | GS | 1,320 | Gas | | 8 | Geregu | Geregu\_1 | Kogi | Privatised | OC | 435 | Gas | | 9 | Geregu NIPP | Geregu\_2 | Kogi | NIPP | OC | 435 | Gas | | 10 | Ibom Power | Ibom Power\_1 | Akwa Ibom | IPP | OC | 190 | Gas | | 11 | Ihovbor NIPP | Ihovbor\_1 | Edo | NIPP | OC | 500 | Gas | | 12 | Okpai | Okpai\_1 | Delta | IPP | CC | 480 | Gas | | 13 | Olorunsogo | Olorunsogo\_1 | Ogun | Privatised | OC | 335 | Gas | | 14 | Olorunsogo NIPP | Olorunsogo\_2 | Ogun | NIPP | CC | 750 | Gas | | 15 | Omoku | Omoku\_1 | Rivers | IPP | OC | 150 | Gas | | 16 | Gbarain | Gbarain\_1 | Rivers | NIPP | OC | 120 | Gas | | 17 | Omotosho | Omotosho\_1 | Ondo | Privatised | OC | 335 | Gas | | 18 | Omotosho NIPP | Omotosho\_2 | Ondo | NIPP | OC | 500 | Gas | | 19 | Sapele ST | Sapele Steam\_1 | Delta | Privatised | GS | 720 | Gas | | 20 | Sapele GT NIPP | Sapele\_2 | Delta | NIPP | OC | 500 | Gas | | 21 | Delta Gas | Delta\_1 | Delta | Privatised | OC | 900 | Gas | | 22 | Trans Amadi | Trans Amadi\_1 | Rivers | IPP | OC | 100 | Gas | | 23 | Rivers IPP | Rivers\_1 | Rivers | IPP | OC | 180 | Gas | | 24 | Paras | Ikeja\_1 | Ogun | IPP | OC | 110 | Gas | | 25 | Taopex | Igbafo\_1 | Lagos | IPP | GS | 45 | Gas | | 26 | Kainji | Kainji\_1 | Niger | Concession | HT | 760 | Hydro | | 27 | Jebba | Jebba\_1 | Niger | Concession | HT | 578 | Hydro | | 28 | Shiroro | Shiroro\_1 | Niger | Concession | HT | 600 | Hydro | | 29 | Dadinkowa | Dadin-Kowa\_1 | Gombe | Concession | HT | 40 | Hydro | | 30 | Zungeru | Zungeru\_1 | Niger | Concession | HT | 700 | Hydro | B. Transmission Licence: This licence is granted for the construction, operation and maintenance of transmission systems within Nigeria, or that connects Nigeria with a 11 NIPP (Nigerian National Integrated Power Project) refers to plants that were built and are operated by the Niger Delta Power Holding Company (NDPHC) on behalf of the Federation. IPP are a combination of projects developed by either private companies or singular government institutions (Federal Ministry of Power or individual state government). All IPPs are currently operated by private companies. 12 OC is open cycle gas turbine, CC closed cycle gas turbine, GS is gas-fired steam turbine, and HT is hydro turbine. * * * neighbouring country at a voltage above 33kV. The Transmission Company of Nigeria (TCN) has the responsibility of transporting energy from power plants to DisCos and International customers and currently holds two licences; Transmission Service Provider (TSP) and System Operator (SO). The TSP owns and maintains the transmission infrastructure. C. System Operator: The SO is responsible for maintaining system stability, load balance, load dispatch and undertaking market operations responsibilities. Pursuant to Section 15 of the EA 2023, which provides for the incorporation of an Pursuant to Section 15 of the EA 2023, which provides for the incorporation of an entity to be licensed as an ISO to perform the market and system operation functions entity to be licensed as an ISO to perform the market and system operation functions of the TCN, the Commission through the Order on the Establishment of the entity to be licensed as an ISO to perform the market and system operation functions through the Order on the Establishment of the Independent System Operator (NERC/2024/45) unbundled the TCN into two Independent System Operator (NERC/2024/45) entities; the Nigerian Independent System Operator Nigeria Limited (NISO) and the Transmission Service Provider (TSP). This unbundling is intended to enhance efficiency, reliability and transparency in the transmission sub-sector of the NESI. Independent System Operator (NERC/2024/45) unbundled the TCN into two entities; the Nigerian Independent System Operator Nigeria Limited (NISO) and the Transmission Service Provider (TSP). This unbundling is intended to enhance efficiency, reliability and transparency in the transmission sub-sector of the NESI. * * * D. Distribution Licence: A distribution licence holder is permitted to construct, operate and maintain a network operable at 33kV or lower to distribute electricity from grid supply points to the point of delivery to consumers or eligible customers. The licence authorises the holder to carry out installation, maintenance and reading of electricity meters as well as billing and collection of bills. The details of distribution licensees as of December 2024 are given in Table 4.4. Table 4.4: Electricity Distribution Licensees (DisCos) in the NESI | S/N | DisCo | Franchise area(State/LG13) | | --- | --- | --- | | 1 | Aba Power(APLE) | Abia(Aba ring-fenced area-Aba North,Aba South,Osisioma Ngwa,Obingwa,Ugwunagbo,Ukwa East,Ukwa West,Isiala Ngwa North,Isiala Ngwa South) | | 2 | Abuja(AEDC) | FCT,Niger,Kogi,Nasarawa | | 3 | Benin(BEDC) | Edo,Delta,Ondo,Ekiti(Ado-Ekiti,Ikogosi Ekiti,Ipole-lloro Ekiti) | | 4 | Eko(EKEDP) | Lagos(Apapa,Festac,Ijora,Lekki,Ibeju,Ojo,Orile,Mushin,Victoria Island,Ikoyi) | | 5 | Enugu(EEDC) | Enugu,Abia,Imo,Anambra,Ebonyi | | 6 | Ibadan(IBEDC) | Oyo,Ogun,Osun,Kwara, | | 7 | Ikeja(IE) | Lagos(Abule-Egba,Akowonjo,Ikeja,Ikorodu,Oshodi,Amuwo Odofin,Igando,Magodo,Ajao,Ijegun,Oke-afa,Shomolu) | | 8 | Jos(JED) | Plateau,Bauchi,Benue,Gombe | | 9 | Kaduna(KAEDC) | Kaduna,Sokoto,Kebbi,Zamfara | | 10 | Kano(KEDCO) | Kano,Jigawa,Katsina | | 11 | Port Harcourt(PHED) | Rivers,Cross River,Bayelsa,Akwa Ibom | | 12 | Yola(YEDC) | Yola,Adamawa,Borno,Taraba,Yobe | Pursuant to the provisions of the EA 2023, and detailed above, the Commission has issued orders transferring the regulatory oversight of nine (9) states to the state electricity regulatory commissions/bureaus (SERC/SERB). The list of the SERC/SERBs that had been created as at 31 December 2024 is contained in Table 4.5. 13 Local governments – LGs are written in italics * * * Table 4.5: Approved State Electricity Regulatory Bodies in the NESI | SN | State | New Electricity Regulator | DisCo(s) with operations within the State | | --- | --- | --- | --- | | 1 | Enugu | Enugu State Electricity Regulatory Commission | Enugu DisCo | | 2 | Ekiti | Ekiti State Electricity Regulatory Bureau | Benin DisCo Ibadan DisCo | | 3 | Ondo | Ondo State Electricity Regulatory Bureau | Benin DisCo | | 4 | Imo | Imo State Electricity Regulatory Commission | Enugu DisCo | | 5 | Oyo | Oyo State Electricity Regulatory Commission | Ibadan DisCo | | 6 | Edo | Edo State Electricity Regulatory Commission | Benin DisCo | | 7 | Kogi | Kogi State Electricity Regulatory Commission | Abuja DisCo | | 8 | Lagos | Lagos State Electricity Regulatory Commission | Eko DisCo Ikeja DisCo | | 9 | Ogun | Ogun State Electricity Regulatory Commission | Eko DisCo Ikeja DisCo Ibadan DisCo | E. Trading Licence: A trading licence grants the holder the authority to purchase, resell and trade electricity and ancillary services from independent power producers and generation companies. All contracts for the purchase of electrical power and ancillary services by the trading licensee must be concluded in an open, transparent and competitive manner and in accordance with the procedure established by the Commission. In 2024, the Commission approved the renewal of a three-year licence for the Nigerian Bulk Electricity Trading Plc and issued new trading licences to nine (9) companies (Table 4.6). All the trading licences were issued pursuant to the Commission’s commitment to transition the Nigerian electricity market into bilateral wholesale energy trading in compliance with the provisions of the EA 2023. * * * Table 4.6: Trading Licences issued in 2024 | SN | Trading Licensee | Date of Issuance | | --- | --- | --- | | 1 | Watts Exchange Limited | 10 January 2024 | | 2 | Centum Dopemu Energy Services Limited | 10 January 2024 | | 3 | DMD Electric Limited | 23 February 2024 | | 4 | Golden Triangle Electric Power Solutions Company Limited | 26 June 2024 | | 5 | Damcrest Energy Limited | 10 July 2024 | | 6 | Zenith Point Limited | 07 October 2024 | | 7 | Capstone Energies Limited | 25 September 2024 | | 8 | Ecovolt Trade Limited | 23 October 2024 | | 9 | Tendon Innovation Limited | 23 October 2024 | 4.6 Permits and Certifications There are some activities which the EA 2023 does not explicitly grant the Commission licencing powers but which still require regulatory oversight. In line with international best practices, the Commission issues permits or certificates to eligible companies/institutions to participate in those activities. The key activities for which the Commission issues permits or certificates are: B. Mini-grid: The Commission issues permits to mini-grid developers for the construction, operation, maintenance, and where applicable ownership of mini-grids with distribution capacity above 100kW and generation capacity up to 1MW. For systems with a distribution capacity below 100kW, the Commission issues a registration certificate to the mini-grid developer. * * * D. Meter Service Provider (MSP): An MSP is an entity certified by the Commission as a manufacturer, supplier, vendor, or installer of electric energy meters and/or metering systems. The summary of licences, permits and certifications issued by the Commission in 2024 is contained in Table 4.7 and full details of the licensees are contained in Appendix B.1 – B.4. Table 4.7: Licenses, Permits and Certifications Issued by the Commission in 2024 | SN | Licence/Permit | Number | | --- | --- | --- | | 1 | On-grid generation | 3 | | 2 | Off-grid generation | 22 | | 3 | System Operator | 1 | | 4 | Trading Licence | 9 | | 5 | Captive power | 24 | | 6 | Mini-grid registration certificates | 7 | | 7 | Mini-grid permits | 27 | | 8 | Meter service providers | 36 | | 9 | MAP permit | 39 | | | Total | 168 | 4.7 Compliance Monitoring and Enforcement Pursuant to these provisions, the Commission carried out enforcement actions against licensees during the year for violations of rules and infractions against other instruments in the NESI. The primary enforcement mechanisms used by the Commission include: Pursuant to these provisions, the Commission carried out enforcement actions against licensees during the year for violations of rules and infractions against other instruments in the NESI. The primary enforcement mechanisms used by the * * * ## Regulation, Licensing & Compliance NERC Annual Report 2024 ## A. Notice to Commence Enforcement (NICE): this is a formal communication to ## a licensee informing them of the Commission’s intention to commence ## enforcement proceedings arising from their non-compliance with instructions ## issued by the Commission. The issuance of NICE is pursuant to the provisions ## of section 76(1) of the EA 2023. ## B. Rectification Directives: this is an Order or instruction to correct a mistake, ## submission or omission that ought to be done. ## C. Penalties: refers to a sanction or punishment imposed for violating a law, ## contract, rule, or regulation. ## D. Administrative fines: These are financial sanctions imposed by the Commission ## to deter undesirable behaviour and encourage compliance. ## The summary of the various enforcement actions by the Commission in 2024 is ## contained in Table 4.8. As part of the effort to enforce compliance with all its ## regulatory instruments, codes and standards in the NESI, the Commission held peer ## review meetings with the compliance and regulatory officers of licensees during the ## year to discuss the reporting obligations of licensees as well as health and safety ## matters. During the meeting, licensees' scorecards on compliance with health and ## safety standards, forum office decisions, and key performance indicators were ## discussed while highlighting areas of improvement. ## Nigerian Electricity Regulatory Commission * * * Table 4.8: Summary of enforcement actions carried out by the Commission in 2024 | S/N | Rectification Directive/(NICE)/Fines | Licensee | Date Issued | Deadline | | --- | --- | --- | --- | --- | | | | Rectification Directives | | | | 1 | Non-compliance with Benin Forum Office decision in complaint number BENFO/NERC/869/2023. | Benin DisCo | 04 January 2024 | 16 January 2024 | | 2 | Non-compliance with the Umuahia Forum decision in complaint number UMFO/NERC/10/2022/C0771. | Aba Power | 18 January 2024 | 01 February 2024 | | 3 | Non-compliance with the Ikeja Forum decisions in complaint number IFO/NERC/2023/09/9520 and IFO/NERC/2023/09/9522 | Ikeja DisCo | 05 February 2024 | 12 February 2024 | | 4 | Non-compliance with the Ikeja Forum decisions in complaint number IFO/NERC/2022/11/8402. | Ikeja DisCo | 06 February 2024 | 13 February 2024 | | 5 | Failure to submit the February 2024 metering report | Kano DisCo | 27th March 2024 | 29th March 2024 | | 6 | Failure to submit the Annual Compliance Report on the 2023 Outage Scheduling Programme | TCN | 19 April 2024 | 03 May 2024 | | 7 | Failure to replace faulty prepaid meter | Abuja DisCo | 28 March 2024 | 04 April 2024 | | 8 | Directive to reconcile the difference in the amount owed by a customer | Abuja DisCo | 07 May 2024 | 21 May 2024 | | 9 | Non-metering of Maximum Demand (MD) customers and estimated billing of MD customers | All DisCos except Kaduna and Kano | 31 May 2024 | 14 June 2024 | | 10 | Non-compliance with the Commission's directives regarding Angwan Magaji Community | Abuja DisCo | 08 May 2024 | 22 May 2024 | | 11 | Failure to meter 15 customers within the prescribed 10-day period after payment | IBEDC | 20 August 2024 | 03 September 2024 | | 12 | Failure to file audited financial statements | Various off-grid licensees14 | 30 August 2024 | 13 September 2024 | 14 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. * * * Regulation, Licensing & Compliance NERC Annual Report 2024 | S/N | Rectification Directive/(NICE)/Fines | Licensee | Date Issued | Deadline | | --- | --- | --- | --- | --- | | 13 | Failure to adequately show compliance with post-incident remedial actions directed by the Commission | TCN | 09 September 2024 | 23 September 2024 | | 14 | 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 | | 15 | Non-compliance with forum decision | Ikeja DisCo | 06 September 2024 | 13 September 2024 | | 16 | Non-compliance with the Commission's decision regarding the complaint by KYC estate | Abuja DisCo | 24 September 2024 | 30 September 2024 | | 17 | Non-compliance with Eko forum ruling in complaint No: EFO/5770/2024 | Eko DisCo | 20 December 2024 | 27 December 2024 | | 18 | Non-compliance with MAP and NMMP Regulations | Eko DisCo | 20 December 2024 | 03 January 2025 | | 19 | Non-compliance with capping of estimated bills | Enugu and Port Harcourt DisCo | 20 November 2024 | 30 November 2024 | | 20 | Non-compliance with customer complaints resolution procedure | Eko and Ikeja DisCos | 26 November 2024 | 06 December 2024 | | 21 | Non-compliance with resolution on appeal | Ibadan DisCo | 26 November 2024 | 10 December 2024 | | 22 | Non-compliance with decision in customer complaints | Abuja DisCo | 19 November 2024 | 26 November 2024 | | 23 | Non-compliance with forum decision in complaint No: AFO/2019/09/B460 | Abuja DisCo | 12 November 2024 | 19 November 2024 | | 24 | Non-compliance with forum decision in complaint No: AFO/2024/08/C233 | Abuja DisCo | 04 November 2024 | 11 November 2024 | | 25 | Non-compliance with forum decision in complaint No: NERC/SFO/01/24/223 | Kaduna DisCo | 01 November 2024 | 15 November 2024 | | 26 | Non-compliance with forum decision in complaint No: AFO/2024/09/C244 | Abuja DisCo | 11 October 2024 | 25 October 2024 | | 27 | Non-compliance with forum decision in complaint No: IFO/2024/06/10630 | Ikeja DisCo | 16 October 2024 | 30 October 2024 | | 28 | Non-compliance with directive on filing audited financial statements | Green Energy International Limited | 10 October 2024 | 23 October 2024 | | Notice of Intention to Commence Enforcement Action (NICE) | | | | | | 29 | Failure to file compliance returns | Wapsila Nigeria Limited | 15 January 2024 | 29 January 2024 | | 30 | Failure to comply with the HSE Code and NESIS regulations | Abuja, Eko, Jos and Ikeja DisCos | 03 April 2024 | 16 April 2024 | | 31 | Breach of Eligible Customer Regulations 2017 | TCN | 8 April 2024 | 22 April 2024 | * * * Regulation, Licensing & Compliance | S/N | Rectification Directive/(NICE)/Fines | Licensee | Date Issued | Deadline | | --- | --- | --- | --- | --- | | 32 | Failure to comply with forum decision in favour of New Haven Community | Abuja DisCo | 05 April 2024 | 19 April 2024 | | 33 | Health and safety infractions | TCN | 03 April 2024 | 17 April 2024 | | 34 | Non-compliance/health and safety infractions | TCN | 21 June 2024 | 5 July 2024 | | 35 | Non-compliance with the Commission's directives against bulk-billing | Enugu DisCo | 13 September 2024 | 27 September 2024 | | 36 | Non-metering of MD customers | Port Harcourt and Enugu DisCos | 08 July 2024 | 15 July 2024 | | 37 | Decommissioning of 7,319 meters without the Commission's prior consent | Ibadan DisCo | 05 July 2024 | 19 July 2024 | | 38 | Health and safety infractions | Kano DisCo | 20 August 2024 | 03 September 2024 | | 39 | Non-compliance with the Commission's post-incident recommendations | Enugu DisCo | 09 September 2024 | 23 September 2024 | | 40 | Failure to submit reports on standardisation of network infrastructure for 2024/Q2 | Enugu and Eko DisCos | 30 August 2024 | 13 September 2024 | | 41 | Health and safety infractions | Ibadan DisCo | 05 September 2024 | 19 September 2024 | | 42 | Non-compliance with the Commission's directives on faulty transformer replacement | Abuja DisCo | 21 August 2024 | 05 September 2024 | | 43 | Non-compliance with the Commission's directives against bulk-billing | Eko DisCo | 13 September 2024 | 27 September 2024 | | 44 | Health and safety infractions | Kano DisCo | 11 September 2024 | 25 September 2024 | | 45 | Unauthorised supply of power | Obafemi Awolowo University | 10 December 2024 | 24 December 2024 | | 46 | Failure to respond to Commission's request for update on resolution of complaint | Abuja DisCo | 26 November 2024 | 10 December 2024 | | 47 | Non-compliance with forum ruling in KNF/NERC/24/04/0048 | Kano DisCo | 21 November 2024 | 05 December 2024 | | 48 | Non-compliance with the Account Administration Agreement | Kaduna DisCo | 08 November 2024 | 22 December 2024 | | 49 | Non-compliance with directive on Principal Collection Accounts | Kaduna, Kano and Port Harcourt DisCos | 08 November 2024 | 22 December 2024 | | 50 | Non-compliance with forum decision in AFO/2021/11/B856 | Abuja DisCo | 01 November 2024 | 15 December 2024 | | 51 | Non-compliance with NESIS regulation | Ibadan DisCo | 04 October 2024 | 28 October 2024 | | 52 | Non-compliance with NESIS regulation | Ibadan DisCo | 24 October 2024 | 07 November 2024 | | 53 | Non-compliance with the Commission's directive to file audited financial statements. | Green Energy International Limited | 28 October 2024 | 11 November 2024 | * * * Regulation, Licensing & Compliance | S/N | Rectification Directive/(NICE)/Fines | Licensee | Date Issued | Deadline | | --- | --- | --- | --- | --- | | 54 | Non-compliance with NESIS regulation and HSE code | Yola DisCo | 23 October 2024 | 06 November 2024 | | 55 | Non-compliance with Commission's directive in an appeal | Abuja DisCo | 22 October 2024 | 05 November 2024 | | 56 | Non-compliance with NESIS regulation | Abuja DisCo | 14 October 2024 | 28 October 2024 | | 57 | Non-compliance with the grid code | TCN | 14 October 2024 | 28 October 2024 | | | Fines | | | | | 58 | A fine of NGN2,250,000 and USD450,000 (or its naira equivalent) for partaking in the NESI without a licence | CCETC SUK Power Limited | 03 April 2024 | 7 May 2025 | | 59 | A fine of NGN1,000,000 and USD200,000 (or its naira equivalent) for partaking in the NESI without a licence | SUK Distribution Company Limited | 03 April 2024 | 7 May 2025 | | 60 | A fine of NGN200,000,000 for non-compliance with the supplementary Order to the April 2024 MYTO(NERC/2024/027) | Abuja DisCo | 25 April 2024 | 31 July 2024 | 4.8 Hearings and Alternative Dispute Resolution among Market Participants 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 role towards the resolution of disputes between stakeholders is through hearings. During the year, the Commission conducted hearings to consider the petitions filed by different stakeholders on issues pertaining to the provision and utilisation of electricity services. The list of the hearings conducted in 2024 is contained in Table 4.9. Alternative Dispute Resolution (ADR) refers to the settlement process instituted by Alternative Dispute Resolution (ADR) refers to the settlement process instituted by the Commission for the resolution of disputes that may arise among market participants. Section 42.3 of the Market Rule empowers the Commission to appoint a Dispute Resolution Counsellor (DRC) and constitute a Dispute Resolution Panel a Dispute Resolution Counsellor (DRC) and constitute a Dispute Resolution Panel (DRP). Pursuant to the Market Rules, the Commission has constituted a DRP and appointed a DRC responsible for arbitrating or otherwise resolving disputes between a Dispute Resolution Counsellor (DRC) and constitute a Dispute Resolution Panel (DRP). Pursuant to the Market Rules, the Commission has constituted a DRP and appointed a DRC responsible for arbitrating or otherwise resolving disputes between market participants. The DRP did not handle any disputes among industry stakeholders in 2024. Table 4.9: Hearings conducted by the Commission in 2024 | S/N | Parties | Petition | Date of Hearing | | --- | --- | --- | --- | | 1 | Enugu Electricity Distribution Company (EEDC), NERC | Petition against the Commission's Order(NERC/2024/006) on Non-compliance with the capping of estimated bills by EEDC | 18 March 2024 | | 2 | Ikeja Electric (IE), NERC | Petition against the Order on Non-compliance with the capping of estimated bills by IE | 19 March 2024 | | 3 | Eko Electricity Distribution Company Plc(EKEDP), NERC | Petition for a Review of the Order on Non-compliance with Capping of estimated bills by EKEDP | 19 March 2024 | | 4 | Benin Electricity Distribution Company(BEDC), NERC | Petition for a Review of the Order on Non-compliance with Capping of estimated bills by BEDC | 20 March 2024 | | 5 | Port Harcourt Distribution Company(PHED), NERC | Petition for a Review of the Order on Non-compliance with Capping of estimated bills by PHED | 20 March 2024 | | 6 | BEDC/OOSS/LECAN, Anyigba IEDN | Petition by Benin Electricity Distribution Company, Obas of Ondo South Senatorial District and the Licenced Electricity Contractors Association of Nigeria against the grant of an Independent Electricity Distribution Network to Anyigba Independent Electricity Distribution Network Limited | 11 March 2024 | | 7 | Eko Electricity Distribution Company Plc(EKEDP), MILL WATER | Petition by EKEDP against the grant of an Independent Electricity Distribution Network licence to MILL WATER Agbara Power Limited | 11 March 2024 | | 8 | Ibadan Electricity Distribution Company(IBEDC), NERC | Petition for a Review of the Order on Non-compliance with Capping of estimated bills by IBEDC | 30 May 2024 | | 9 | CCECC SUK Power Company & SUK Distribution Plc | Petition for a review of fines imposed by the commission for operating undertakings without requisite licensees | 08 May 2024 | | 10 | Manufacturers Association of Nigeria | Petition for the reversal/indefinite suspension of the implementation of the new electricity tariff rate implemented in the Supplementary Multi-Year Tariff Order of 3rd April 2024 and 6th May 2024 | 23 May 2024 | | 11 | Ibadan DisCo | Petition for a review of April Supplementary Order to MYTO 2024 & non-compliance with the procedure for tariff review | 30 May 2024 | | 12 | 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 | * * * Regulation, Licensing & Compliance NERC Annual Report 2024 | S/N | Parties | Petition | Date of Hearing | | --- | --- | --- | --- | | 13 | 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 | | 14 | 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 | | 15 | NBET | Hearing on NBET's application for renewal of its license | 12 September 2024 | | 16 | Ibadan Electricity Distribution Company, Phoenix Steel Mills | Petition against the grant of eligible customer | 15 September 2024 | | 17 | TCN | Hearing on grid disturbances | 24 October 2024 | | 18 | Aba Power | Hearing on Rate Review | 10 December 2024 | * * * # Chapter Five: Consumer Affairs and # a—akeholder Engagements * * * # 5.1 Consumer Affairs # 5.2 atakeholder Engagements * * * ## Consumer Affairs NERC Annual Report 2024 ## 5.1 Consumer Affairs ## The Commission has developed various initiatives to ensure that electricity customers ## are aware of their rights and obligations and that customer service standards by ## licensees are consistent with international best practices. The main avenues of ## interface between the Commission and customers are: ## A. Customer Education/Townhall Meetings ## B. Customer complaints reporting channels ## 5.1.1 Consumer Education-Townhall Meetings ## The customer education/townhall meetings are used to enlighten customers on the ## Commission’s activities, regulatory instruments, customer rights and obligations, as ## well as facilitating swift resolution of complaints. These fora also provide avenues ## for the Commission to obtain feedback from customers which serve as input to the ## Commission in its decision-making process. ## In 2024, nine (9) customer education/townhall meetings were held at different ## locations across the country (Table 5.1). These meetings were held in collaboration ## with other government agencies and development partners, including the Federal ## Competition and Consumer Protection Commission (FCCPC), National Orientation ## Agency (NOA) and United Kingdom Nigeria Infrastructure Advisory Facility ## (UKNIAF). During the meetings, discussions centered around several critical issues ## which include: - **Serviced Based Tariff (SBT) provisions** - **Capping of estimated bills for unmetered customers** - **Electricity customer rights and obligation** - **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. Table 5.1: Town Hall Meetings held in 2024 | S/N | Date | DisCo | Location | | --- | --- | --- | --- | | 1 | 7-9 March 2024 | Kano | Kano State | | 2 | 21-23 March 2024 | Eko | Lagos State | | 3 | 19 March 2024\* | Abuja | FCT | | 4 | 18-20 April 2024 | Enugu | Enugu State | | 5 | 18-20 July 2024 | Jos | Gombe State | | 6 | 08-10 August 2024 | Port Harcourt | Cross River State | | 7 | 12-14 September 2024 | Abuja | Kogi State | | 8 | 10-12 October 2024 | Ibadan | Osun State | | 9 | 12-14 December 2024 | Kaduna | Kaduna State | \*The town hall meeting was organised by UKNIAF for customers of Abuja DisCo A cross-section of participants at the town hall/customer complaints resolution meeting held in Lagos, March 2024 * * * Commissioner of Consumer Affairs (NERC) with representatives from Eko DisCo at the town hall meeting held in Lagos, March 2024 A cross section of participants at the town hall/customer complaints resolution meeting held in Kano, March 2024 * * * A cross-section of participants at the town hall/customer complaints resolution meeting held in Abuja, March 2024 A cross-section of participants at the town hall/customer complaints resolution meeting held in Lokoja, September 2024. * * * ## Consumer Affairs NERC Annual Report 2024 **A cross-section of participants at the town hall/complaints resolution meeting held in Kaduna,** **December 2024** **5.1.2 Customer Complaints** ## Pursuant to section 34(2)(c) of the Electricity Act 2023 which empowers the ## Commission to “establish appropriate consumer rights and obligations regarding the ## provision and use of electricity services” in the NESI, the Commission issued the ## updated Customer Protection Regulation (CPR) in 2023. The updated CPR ## adequately highlights the standards and procedures for handling customer ## complaints in the NESI. Furthermore, the Regulation provides a clear process flow ## for efficient customer complaint resolution in the NESI. The process Error! Reference s ## ource not found.for customer complaint handling and resolution in the NESI is as **follows:** ## i. Lodging a complaint: Customers must first lodge their complaints in writing or ## via email to the Customer Complaints Unit (CCU) of their respective ## Distribution Company (DisCo). ## ii. Acknowledgement of Complaints: The CCU of the DisCos acknowledges ## receipt of the complaint within three (3) working days. ## iii. Resolution by DisCos CCU: The DisCo’s CCU is responsible for resolving the ## complaint within 15 working days. If the complaint requires more time, the ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 ## customer is notified within the initial 15 working days and every 15 days ## thereafter until the complaint is resolved. ## iv. Escalation to Forum Office: If the customer is dissatisfied with the CCU's ## resolution, they can escalate the complaint to the nearest NERC Forum office ## under the DisCo’s operational area. The Forum office reviews the complaint ## with the aim to resolve it within two months. ## v. Escalation to NERC Head Office: If the customer is still not satisfied with the ## Forum office's resolution, they can escalate the complaint to the NERC head ## office. NERC reviews the complaint and the processes followed by the DisCo ## and Forum to arrive at a final decision. ## This structured approach ensures that customer complaints are handled ## systematically and transparently, providing multiple levels of review to ensure fair **resolution.** ## 5.1.3 Complaints Reporting Channels ## Pursuant to the provisions of 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 include: ## A. NERC Customer Complaint Unit (NERC-CCU): This is a unit at the Consumer ## Affairs Division of the Commission dedicated to the management of customer ## complaints against the DisCos; i.e., the Unit does not directly resolve ## complaints but rather tracks the resolution of the complaints by the DisCos. ## Customers can lodge complaints at the NERC CCU for onward passage to ## the respective DisCos for resolution via emails, letters or phone calls (through ## the NESI Call Centre). ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 ## The NEaI call centre which was launched by the Commission in 2023, ## provides a centralised portal for customers to pass complaints directly to their ## service providers. Being a centralised portal, it provides the Commission with ## near real-time visibility into the filing and resolution of customer complaints ## by the DisCos pursuant to the provisions of the CPR 2023. ## B. DisCo Customer Complaint Unit (DisCo-CCU): The CPR 2023 mandates all ## DisCos to establish customer complaint units (CCU) across their franchise area ## dedicated to the receipt and resolution of complaints from customers. ## Complaints can be lodged with the DisCo via electronic means including ## phone calls, SMS, email, etc. 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 satisfied with the resolution of their complaints at the DisCo- ## CCU. As of 31 December 2024, the Commission had twenty-seven (27) ## operational Forum Offices in twenty-six (26) states and the FCT, Abuja. The ## details, including names, addresses and contacts of the Commission’s Forum ## Offices are contained in Appendix C.4. ## 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 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 have jurisdiction over the customer complaints from the **state.** ## Nigerian Electricity Regulatory Commission * * * 5.16 Customer Complaints Received in 2024 This subsection provides a summary of the types of complaints and resolution rates of complaints across the various channels explained in section 5.1.3 above. 5.1.4.1 NERC CCU In 2024, 16,882 complaints were received at the Commission’s CCU - Ikeja (7,392), Eko (3,664) and Abuja (2,548) DisCos recorded the highest number of complaints by their customers, accounting for 43.79%, 21.70% and 15.09% of the total, respectively. Conversely, Kano DisCo (55) and APLE (42) had the lowest number of complaints, corresponding to 0.33% and 0.25%, respectively. Cumulatively, 4,858 were resolved, corresponding to a 28.78% resolution rate. The most common issues among the 16,882 complaints received were billing (33.59%), metering (28.62%), service interruption (15.06%) and customer band (12.36%). The four (4) complaint categories cumulatively accounted for 89.62% of the total complaints in the year (Figure 5.1). Figure 5.1: Category of Complaints Received at the Commission’s CCU in 2024 * * * 5.16 .2 DisCo CCU The total number of complaints received across all DisCos in 2024 was 1,183,198 – Port Harcourt, Eko and Ibadan DisCos received the highest complaints (222,007, 214,175 and 209,562, representing 18.76%, 18.10% and 17.71% of total complaints, respectively). In comparison, Yola DisCo and APLE had the lowest complaints (9,321 and 18,053 representing 0.79% and 1.53% of the total complaints, respectively). The most common issues among the complaints received by DisCos during the year were metering (49.62%), billing (14.28%), and service interruption (8.42%). These three (3) complaints categories cumulatively accounted for 72.33% of the total complaints in the year (Figure 5.2). The most common issues among the complaints received by DisCos during the year were metering (49.62%), billing (14.28%), and service interruption (8.42%). These three (3) complaints categories cumulatively accounted for 72.33% of the total 5.1.4.3 NERC Forum Offices A summary of the appeals across the Forum Offices in 2024 is contained in Table 5.2. In total, the Forum Offices had 8,351 (7,575 new appeals and 776 pending appeals) active appeals through 2024. The Forum Office serving Ibadan (2,676) and Ikeja (1,563) DisCos received the highest number of appeals (corresponding to 32.04% and 18.71% of total appeals respectively) while Yola DisCo (76) and APLE (21) received the fewest appeals corresponding to 0.91% and 0.25% of total appeals respectively. Cumulatively, the Forum Offices had 308 sittings in 2024 and resolved 83.06% (6,936) of the total active appeals. The breakdown of the various categories of appeals received at the Forum Offices is presented in Figure 5.3. Billing and metering were the most prevalent complaints within the year, accounting for 52.81% and 29.77% of the total appeals respectively. Cumulatively, the Forum Offices had 308 sittings in 2024 and resolved 83.06% (6,936) of the total active appeals. The breakdown of the various categories of appeals received at the Forum Offices is presented in Figure 5.3. Billing and metering were the most prevalent complaints within the year, accounting for 52.81% and 29.77% of the total appeals respectively. Table 5.2: Appeals Handled by Forum Offices in 2024 | Forum Offices | DisCos | Appeals Received¹ | Appeals Resolved | Appeals Pending² | Resolution Rate(%) | No of Sittings | | --- | --- | --- | --- | --- | --- | --- | | Abuja, Lafia & Lokoja | Abuja | 232 | 204 | 28 | 87.93 | 24 | | Ado-Ekiti,Asaba & Benin | Benin | 413 | 356 | 54 | 86.20 | 26 | | Eko | Eko | 796 | 694 | 98 | 87.19 | 24 | | Abakaliki,Akwa,Enugu,Owerri&Umuahia(including APLE cases) | Enugu | 1,192 | 969 | 106 | 81.29 | 65 | | Abeokuta,Ibadan,Ilorin&Osogbo | Ibadan | 2,676 | 1,916 | 480 | 71.60 | 76 | | Ikeja | Ikeja | 1,563 | 1,520 | 43 | 97.25 | 28 | | Bauchi,Gombe,Jos&Makurdi | Jos | 170 | 129 | 22 | 75.88 | 6 | | Gusau,Kaduna,Kebbi&Sokoto | Kaduna | 150 | 107 | 22 | 71.33 | 14 | | Jigawa,Kano&Katsina | Kano | 107 | 82 | 11 | 76.64 | 5 | | Calabar,Port Harcourt&Uyo | P/H | 976 | 894 | 68 | 91.60 | 35 | | Yola | Yola | 76 | 65 | 8 | 85.53 | 5 | | All Forum Offices | All | 8,351 | 6,936 | 940 | 83.06 | 308 | Appeals received include outstanding complaints from the preceding year as well as complaints rejected and withdrawn. 2\. During the year, 320 appeals were rejected while 155 appeals were withdrawn. Some of the pending appeals are still within the regulatory timeframe of 2 months to resolve. * * * Figure 5.3: Category of Complaints Received by all Forum Offices in 2024 To ensure DisCos comply with the rulings of the Forum Offices, the Commission has included “Compliance with forum rulings” as one of the indices contained in the Order on Performance Monitoring Framework. As contained in the KPI order, a DisCo is fined ₦10,000 per day for non-compliance with the forum ruling. Furthermore, the Commission is exploring strategies to improve the operational efficiency of Forum Offices such as ensuring that the forum panels sit regularly to increase the resolution rate and reduce the number of pending appeals carried over across years. The Commission also undertakes regular training and capacity development for members of the forum panel to equip them to deliver on their mandates. * * * ## Consumer Affairs NERC Annual Report 2024 **A cross-section of forum members at the capacity development training held in Abuja, April 2024.** **5.2 Stakeholder Engagements** ## The Commission engages relevant stakeholders as well as the public to apprise them ## of the Commission’s activities. The main avenues for interface between the ## Commission and stakeholders are: ## A. NESI stakeholder meetings ## B. Trainings/Workshops ## C. Other stakeholder engagement activities ## 5.2.1 Nigerian Electricity Supply Industry (NESI) Stakeholder Meetings ## The NESI meetings are periodic gatherings of all stakeholders in the NESI to ## deliberate on important industry issues and to review compliance and performances. ## The meetings usually have in attendance the executives of DisCos, GenCos, ## Transmission Service Provider (TSP), System Operator (SO), Market Operator ## (MO), Nigerian Bulk Electricity Trading (NBET) Company, Rural Electrification ## Agency (REA), other FGN Stakeholders and Development Partners (on an ad-hoc ## basis). Four (4) NESI meetings were held in 2024 (Table 5.3). ## Nigerian Electricity Regulatory Commission 10A * * * Table 5.3: NESI Meetings held in 2024 | S/N | NESI Meeting | Date | Location | | --- | --- | --- | --- | | 1 | Q1 NESI meeting | 12 February 2024 | Lagos, Nigeria | | 2 | Q2 NESI meeting | 24 June 2024 | Abuja, Nigeria | | 3 | Q3 NESI meeting | 02 September 2024 | Lagos, Nigeria | | 4 | Q4 NESI meeting | 03 December 2024 | Lagos, Nigeria | NERC Commissioners and other participants at the second quarter NESI meeting held in Abuja, June 2024 * * * ## Consumer Affairs NERC Annual Report 2024 **A cross-section of participants at the fourth quarter NESI meeting held in Lagos, December 2024** **5.2.2 Summit on Accelerating Scale-up of Renewable and Distributed Energy** ## Resources in Nigeria ## The summit on Accelerating Scale-up of Renewable and Distributed Energy ## Resources in Nigeria was organised by the Commission between July 22-23, 2024, ## in Abuja. The summit focused on discussing strategies, regulatory frameworks, and ## financing options to promote the development of grid-scale renewable energy ## projects in Nigeria. It was a significant event for fostering partnerships and driving ## the expansion of renewable and distributed energy access in Nigeria. The ## discussions and commitments made during the summit are expected to drive the ## adoption and incorporation of renewable and distributed energy access in the **country.** ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 **The Minister of Power, Chief Adebayo Adelabu declares open the summit on Accelerating Scale** **Up of Renewables and Distributed Energy Resources in Abuja, July 2024** ## Nigerian Electricity Regulatory Commission * * * Participants and other NESI stakeholders at the summit on Accelerating Scale Up of Renewables and Distributed Energy Resources in Abuja, July 2024 5.2.3 Other Stakeholder Engagements The Commission held a series of other stakeholder engagements and activities during the year, including workshops, training, customer service week celebrations as well as hosting various stakeholders who paid courtesy visits to the Commission. The summary of the Commission’s engagements with external stakeholders during the year is contained in Table 5.4. Table 5.4: Stakeholder engagements and other activities of the Commission in 2024 | S/N | Event | Date | Location | | --- | --- | --- | --- | | | Trainings/Workshops | | | | 1 | Capacity building workshop for members of the Nigerian Bar Association (NBA) | 07 February 2024 | NERC HQ, Abuja | | 2 | Seminar for judges from the Federal and State High Courts as well as the National Industrial Court. | 19-21 February 2024 | National Judicial Institute(NJI),Abuja | | 3 | Training for NERC Forum Panel members | 25 April 2024 | NERC HQ, Abuja | | 4 | Capacity building workshop for representatives of Civil Society Organisations(CSO)and Community Based Organisations(CBO) | 29-30 April 2024 | NERC HQ, Abuja | | 5 | A three-day workshop on Technical Codes for Operators in the NESI | 29-31 July 2024 | NERC HQ, Abuja | 5 A three-day workshop on Technical Codes for 29 – 31 July 2024 NERC HQ, Abuja Operators in the NESI * * * NERC Annual Report 2024 | S/N | Event | Date | Location | | --- | --- | --- | --- | | 6 | Training on Average Participation Method for Regional Electricity Transmission by ECOWAS Regional Electricity Regulatory Authority (ERERA) | 16 September 2024 | NERC HQ, Abuja | | | Courtesy Visits | | | | 7 | Courtesy call by a delegation from the Autorité de Régulation du secteur de l'Electricité (ARE) | 30 January 2024 | NERC HQ, Abuja | | 8 | Courtesy visit to the Nigerian Bar Association (NBA) | 01 February 2024 | NBA Secretariat, Abuja | | 9 | Courtesy visit by the leadership of the NBA | 06 February 2024 | NERC HQ, Abuja | | 10 | Courtesy visit to the Federal Competition and Consumer Protection Commission (FCCPC) | 30 February 2024 | FCCPC HQ, Abuja | | 11 | Familiarisation visit by the House of Representatives Committee on Delegated Regulations | 22 March 2024 | NERC HQ, Abuja | | 12 | Courtesy visit by the Chartered Institute of Power Engineers of Nigeria (CIPEN) | 23 April 2024 | NERC HQ, Abuja | | 13 | Oversight visit by the Senate Committee on Power | 23 April 2024 | NERC HQ, Abuja | | 14 | Courtesy visit by the Ambassador of Spain and a Spanish energy solution firm | 25 April 2024 | NERC HQ, Abuja | | 15 | Courtesy visit by a delegation from the Norwegian embassy | 08 May 2024 | NERC HQ, Abuja | | 16 | Courtesy call by a delegation from the Kano State energy committee | 09 May 2024 | NERC HQ, Abuja | | 17 | Courtesy visit by the management team of the Rural Electrification Agency (REA) | 10 May 2024 | NERC HQ, Abuja | | 18 | Courtesy call by the leadership of the Institute of Chartered Accountants of Nigeria (ICAN) Abuja district | 31 May 2025 | NERC HQ, Abuja | | 19 | Courtesy visit by a delegation from the Nigerian Economic Summit Group (NESG) | 13 June 2024 | NERC HQ, Abuja | | 20 | Oversight visit by the House of Representatives Committee on Power | 23 July 2024 | NERC HQ, Abuja | | 21 | Working visit to the National Youth Service Corps (NYSC) | 21 August 2024 | NYSC HQ, Abuja | | | Other Activities | | | | 22 | Media engagement with NESI stakeholders | 17 January 2024 | NERC HQ, Abuja | | 23 | Award ceremony for the winners of the annual energy essay competition | 15 June 2024 | NERC HQ, Abuja | | 24 | NERC and NESI Health and Safety Managers Meeting | 26 June 2024 | NERC HQ, Abuja | | 25 | Inauguration of members of the Anti-Corruption and Transparency Unit (ACTU) by the Independent | 30 July 2024 | NERC HQ, Abuja | * * * NERC Annual Report 2024 | S/N | Event | Date | Location | | --- | --- | --- | --- | | 26 | Corrupt Practices and Other Related Offences Commission | | | | Engagement with members of the Civil Society Organisations (CSO) and Community-Based Organisations (CBO) | 12 October 2024 | NERC HQ, Abuja | | | 27 | Peer review meeting with compliance and regulatory officers of licensees | 11 November 2024 | NERC HQ, Abuja | NERC Chairman and some Commissioners at the press briefing in Abuja, January 2024 NERC Commissioners with a delegation of regulatory officers from the Autorité de Régulation de l'Électricité (ARE) in Abuja, January 2024. * * * ## Consumer Affairs NERC Annual Report 2024 **NERC delegation led by the Commissioner for Consumer Affairs during a courtesy visit to the Federal** **Competition and Consumer Protection Commission (FCCPC) in Abuja, February 2024.** **Delegations from NERC and NBA during the courtesy visits to the NBA secretariat and NERC HQ in Abuja,** **February 2024.** ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 **Participants at the three-day seminar for judges at the NJI complex in Abuja, February 2024** **NERC Chairman and other Commissioners at the seminar for judges at the NJI, February 2024** **Minister of Power, Chief Adebayo Adelabu (left) and NERC Chairman delivering their speech at the seminar** **for judges, February 2024** ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 **NERC Chairman and Commissioner for Engineering and Performance Monitoring with the delegation from the** **Chartered Institute of Power Engineers of Nigeria (CIPEN) in Abuja, April 2024.** **NERC Commissioners with the Chairman and other members of the Senate Committee on Power in Abuja,** **April 2024.** ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 **NERC forum panel members at the capacity-building training in Abuja, April 2024.** **NERC Commissioners with a delegation led by the Spanish Ambassador to Nigeria in Abuja, April 2024.** **NERC Commissioners with a delegation from the Norwegian embassy in Abuja, May 2024.** ## Nigerian Electricity Regulatory Commission 11A * * * Participants at the petition hearing of the Manufacturers Association of Nigeria in Abuja, May 2024 * * * ## Consumer Affairs NERC Annual Report 2024 **Top three winners of the 2024 NERC electricity essay competition, June 2024** **Commissioners and staff of NERC at the 2024 NERC Customer Service Week, October 2024** ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2024 **Cross Section of participants at the seminar for Justices of the Supreme Court and Court of Appeal in Ikot** **Ekpene, October 2024** **Participants at the public hearing on the incessant grid disturbances in the NESI, October 2024.** ## Nigerian Electricity Regulatory Commission * * * # Chapter Six: Electricity Tariffs * * * # A69 Introduction # A6: Components of Electricity Tariff # A6;( Multi-Year Tariff Order (MYTO) # A6 ( Customer Tariffs in 2024 * * * ## Electricity Tariffs NERC Annual Report 2024 ## 6.1 Introduction ## Pursuant to section 34(1)(d) of the EA 2023, the Commission is mandated to ensure ## that prices charged by licensees are fair to customers and sufficient to allow the ## licensees to fully recover their efficient cost of operation. In compliance with the ## provisions of Section 116 of the EA 2023, the Commission has since 2007 adopted ## the Multi-Year Tariff methodology for the determination of electricity tariffs to be ## charged by distribution companies in the NESI. ## 6.2 Components of Electricity Tariffs ## The components of electricity tariffs include the cost of generation, transmission, ## distribution, and administrative services (Figure 6.1). Tariffs are structured to ensure ## fairness and incentivise performance. ## Components of Electricity Tariffs **Transmission/** **Generation cost Distribution cost** **Administrative Cost** **Final retail end-user** **tariff** **\+ 7.5% VAT** **Figure 6.1: Components of Electricity Tariffs** ## The generation cost/tariff is determined using a benchmark Long Run Marginal Cost ## (LRMC) of the most economically efficient new entrant. Generation tariffs are usually ## bilaterally negotiated between the Generation Company and the off-taker; the ## negotiated rates are subject to the Commission’s approval before they become ## Nigerian Electricity Regulatory Commission * * * ## Electricity Tariffs NERC Annual Report 2024 ## effective. If components of the tariffs, e.g. gas price, are indexed to the US$, they ## will be adjusted at the time of invoicing based on the provisions of the contract. ## Transmission and distribution costs are computed based on the revenue requirement ## and the volume of energy to be traded over a specific period. The revenue ## requirements for the transmission and distribution segments of the value chain are ## determined using a building blocks approach which provides the joint benefit of ## price cap and incentive-based regulation. The three building blocks are: - **The allowed return on capital – fair (market-based) rate of return on** ## capital invested - **The allowed return of capital – recoup capital over the useful lives of the** ## assets (depreciation) - **Efficient operating costs and overheads** ## 6.3 Multi-Year Tariff Order (MYTO) **The MYTO is a regulation that is used to set cost-reflective prices for electricity in the** **industry by employing a unified way to determine total industry revenue** **requirements tied to measurable performance improvements and standards. It seeks** **to reward performance above certain benchmarks, reduce technical and non-** **technical/commercial losses and lead to cost recovery as well as improved** **performance standards from all industry operators in the NESI. The first MYTO was** **issued by the Commission in July 2008 and has been reviewed regularly pursuant** **to the provisions of the extant regulatory instruments.** ## 6.3.1 Objectives of the MYTO ## The MYTO methodology offers a transparent framework for determining electricity ## tariffs that provides for the clear disaggregation and determination of necessary ## operating costs and overheads, and a reasonable Return on Investment. Specific ## objectives of the MYTO include: ## Nigerian Electricity Regulatory Commission * * * ## Electricity Tariffs NERC Annual Report 2024 ## A. Cost recovery and financial viability-regulated entities should recover their ## efficient costs of providing electricity services, including a reasonable rate of ## return on their capital. ## B. Certainty and stability of the pricing framework – this assures the ## recoverability of returns, thereby promoting investments in the sector. ## C. Incentives for improving performance – It provides incentives to reduce costs, ## improve the quality of service and encourage efficient use of the network. ## D. Allocation of risk – It promotes the efficient allocation of risks. ## E. Simplicity and cost-effectiveness – the MYTO was designed to be easy to ## understand and implement. ## 6.3.2 Tariff Reviews ## In 2024, the Commission issued the updated Regulations on the Procedure for ## Electricity Tariff Reviews in the NESI (NERC-R-002-2024). The Regulation provides ## a detailed procedure for conducting electricity tariff reviews in line with the ## provisions of the EA 2023. It also provides clarity on the responsibilities of parties ## regarding the tariff review processes, filing arrangements, timelines, fees and ## documentation required for the tariff review process in the NESI. The regulation ## further provides for the following types of reviews: ## A. Monthly/Minor review: This is done to consider changes in a limited number ## of tariff-setting macroeconomic indices such as inflation, interest rates, ## exchange rates and generation capacity. Pursuant to the provisions of the ## regulation, the monthly review shall include the review and approval for ## migration or classification/reclassification of distribution feeders based on the ## availability of supply on the feeders. The Commission may, at its discretion, ## conduct minor reviews of tariffs at shorter periods but no longer than six ## months, depending on the stability of macroeconomic indices. ## Nigerian Electricity Regulatory Commission * * * B. Major review: This is to be conducted once in five (5) years and entails a review of all inputs for tariff setting. It is a comprehensive review of all tariff assumptions to ensure the viability and efficiency of the NESI. C. Extraordinary review: This type of review is conducted where industry parameters have significantly changed, thus requiring immediate consideration for the sustainability of the licensee and the provision of service. The Regulations allow licensees that encounter significant unforeseen operational, legal or regulatory costs that can be reasonably passed on to customers to file for extraordinary tariff reviews, following which the Commission conducts electricity rate case hearings. The group of parameters which the Commission considers during tariff reviews are summarised in Table 6.1. Table 6.1: Parameters considered during Tariff Reviews | Parameters | | Generation | Transmission | Distribution | Type of Review | | --- | --- | --- | --- | --- | --- | | Exogenous(parameters outside the control of licensees) | Macroeconomic Indices(Inflation rate, Interest rate, Foreign exchange) | √ | √ | √ | Minor Review | | Endogenous(parameters within the control of licensees) | Efficient Loss Targets(Transmission loss factor\[TLF\], Aggregate Technical, Commercial and Collection Loss \[ATC&C\]) | × | √ | √ | Major/ExtraordinaryReview | | Capital Expenditure(CapEx)/Regulatory Asset Base(RAB) | × | √ | √ | | | | Operational & Maintenance cost(O&M) | × | √ | √ | | | | Energy Offtake | × | √ | √ | | | * * * ## Electricity Tariffs NERC Annual Report 2024 ## 6.4 Customer Tariffs in 2024 ## 6.4.1 Service-Based Tariff Regime (SBT) ## Pursuant to section 116(2)(c) of the EA 2023 which mandates the Commission to ## approve rates that incentivise continuous improvement of the quality of service, tariff ## reviews take into consideration the varying levels of infrastructural development in ## the utility’s network, that is directly attributable to the differential level of supply ## experienced by customers in the DisCo’s network. ## In August 2020, the Commission issued the MYTO 2020, marking the beginning of ## the Service-Based Tariff (SBT) regime in the NESI. The objectives of MYTO 2020 **included:** ## A. Creation of a path towards transitioning to a fully service-based cost-reflective ## tariff in the NESI. ## B. Disaggregation of the pre-existing customers’ classes and clusters, ## reclassifying them based on each DisCo’s commitment to service quality to ## them (which comprises such factors as the quantum of energy delivered, its ## voltage, and the DisCo’s average response time to resolving customer **complaints).** **C. Ensure that the tariffs are aligned with the quality and availability of electricity** ## committed to customer clusters by the DisCos. ## The customer clusters/classes specified in MYTO 2020 and expected service ## delivery are contained in Table 6.2. ## Nigerian Electricity Regulatory Commission * * * Table 6.2: Customer Cluster and Expected Service Delivery | Service Band | Minimum hours of supply | | --- | --- | | A | 20 | | B | 16 | | C | 12 | | D | 8 | | E | 4 | 6.4.2 Tariff Reviews in 2024 15 In July 2023, eleven (11) DisCos filed applications for extraordinary review of their tariffs due to the significant change in the macroeconomic environment highlighted by the liberalisation of the foreign exchange market. Pursuant to section 116 of the EA 2023 and extant regulations, the Commission considered and approved cost-reflective tariffs (CRT) for the DisCos effective 01 January 2024. Although the Commission undertakes regular reviews of the DisCos’ CRT in line with extant regulations, the allowed end-user tariffs are determined by government policy on subsidy (details below). As a result, pursuant to the subsisting government policy as at 01 January 2024, all customer tariffs across the eleven (11) DisCos were frozen at the rates set in December 2022 in spite of the significant increase in the CRT arising from the extraordinary reviews. Following the tariff review in April, the Commission carried out monthly tariff reviews pursuant to Section 7 of the April 2024 supplementary MYT Orders which provide for monthly tariff reviews to reflect the changes in the pass-through indices outside 15 Abuja, Benin, Eko, Enugu, Ikeja, Ibadan, Jos, Kaduna, Kano, Port Harcourt and Yola Nigerian Electricity Regulatory Commission the control of licensees. Between April and June 2024, the tariffs charged to band A customers were adjusted in line with the overall changes to the CRT. Effective from July 2024, the FGN issued a policy directive for all customer tariffs to be frozen at the July 2024 rates; these rates remained in effect until December 2024. In October 2024, the Commission received an application for an extraordinary tariff review from Aba Power Limited Electric (APLE). APLE is the electricity distribution company in the Aba Ring Fenced Area of Abia State. The review was initiated to address significant changes in macroeconomic parameters and operational realities affecting the electricity distribution company. Table 6.3: Summary of NERC’s Decision on APLE’s Filing | Parameter | APLE's Request | NERC Approval | | --- | --- | --- | | Nigerian Inflation | 34.60% | 34.60% | | United States Inflation | 3.20% | 3.70% | | Foreign Exchange(N/$) | N1,654.2/$1 | N1,572.2/$1 | | Gas Supply and Transportation Cost($/MMBTU) | $4.62 | $4.62 | | Available Generation | 135MW | 135MW | Nigerian Electricity Regulatory Commission * * * Electricity Tariffs | Parameter | APLE's Request | NERC Approval | | --- | --- | --- | | Generation Cost(N/kWh) | 137.39 | 135.00 | | Annual OPEX(N' billion) | 14.23 | 12.42 | | Annual Meter CAPEX(N' billion) | 13.58 | 10.85 | | Annual Other CAPEX(N' billion) | 10.38 | 10.77 | | Annual Revenue Requirement(N' billion) | 244.25 | 187.27 | | Cost-reflective tariff(N/kWh) | 240.82 | 201.11 | 6.4.3 Tariff Subsidies When the tariffs allowed for DisCos to charge customers (allowed tariff) is lower than the cost-reflective tariff as computed by the Commission, the Government undertakes to cover the resultant gap (between the cost-reflective and allowed tariff) in the form of tariff shortfall funding. The gross subsidy obligation of the FGN in 2024 is presented in Figure 6.2. The FGN directive to freeze all customer tariffs at the December 2022 approved rates despite the increase in the cost-reflective tariffs arising from the major increase in FX rates caused the FGN subsidy to reach ₦633.30 billion in 2024/Q1; this represents a 303% and 1,699% increase respectively compared to the average quarterly subsidy liability incurred in 2023 (₦157.15 billion) and 2022 (₦35.21 billion). As explained earlier, effective 01 April 2024, the tariffs for Band A customers who account for ~40% of total energy consumed across all the DisCos were reviewed to cost-reflective rates (in most DisCos). This adjustment led to a significant decrease (- 39.99%) in FGN subsidy obligations between 2024/Q1 (₦633.30 billion) and 2024/Q2 (₦380.06 billion). 16 Compared to 2024/Q2 (₦380.06 billion) * * * Electricity Tariffs is because although allowed tariffs were frozen, the cost-reflective tariffs increased due to macroeconomic factors. Figure 6.2: FGN subsidy obligation in 2024 The DRO represents the ratio of the total GenCo invoice that is billed to the DisCos by NBET based on what the allowed DisCo tariffs can cover. The DRO regime 17 replaced the Minimum Remittance 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. 17 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. * * * The 2024 average DRO of the DisCos, weighted average cost-reflective tariffs, average allowed tariffs, corresponding tariff subsidies and accrued gross subsidy required to bridge the revenue shortfall in the NESI are contained in Table 6.4. Table 6.4: DRO and Average Tariff for Non-MD Customers Across DisCos in 2024 | DisCo | Average DRO | Cost-reflective tariff(N/kWh) | Allowed Tariff(N/kWh) | Tariff Subsidy(N/kWh) | Accrued Subsidy(N'bn) | | --- | --- | --- | --- | --- | --- | | Abuja | 38% | 170.51 | 101.91 | 68.60 | 284.88 | | Benin | 34% | 190.92 | 102.47 | 88.45 | 169.20 | | Eko | 41% | 163.03 | 101.43 | 61.61 | 230.86 | | Enugu | 32% | 196.74 | 101.02 | 95.72 | 161.47 | | Ibadan | 34% | 172.18 | 101.73 | 70.44 | 236.06 | | Ikeja | 41% | 160.80 | 98.58 | 62.22 | 272.22 | | Jos | 23% | 185.74 | 95.76 | 89.98 | 117.89 | | Kaduna | 25% | 176.35 | 96.95 | 79.40 | 128.29 | | Kano | 28% | 171.17 | 99.28 | 71.89 | 124.19 | | PH | 32% | 184.56 | 100.08 | 84.48 | 149.40 | | Yola | 4% | 266.64 | 96.77 | 169.87 | 67.32 | | National | 34% | 175.31 | 100.27 | 75.04 | 1,941.78 | In 2024, Yola DisCo had the highest cost-reflective tariff compared to other DisCos due to higher operational costs and other unique factors (such as vandalism and insecurity in parts of the franchise area) which the Federal Government approved as part of the reprivatisation effort in 2021. As a result of the fact that its allowed tariffs were also identical to the rest of the DisCos, Yola DisCo enjoyed the highest subsidy cost per unit of energy delivered (~2 times the average subsidy per kWh of other DisCos). On the other hand, Ikeja and Eko DisCos had relatively lower costreflective tariffs and subsidy allocations per unit of energy delivered. * * * Electricity Tariffs 6.4.4 End-user Tariffs in Nigeria and Other African Countries A comparison of the average allowed end-use customer electricity tariff in Nigeria in 2024 and the rates charged in selected African countries (predominantly West African countries) is presented in Table 6.5. On average, across 2024, the average allowed customer tariff in Nigeria was US$0.07/kWh (approximately ₦100.27/kWh), which was the lowest tariff charged across the selected countries and represented only 35.71% of the average tariff charged in the other selected 18 countries (US$0.19/kWh). Table 6.5: Comparison of the Average Electricity Tariff in Nigeria and Selected African Countries | Country | Average Tariff($/kWh) | Average Cost(N/kWh) | | --- | --- | --- | | Nigeria | 0.07 | 100.26 | | South Africa | 0.18 | 263.70 | | Burkina Faso | 0.20 | 293.00 | | Gambia | 0.24 | 351.60 | | Ghana | 0.11 | 161.15 | | Guinea Bissau | 0.38 | 556.70 | | Ivory Coast | 0.13 | 187.52 | | Liberia | 0.35 | 512.75 | | Mali | 0.21 | 307.65 | | Mauritania | 0.15 | 212.29 | | Mauritius | 0.13 | 190.45 | | Niger | 0.12 | 174.33 | | Senegal | 0.18 | 263.70 | | Sierra Leone | 0.25 | 366.25 | | Togo | 0.18 | 263.70 | | Uganda | 0.18 | 263.70 | 1 Note: Average rate of tariffs is as of June 2024, at an exchange rate of NGN1,465/$1. (Source: Statista) While the relatively low tariff in Nigeria is largely due to the tariff subsidy provided by the FGN, the cost-reflective tariff for Nigeria (US$0.12/kWh; ₦175.31) represents only 63% of the average tariff charged in the reference countries (US$0.19/kWh). 18 The Cost of electricity for Nigeria was excluded in the computation of average cost Nigerian Electricity Regulatory Commission * * * # Chapter Seven: a—ate of the Nigerian # Electricity Supply Industry 0YPaT1 * * * 7.1 Operational Report 7.2 Indices on the Performance of the National Grid 7.2 Metering 7.3 Commercial Report * * * ## atate of the Industry NERC Annual Report 2024 ## 7.1 Operational Report ## The operational performance of the NESI is a measure of how effectively available ## resources are utilised to generate electricity. Optimum operational performance is ## essential to ensure adequate and safe electricity generation, transmission, and ## distribution. In evaluating the operational performance of the NESI in 2024, the ## following Key Performance Indicators (KPIs) were considered: ## A. Available generation ## B. Plant availability factor ## C. Total generation ## D. Generation load factor ## E. Generation mix ## 7.1.1 Available Generation ## In 2024, the average available generation capacity of the grid-connected power ## plants was 4,853.69MW. A review of monthly data showed that during 2024, the ## average available generation capacity peaked in the last third of the year (Figure ## 7.1). The highest monthly average available generation capacity during the year ## was recorded in September, largely due to the improved mechanical availability of **19** **Egbin\_1, Omotosho\_1, Olorunsogo\_1, Geregu\_2 and Rivers\_1. It is noteworthy** **that, except Zungeru\_1, all the other hydropower plants (Shiroro\_1, Kainji\_1,** **Jebba\_1, and Dadin-Kowa\_1) recorded improved availability in the last third of** **2024, owing to improved water reserves after the rainy season.** **19** **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 D 1.** ## Nigerian Electricity Regulatory Commission * * * ## atate of the Industry NERC Annual Report 2024 **6,000** **5,000** **)** **MW** **(** **4,000** **3,000** **2,000** **Average Available Capacity** **1,000** **-** **January February March April May June July August September October November December** **Figure 7.1: Average Available Capacity (MW) in 2024** ## 7.1.2 Plant Availability Factor (PAF) **The availability factor of a plant is measured as a ratio of the maximum rated output** **of the plant declared by the operator (available capacity) relative to the maximum** **rated output specified by the manufacturer (installed capacity). The available** **capacity of a plant may change from time to time due to several factors including i)** **atmospheric conditions at the plant; ii) mechanical availability of the plant (planned** **and unplanned outages); iii) feedstock availability, etc. The formula for the plant** **availability factor is represented by equation 7.1.** **Average Available Capacity (MW)** **Plant Availability Factor × 100 (7.1)** **Installed Capacity (MW)** ## The plant availability factor is a critical parameter for evaluating the overall health ## of the upstream segment of the NESI. In 2024, the overall availability factor for all ## grid-connected power plants was 37.43%. This indicates that more than 62% of the ## installed capacity of grid-connected power plants in the NESI was not available ## Nigerian Electricity Regulatory Commission * * * during the year. Overall, only eight (8) power plants had availability factors above 50% with Ihovbor\_2 recording the highest availability factor of 93.72% (Table 7.1). Conversely, Alaoji\_1 was unavailable throughout the year while Ihovbor\_1 and Omotosho\_2 recorded PAF of 1.73% and 5.77% respectively. Table 7.1: Plant Availability Factor (%) in 2024 | Plant | InstalledCapacity(MW) | Average AvailableCapacity in 2024 | Plant AvailabilityFactor in 2024(%) | | --- | --- | --- | --- | | Ihovbor\_2 | 461 | 432.05 | 93.72 | | Ikeja\_1 | 110 | 96.93 | 88.12 | | Jebba\_1 | 578 | 378.25 | 65.44 | | Dadin-Kowa\_1 | 40 | 25.60 | 64.01 | | Shiroro\_1 | 600 | 327.02 | 54.50 | | Okpai\_1 | 480 | 258.52 | 53.86 | | Zungeru\_1 | 700 | 372.12 | 53.16 | | Kainji\_1 | 760 | 399.55 | 52.57 | | Odukpani\_1 | 625 | 308.27 | 49.32 | | Afam\_2 | 650 | 280.49 | 43.15 | | Egbin\_1 | 1320 | 558.35 | 42.30 | | Geregu\_2 | 435 | 179.01 | 41.15 | | Delta\_1 | 900 | 350.95 | 38.99 | | Rivers\_1 | 180 | 69.12 | 38.40 | | Ibom power\_1 | 190 | 72.27 | 38.04 | | Omotosho\_1 | 335 | 124.20 | 37.07 | | Geregu\_1 | 435 | 159.14 | 36.58 | | Olorunsogo\_1 | 335 | 121.61 | 36.30 | | Igbafo\_1 | 45 | 15.98 | 35.51 | | Omoku\_1 | 150 | 49.07 | 32.72 | | Trans Amadi\_1 | 100 | 12.91 | 12.91 | | Sapele Steam\_1 | 720 | 79.15 | 10.99 | | Olorunsogo\_2 | 750 | 70.68 | 9.42 | | Sapele\_2 | 500 | 31.06 | 6.21 | | Afam\_1 | 726 | 43.85 | 6.04 | | Ihovbor\_1 | 500 | 28.83 | 5.77 | | Omotosho\_2 | 500 | 8.67 | 1.73 | | Alaoji\_1 | 500 | 0.05 | 0.01 | | Total | 13,625 | 4,853.69 | 37.43 | The low overall availability factor of the power plants in the NESI is a major reason why there are limited energy flows on the National grid. The major contributory factors to the low PAF experienced in the NESI include: * * * ## atate of the Industry NERC Annual Report 2024 - **Aged generation units and poor maintenance: As of December 31 2024, the** ## average plant in the NESI is 22 years old. This, combined with the poor ## maintenance record of the units (caused in part by the liquidity challenges ## explained below) means that the majority of the grid-connected generating ## units suffer frequent incidents of unscheduled outages. - **Liquidity challenges at the upstream segment of the NESI (applicable to all** ## GenCos): this is caused by the gross underpayment of GenCo invoices by ## DisCos (market shortfall) and the Government (unpaid subsidy costs). Without ## sufficient cash flows, GenCos cannot maintain their generation units, leading ## to extended outages. The liquidity challenges have also prevented operators ## of the privatised generation assets from recovering capacity that had been ## inoperable before privatisation. - **Gas supply challenges (applicable to thermal GenCos): this is caused by the** ## lack of a reliable gas supply to the plants due to gas infrastructure constraints ## on the national gas network and the absence of fully effective Gas Supply **20** **Agreements (GSA). As of the end of December 2024, only five (5) plants** **out of the total twenty-three (23) thermal plants are operating with fully** **effective GSAs. This means that the remaining eighteen (18) plants secure gas** **21** **on a “best endeavour basis ” which puts them at great risk of having their** **supply curtailed by the suppliers when there is a reduction in gas production.** ## Improving liquidity flows to GenCos through the enforcement of payment discipline ## on DisCos and the timely payment of subsidies by the Federal Government are ## essential to allowing GenCos to fund much-needed capital expenditures. This will ## allow them to reclaim units that have been inoperable for extended periods and **20** **The generation companies include Azura Power West Africa Ltd, Omotosho Power Plc, Olorunsogo Power** **Plc, Nigerian Agip Oil Company Ltd, and Shell Petroleum Development Company of Nigeria Ltd.** **21** **Best endeavour basis refers to a situation where parties (i.e., GenCos and Gas suppliers) transact without a** **fully effective contract, therefore there are limited service requirements and obligations between parties.** ## Nigerian Electricity Regulatory Commission * * * ## atate of the Industry NERC Annual Report 2024 ## fund the preventive maintenance of operable units to prevent frequent unscheduled ## mechanical failures/outages. ## To manage the overall availability of plants on the grid, the System Operator (SO) ## must implement the provisions of section 22.3 of the Grid Code on scheduling **outages in a way that does not put the grid at risk of low gross availability.** **Furthermore, GenCos must engage with the gas subsector to ensure that scheduled** **outages for the generation units are aligned with planned outages on the gas** **infrastructure (e.g. pipeline maintenance).** ## 7.1.3 Total Generation **The hourly output produced by all the units in a power plant fluctuates based on grid** **demand, mechanical operability of the unit(s), and the availability of feedstock.** **Plants are only dispatched when the load on the grid is sufficient to offtake the energy** **while operating within acceptable technical limits. The factors that determine the** **dispatch of a plant include:** ## A. Plant availability (mechanical and feedstock) ## B. Load offtake on the grid ## C. Financial competitiveness of the plant in the economic merit order dispatch. ## The average hourly generation on the National Grid in 2024 was 4,222.87MWh/h, ## which translates to a total generation of 37,093.70GWh (equation 7.2). **Total Generation Hourly Generation (MWh/h) × 24hrs × No of days in the year (7.2)** ## The lowest monthly average hourly generation on the National Grid in 2024 ## (3,796.11MWh/h) was recorded in February, while the highest monthly average ## (4,524.21MWh/h) was recorded in December (Figure 7.2). ## Nigerian Electricity Regulatory Commission * * * 2024 Average Hourly Generation = 4,222.87MWh/h Figure 7.2: Average Hourly Generation (MWh/h) in 2024 7.1.4. Plant Share (%) of Generation Output The generation share is a percentage of the total energy generated within a specified period. The generation share of a power plant is affected by its size (installed capacity), feedstock availability, and mechanical availability within the year as well as its rank within the merit dispatch order. The contribution of nineteen (19) power plants out of the twenty-eight (28) gridconnected power plants, which accounted for 95.99% of the total electricity generated in 2024, is presented in Figure 7.3. Egbin\_1 had the highest share of generation output (11.86%) compared to the other power plants. Ihovbor\_2 (8.96%) and Kainji\_1 (8.80%) had more than 8% share of generation output in 2024. Conversely, Omotosho\_2 accounted for the lowest share of output, contributing 0.12% of the total energy generated within the year. * * * atate of the Industry Figure 7.3: Average Share (%) of Generation Output by Power Plants in 2024 7.1.5 Generation Load Factor 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 7.3. $$ \\text {L o a d F a c t o r} = \\frac {\\text {T o t a l E n e r g y G e n e r a t e d (M W h)}}{\\text {A v e . A v a i l a b l e C a p a c i t y (M W)} \\times 2 4 \\mathrm {h r s} \\times \\text {P e r i o d (i n D a y s)}} \\times 1 0 0 \\tag {7.3} $$ The overall load factor for all grid-connected power plants in 2024 was 87.00%; meaning that 13.00% of available energy (MWh) was not dispatched during the year. In the absence of a Supervisory Control and Data Acquisition (SCADA) system, and provisioning for spinning reserve, the SO and DisCos do not operate × 100 (7.3) * * * the system to its limit to allow for some inherent protection against grid disturbances. Therefore, grid-connected power plants have historically been operated with load factors below 95%. The load factors of the ten (10) power plants with the highest dispatch rates in 2024 are represented in Figure 7.4. Trans Amadi\_1 and Omoku\_1 recorded dispatch rates of 100%, while nine (9) other power plants, including Kainji\_1 and Dadin Kowa\_1 hydropower plants, recorded dispatch rates above 90%. Jebba\_1 (86.02%), Zungeru\_1 (84.84%) and Shiroro\_1 (82.35%) hydropower plants recorded dispatch rates below the 90% minimum threshold contained in the 22 Commission’s Order (Order No: NERC/182/2019) on mandatory and priority dispatch of hydropower plants. Figure 7.4: Load Factor of Plants with Highest Dispatch Rate (%) in 2024 22 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. Dispatch of hydropower plants also helps to manage the flow of water thereby mitigating the risk of dam overflow and consequentially flooding. * * * ## atate of the Industry NERC Annual Report 2024 ## 7.1.6 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 ## elements of the energy trilemma: **23** **A. Energy Security** **24** **B. Energy Sustainability** **25** **C. Energy Affordability/Equity** ## The formula for the share of electricity generated by fuel source is given by equation **7.4.** **Total Electricty Generated from Fuel i (MWh)** **Share of Fueli× 100 (7.4)** **Total Electricity Generated from all Fuel Sources (MWh)** ## The contribution from hydropower plants to total generation in 2024 was 30.92% ## (11,469.85GWh). The National Control Centre (NCC) tracks the daily water levels ## at all hydropower plants and manages the dispatch of the plants to ensure that there **is sufficient water in the plants’ reservoirs to allow them to run during the peak of** **the dry season albeit with limited output compared to the wet season. This is critical** **to grid stabilisation as it allows for year-round security of supply from the** **hydropower plants which are all located in the northern part of the country.** **23** **This reflects a nation’s capacity to meet current and future energy demands reliably, withstand, and bounce** **back from system shocks with minimum disruption to supplies.** **24** **This represents the transition of a nation’s energy system towards mitigating and avoiding potential** **environmental harm and climate change impacts.** **25** **This reflects a nation’s ability to provide universal access to affordable, fairly priced and abundant energy** **for domestic and commercial use.** ## Nigerian Electricity Regulatory Commission * * * ## atate of the Industry NERC Annual Report 2024 ## 7.2 Indices on the Performance of the National Grid ## The Transmission Company of Nigeria (TCN) which has the responsibility of ## transporting energy from power plants to distribution substations holds two licences; ## Transmission Service Provider (TSP) and System Operator (SO). The TSP owns and ## maintains the transmission infrastructure while the SO is responsible for maintaining ## system stability, load balance, load dispatch and undertaking market operations **responsibilities.** ## Pursuant to Section 15 of the EA 2023, the Commission issued the Order on the ## Establishment of the Independent System Operator (ISO) in May 2024. Pursuant to ## the provisions of the Order, the TCN was unbundled into two entities; the TSP and ## the Nigerian Independent System Operator Nigeria Limited (NISO). The TSP will ## retain ownership and maintenance of the transmission infrastructure while the NISO ## will perform market and system operation functions of the TCN. ## To assess the performance of the grid, the Commission focuses on the following four ## (4) Key Performance Indicators (KPIs) that relate to power transmission: ## A. Transmission loss factor ## B. Stability of grid frequency ## C. Voltage fluctuation ## D. Incidence of system collapse ## 7.2.1 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 local and international ## bilateral 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 ## Nigerian Electricity Regulatory Commission * * * improvement in transmission efficiency over a given period. The formula for TLF is represented by equation 7.5. $$ \\mathrm {T L F} = \\left(1 - \\frac {\\mathrm {E n e r g y D e l i v e r e d t o a l l D i s C o s + E n e r g y E x p o r t e d}}{\\mathrm {E n e r g y S e n t o u t b y a l l G e n C o s}}\\right) \\times 1 0 0 $$ × 100 (7.5) 26 The average TLF in 2024 was 8.71%, as shown in Figure 7.5. A TLF of 8.71% indicates that for every 100MWh of energy injected into the grid, 8.71MWh of the energy was undelivered to DisCos and international customers due to losses in the transmission network or consumption at the transmission substation. $$ 8\. 71 % ^ {2 6} $$ The average TLF of 8.71% recorded in 2024 represents an under-performance of - 1.71pp relative to the MYTO target for 2024 (7.00%). The 7.00% TLF target set by the Commission for 2024 represents the maximum efficient transmission loss, which is to be recovered from tariffs paid by the customers. When the TLF exceeds the set target, the additional cost is borne solely by the TSP because there is no provision to recover revenues needed to cover excess (inefficient) losses from customers. The Commission has directed TCN to work on a mechanism to identify the drivers of TLF so that they can develop solutions to maintain the TLF on the grid within the limits approved in its tariff. 26 The TLF for May has been excluded in the computation of the 2024 average TLF because of the extraordinarily low TLF recorded in the month. The low TLF in May is because the energy injected into the grid by Zungeru\_1 between 29 April to 15 May 2024 was not apportioned to DisCos and thus was used to net off transmission losses on the grid during the period. * * * Figure 7.5: Actual TLF (%) vs. MYTO TLF Target (%) in 2024 7.2.2 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 tolerance 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 deviation 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. * * * A system’s stability over a given period is measured by its ability to operate as close as possible to the 50Hz benchmark set in the Grid Code; this means that the lower the range between the average upper daily system frequency and the average lower daily system frequency, the more stable the system has been. In 2024, the average upper daily system frequency was 50.83Hz, while the average lower daily system frequency was 49.28Hz, which translates to a range of 1.55Hz. Figure 7.6: Monthly System Frequency (Hz) from Jan – Dec 2024 Figure 7.6 shows that the monthly average upper and lower bounds of the system frequency were both outside the normal operation limits but within the stress limits throughout 2024. The consistent operation of the grid outside the normal frequency limits during the year 2024 indicates an imbalance in the supply and demand of electricity on the grid, which is primarily caused by the lack of a Supervisory Control and Data Acquisition (SCADA) system that provides for real-time grid monitoring and load management. * * * ## atate of the Industry NERC Annual Report 2024 ## Since 2022, the SO has introduced an IoT-based solution to improve real-time ## visibility into the operations of the grid. However, the inability to remotely operate ## the entire system as would be possible under the SCADA system continues to pose ## challenges to the SO’s ability to operate the grid within the normal operational ## frequency limits. ## 7.2.3 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. ## The system voltage pattern for 2024 is illustrated in Figure 7.7. The average upper ## and lower operating voltage bounds for the transmission network in 2024 were ## 352.55kV and 299.42kV, respectively (range of 53.13kV); both values are outside ## their respective allowable limits, which shows that the grid performance did not ## comply with the standard specified in the Grid Code. ## The Commission continues to engage with TCN and other stakeholders to ensure ## sustained efforts at keeping the system voltage within the regulated limits, providing ## a safe and reliable electricity supply to end users. ## Nigerian Electricity Regulatory Commission * * * Figure 7.7: Monthly System Voltage (kV) in 2024 7.2.4 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 it 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 collapse. $$ (3 3 0 \\mathrm {k V} \\pm 5. 0 %) $$ 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 may cause the units to shut down. This often exacerbates the frequency imbalance on the grid, thereby causing more generation units to shut down, resulting in a full or partial system collapse. * * * There were nine (9) incidents of system collapse in 2024. The summary of grid collapse incidents between 2019 and 2024 is contained in Table 7.2 and the details of the system collapse recorded in 2024 are contained in Table 7.3 respectively. Table 7.2: System Collapses in 2019 – 2024 | | No. of Collapses | | | | | | | --- | --- | --- | --- | --- | --- | --- | | Category of Collapse | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | | Partial Collapse | 1 | 0 | 2 | 2 | 0 | 5 | | Total Collapse | 10 | 4 | 2 | 4 | 3 | 4 | * * * Table 7.3: System collapse incidents in 2024 | SN | Date and Time of Collapse | Type of Collapse | Data and Time of full system restoration | Remarks | | --- | --- | --- | --- | --- | | 1 | 04/02/202411:21Hrs | Partial | 04/02/202418:15Hrs | The cascaded tripping of Sapele steam on gas constraints(29.2MW)和 Egbin G.S units on units' faulty transmitters(343.8MW) initiated the instability on the grid. | | 2 | 28/03/202416:28Hrs | Full | 28/03/202420:27Hrs | The cascaded tripping of Sapele steam(93.95MW)和 Egbin G.S units(518.55MW) initiated the instability that caused the collapse. | | 3 | 15/04/202402:41Hrs | Partial | 15/04/202410:55Hrs | The cascaded tripping of Afam VI(305MW)和 Afam III(25MW) due to the fire incident at Afam T.S initiated the system instability on the grid and islanded Ibom power | | 4 | 06/07/202415:09Hrs | Partial | 06/07/202423:56Hrs | The cascaded tripping of Egbin G.S units(347.0MW), Odukpani NIPP units(308.7MW)和 Jebba G.S units(260.0MW) initiated the instability on the grid. | | 5 | 14/10/202418:48Hrs | Partial | 15/10/202416:14Hrs | The cascading tripping of Jebba-Osogbo 330kV lines1&2)(ccts2JEB-SGB1&2),Jebba-Ganmo 330kV line(cct2JEB-GAM1),Ikeja West - Osogbo 330kV line(cct2KJW-SGB1)和 Ihovbor-Osogbo 330kV line(cct2HVR-SGB1) initiated the instability that eventually caused the system disturbance. | | 6 | 19/10/202408:15Hrs | Full | 19/10/202417:57Hrs | The explosion of the yellow phase Current Transformer of the Bus-Section at Jebba TS triggered the tripping of all lines connected to Jebba TS,resulting in the loss of Jebba generation and subsequent loss of Shiroro,Zungeru and Kainji generating units.This event initiated the instability that eventually led to the system disturbance. | | 7 | 05/11/202413:52Hrs | Partial | 05/11/202423:37Hrs | The cascaded tripping of Osogbo-Ayede 330kV line1(circuit2SGB-YDE1),Osogbo-Ganmo 330kV line1(circuit2SGB-GAM1),and Osogbo-Ikeja West 330kV line1(circuit2SGB-KJW1) initiated the instability on the grid,this was further aggravated by the tripping of Osogbo-Ihovbor 330kV line1(circuit2HVR-SGB1),and Ughelli/Sapele 330kV line1(circuit2UGH-SAP1)which eventually caused the system disturbance. | * * * atate of the Industry | SN | Date and Time of Collapse | Type of Collapse | Data and Time of full system restoration | Remarks | | --- | --- | --- | --- | --- | | 8 | 07/11/202411:29Hrs | Full | 08/11/202410:59Hrs | The tripping of the following circuits:2SHR-KTP1,2SHR-GWA1,2JEB-SGB2,2SGB-KJW1,2SGB-YDE1 with subsequent tripping of 2HVR-SGB1 and 2SGB-GAM1 initiated the instability that eventually led to the system disturbance. | | 9 | 11/12/202413:32Hrs | Full | 11/12/202420:07Hrs | The tripping of the following circuits and generators:Kainji-Jebba 330kV Line 1(circuit 2KNJ-JEB1),Jebba G.S-Jebba T.S 330kV Line 1(circuit 1JEG-JEB1),Jebba G.S unit 2G1,2,3,4&6and Kainji G.S unit 1G5,6,7,11&12with a generation loss totalling731.48MW initiated the instability that eventually led to the system disturbance. | * * * 7.3 Metering The status of the metering of end-use customers is presented in Table 7.4. The total number of registered customers as of December 2024 was 13,503,342, with 6,288,642 (46.57%) of the customers metered. Table 7.4: Metering Progress as of December 2024 | DisCos | Total No.of Registered Customers2024 | No.of MeteredCustomers2024 | MeteringProgress(%)2024 | MeteringGap(%)2024 | | --- | --- | --- | --- | --- | | Aba | 206,540 | 78,281 | 37.90 | 62.10 | | Abuja | 1,195,429 | 910,942 | 76.20 | 23.80 | | Benin | 1,435,685 | 714,242 | 49.75 | 50.25 | | Eko | 729,169 | 460,187 | 63.11 | 36.89 | | Enugu | 1,396,440 | 671,760 | 48.11 | 51.89 | | Ibadan | 2,644,124 | 1,153,025 | 43.61 | 56.39 | | Ikeja | 1,286,026 | 998,986 | 77.68 | 22.32 | | Jos | 832,053 | 225,188 | 27.06 | 72.94 | | Kaduna | 884,647 | 217,033 | 24.53 | 75.47 | | Kano | 891,410 | 215,834 | 24.21 | 75.79 | | Port Harcourt | 1,179,194 | 524,256 | 44.46 | 55.54 | | Yola | 822,625 | 118,908 | 14.45 | 85.55 | | Total | 13,503,342 | 6,288,642 | 46.57 | 53.43 | 7.3.1 Metering Frameworks The five (5) frameworks that are available for DisCos to meter their customers are contained in the Meter Asset Provider and National Mass Metering Regulations (NERC-R-113-2021) which was issued in 2021. Descriptions of the frameworks are contained below - * * * ## atate of the Industry NERC Annual Report 2024 ## B. 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. ## C. Vendor Financed: 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. ## D. DisCo Financed: This involves the 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 approved by the Commission, and the terms of supply should not be ## in conflict with the terms of existing MAP and NMMP contracts. ## E. Other External Efficient Meter Financing: The Commission has also approved ## other external meter financing that is efficient, cost-effective, and in tune with ## the terms of existing MAP and NMMP contracts. ## In addition to the frameworks, the Commission created the Meter Acquisition Fund ## (MAF) in February 2024. The fund provides for a metering surcharge in the allowed ## tariffs for all DisCos. It is geared towards providing regulatory-backed long-tenor ## financing for the procurement of meters towards closing the metering gap in the ## NESI. A proportionate amount is deducted from the monthly collections of DisCos ## towards the MAF; this is then made available for DisCos to purchase meters either ## through a bulk one-off procurement or repayment of mid/long-term vendor-financed ## meter deployments. ## In April 2024, the Commission, vide the Order: NERC/2024/072 on the ## Operationalisation of Tranche A of the MAF approved the use of ₦21.00 billion out **of the funds that have accrued in the MAF as of the April 2024 settlement cycle, for** ## Nigerian Electricity Regulatory Commission 1A0 * * * DisCos to provide meters for Band A customers in their franchise area at no cost. The approved fund was distributed pro rata among the DisCos based on their contribution to the MAF scheme at the cut-off date. 7.3.2 Customer Metering in 2024 A total of 572,055 meters were installed across all DisCos in 2024 (Table 7.5) utilising all the metering frameworks (Table 7.6). Ikeja (137,261), Ibadan (108,155), and Abuja (80,932) DisCos had the highest number of meter installations, representing 23.99%, 18.91% and 14.15% respectively of the total installations. Conversely, Kano (3,156) and Yola (2,586) DisCos had the lowest number of installations, accounting for 0.55% and 0.45% respectively of the total installations. Table 7.5: Meter Deployment by DisCos in 2024 | DisCo | No. of Metered Customers as of December 2024 | No. of Customers Metered in 2024 | Percentage of Total Installations | | --- | --- | --- | --- | | Aba | 78,281 | 23,728 | 4.15 | | Abuja | 910,942 | 80,932 | 14.15 | | Benin | 714,242 | 55,105 | 9.63 | | Eko | 460,187 | 38,117 | 6.66 | | Enugu | 671,760 | 53,737 | 9.39 | | Ibadan | 1,153,025 | 108,155 | 18.91 | | Ikeja | 998,986 | 137,261 | 23.99 | | Jos | 225,188 | 36,930 | 6.46 | | Kaduna | 217,033 | 9,761 | 1.71 | | Kano | 215,834 | 3,156 | 0.55 | | Port Harcourt | 524,256 | 22,587 | 3.95 | | Yola | 118,908 | 2,586 | 0.45 | | Total | 6,288,642 | 572,055 | 100.00 | * * * Table 7.6: Meter Installations under the Metering Frameworks | S/N | Framework | Meter Installations in 2024 | | --- | --- | --- | | 1 | NMMP | 289 | | 2 | MAF | 4,076 | | 3 | MAP | 508,103 | | 4 | Vendor Financed | 27,965 | | 5 | DisCo Financed | 31,622 | | | Total | 572,055 | NMMP During the year, there were only 289 meters installed under the NMMP framework due to the winding down of its phase zero. Abuja, Eko, Ibadan, Ikeja, Jos and Port Harcourt DisCos have exhausted their meter allocations under the NMMP phase zero 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 7.7). During the year, there were only 289 meters installed under the NMMP framework due to the winding down of its phase zero. Abuja, Eko, Ibadan, Ikeja, Jos and Port Harcourt DisCos have exhausted their meter allocations under the NMMP phase zero 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 Table 7.7: Meter Installations under the NMMP Framework | 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 | 47,908 | 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 | 943,111 | 93.09 | * * * ## atate of the Industry NERC Annual Report 2024 **MAP** ## The MAP framework accounted for a total of 508,103 meter installations in 2024 ## which corresponds to 88.82% of the total installations during the year. The winding ## down of the NMMP phase zero has led DisCos to intensify metering through the ## MAP framework in an attempt to further close the metering gap in the NESI. Ikeja ## (131,263; 25.83%), Ibadan (108,071; 21.27%) and Abuja (79,069; 15.56%) ## DisCos recorded the highest number of meters installed under the MAP framework ## in 2024. Kano (1,846; 0.36%) and Yola (831; 0.16%) recorded the lowest meter ## installations under the MAP in 2024. ## Vendor Financed and DisCo Financed ## A total of 27,965 meters were installed under the Vendor Finance metering ## framework in 2024. Only five (5) DisCos; Aba (18,933), Ikeja (5,998), Abuja ## (1,863), Kano (1,135) and Benin (36) DisCos installed meters under the vendor- ## financed metering framework in 2024. ## A total of 31,622 customers were metered under the DisCo Financed framework by ## Jos (31, 442), Kano (96) and Ibadan (84) DisCos in 2024. **MAF** ## As of 31 December 2024, 4,076 meters have been installed under the MAF ## framework. Yola (1,755), Jos (1,674), Benin (568) and Kano (79) are the only ## DisCos that have commenced meter installations under the MAF. ## Nigerian Electricity Regulatory Commission 1A3 * * * ## atate of the Industry NERC Annual Report 2024 ## 7.4 Commercial Report ## 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 for all the players along the value chain to sustain ## their operations. In evaluating the commercial performance of the NESI in 2024, the ## following parameters have been considered: ## A. Energy offtake performance ## B. Energy billed and billing efficiency ## C. Revenue and collection efficiency ## D. Aggregate Technical, Commercial and Collection (ATC&C) loss ## E. Remittances to the Market Operator (MO) and the Nigerian Bulk ## Electricity Trading Company (NBET) ## 7.4.1 Energy offtake performance ## Effective 01 July 2022, the NESI transitioned into the Partial Activation of Contract ## (PAC) regime which enabled the DisCos to determine their unconstrained power ## requirements in absolute Megawatt (MW) known as their Partially Contracted ## Capacity (PCC). This marked a change from the previous regime under which energy ## was allocated to DisCo based on the percentages contained in the vesting contracts ## signed with NBET – “MYTO Load Allocation”. When the gross available generation **is below the total PCC of the DisCos, the SO shall allocate capacities to the DisCos** **in line with the guidelines for the implementation of the Economic Merit Order of** **Dispatch (EMOD) contained in the Tariff Order (NERC/2023/034) issued to the** **TCN in January 2024.** ## The PAC regime set out a framework to enable GenCos to earn capacity payments, ## i.e., payments for making an agreed generation capacity available irrespective of **whether it is dispatched by the SO or not. This is in line with international best** ## Nigerian Electricity Regulatory Commission 1A4 * * * ## atate of the Industry NERC Annual Report 2024 ## practices in power procurement contracting and it increases the predictability of ## revenue flows for GenCos, thus allowing for critical routine maintenance activities to ## improve the availability of their plants. ## The PAC regime acts as a deterrent against discretionary non-offtake of energy ## because DisCos have the obligation to make payments for all available capacity (up ## to the PCC) irrespective of actual energy offtake. To further improve contract ## discipline along the upstream segment of the NESI, the PAC regime provides for ## Liquidated Damages (LD) to be paid by GenCos to the DisCos in situations where ## the DisCo does not receive the contracted capacity due to challenges at the **27** **generation and/or transmission sub-segments. In July 2022, updated Service Level** **Agreements (SLA) were signed between DisCos and TCN to institutionalise the** **compensation mechanism for DisCos when TCN’s limitations constrain the energy** **delivered to the DisCos (up to the PCC).** ## The ratio between a DisCo’s energy offtake and the available PCC is known as the ## “energy offtake performance”. The formula for determining a DisCo’s energy ## offtake performance is represented by equation 7.6: **Energy Offtake** **Energy Offtake performance (%)** () **× 100 (7.6)** **Available PCC** ## Considering the large disparity between the energy on the national grid and ## customer demand, it is expected that DisCos will offtake 100% of their available ## PCC at all times. However, the Commission continues to observe with concern that ## many DisCos do not take their full PCC due to a combination of technical limitations ## as well as load rejection by the DisCos largely due to commercial reasons, i.e., **27** **Liquidated Damages (LD) are only due when issues are not Force Majeure i.e. the issues are within the** **control of the TCN/GenCo.** ## Nigerian Electricity Regulatory Commission 1A5 * * * instances where DisCos deliberately reduced energy supply to areas with high commercial and collection losses. It is noteworthy that when DisCos have offtake ratios below 100%, they incur increased wholesale energy costs as they still have to pay NBET/GenCos for unutilised capacity. The tariff methodology utilised by the Commission does not allow DisCos to recover the resultant additional wholesale energy costs (relative to the volume of energy off-taken) from customers. The DisCos’ load offtake performance in 2024 is presented in Table 7.8. Cumulatively, the DisCos’ offtake performance in 2024 was 94.55%. All DisCos took less energy than their PCC in 2024. Enugu (98.18%) and Benin (98.03%) recorded the highest offtake performances. Yola (85.04%) DisCo, which was the only DisCo with offtake performance below 90%, recorded the lowest offtake performance during the year. Table 7.8: Energy Offtake Performance in 2024 | DisCos | Offtake(MWh/h) | PCC(MWh/h) | Offtake Performance(%) | | --- | --- | --- | --- | | Abuja | 513.54 | 555.70 | 92.41 | | Benin | 295.87 | 301.82 | 98.03 | | Eko | 442.47 | 468.00 | 94.54 | | Enugu | 269.93 | 274.93 | 98.18 | | Ibadan | 407.94 | 421.90 | 96.69 | | Ikeja | 520.39 | 549.04 | 94.78 | | Jos | 167.86 | 184.58 | 90.94 | | Kaduna | 189.64 | 208.61 | 90.91 | | Kano | 192.59 | 207.25 | 92.93 | | Port Harcourt | 251.10 | 258.21 | 97.25 | | Yola | 73.58 | 86.52 | 85.04 | | All DisCos | 3,324.92 | 3,516.57 | 94.55 | * * * ## atate of the Industry NERC Annual Report 2024 ## 7.4.2 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 formula for billing efficiency is represented by equation 7.7. **Total Units Billed (kWh)** **Billing Efficiency (%) × 100 (7.7)** **Total Energy Received by the Network (kWh)** ## The amount of energy received by DisCos at their trading points in 2024 was ## 29,126.27GWh, out of which 23,919.68GWh was billed to the end-users, resulting ## in a billing efficiency of 82.12%. Billing Efficiency covers the technical and ## commercial loss components in the Aggregate, Technical, Commercial and ## Collection (ATC&C) loss. Some of the major factors that contribute to billing losses **include;** ## A. Poor Customer Enumeration: this is the inability of DisCos to identify all ## electricity consumers. ## B. Inaccurate Meters/Outdated Meters: this is the inability of DisCos to ## accurately measure the electricity consumed by end users due to the ## unavailability of meters or the use of obsolete meters at user sites. ## C. Energy Theft: this is the deliberate action by some electricity consumers to ## consume electricity without making payments. ## D. Technical Loss: this is the energy loss to wires and transformers (technical ## losses) which also contributes to DisCos’ billing inefficiency, and this is ## particularly relevant for areas of the network with substandard or aged **infrastructure.** ## The billing efficiency of all DisCos contained in Table 7.9 shows that Eko, Ibadan ## and Yola DisCos had the highest billing efficiencies of 89.46%, 88.78% and ## 88.04% respectively. Conversely, Kaduna recorded the lowest billing efficiency of ## Nigerian Electricity Regulatory Commission 1A7 * * * 63.24%, indicating that Kaduna DisCo lost 36.76% of the energy received in 2024 to technical and commercial inefficiencies. Table 7.9: Energy Received and Billed by DisCos in 2024 | DisCos | Total Energy Received(GWh) | Total Energy Billed(GWh) | Billing Efficiency(%) | | --- | --- | --- | --- | | Abuja | 4,498.57 | 3,510.00 | 78.02 | | Benin | 2,591.83 | 2,207.87 | 85.19 | | Eko | 3,876.01 | 3,467.65 | 89.46 | | Enugu | 2,364.63 | 1,864.77 | 78.86 | | Ibadan | 3,573.60 | 3,172.56 | 88.78 | | Ikeja | 4,558.58 | 3,803.34 | 83.43 | | Jos | 1,470.44 | 1,055.77 | 71.80 | | Kaduna | 1,661.27 | 1,050.62 | 63.24 | | Kano | 1,687.08 | 1,351.88 | 80.13 | | Port Harcourt | 2,199.67 | 1,867.71 | 84.91 | | Yola | 644.59 | 567.52 | 88.04 | | All DisCos | 29,126.27 | 23,919.68 | 82.12 | 7.4.3 Revenue and Collection Efficiency Collection efficiency is the ratio of the amount that is collected from customers compared to the amount billed to them by the DisCos. The significant under-recovery of the bills issued to customers by DisCos is driven by a lack of willingness of customers to pay bills when due, unsatisfactory DisCos’ services and inadequate customer metering, among other challenges. The formula for collection efficiency is represented by equation 7.8. The total revenue collected by the DisCos from customers in 2024 was ₦1,659.76 billion out of the total bill of ₦2,196.71 billion to customers, leaving an outstanding balance of ₦536.95 billion. This translates to a collection efficiency of 75.56% and implies that for every ₦100.00 worth of energy billed to customers by DisCos in × 100 (7.8) * * * 2024, approximately ₦24.44 was not recovered from customers. The significant collection inefficiency, combined with billing inefficiency, has continued to adversely impact the financial liquidity of the industry, ultimately limiting the NESI’s ability to grow and attract new investments. In 2024, Eko (86.85%) and Ikeja (83.37%) DisCos recorded the highest collection efficiencies among the DisCos, while Yola DisCo (51.53%) had the lowest collection efficiency (Table 7.10). Table 7.10: Revenue Performance of DisCos in 2024 | DisCos | Total Billings(N'Billion) | Revenue Collected(N'Billion) | Collection Efficiency(%) | | --- | --- | --- | --- | | Abuja | 349.97 | 275.81 | 78.81 | | Benin | 177.69 | 141.88 | 79.85 | | Eko | 352.40 | 306.05 | 86.85 | | Enugu | 163.23 | 126.05 | 77.22 | | Ibadan | 261.40 | 192.50 | 73.64 | | Ikeja | 371.22 | 309.48 | 83.37 | | Jos | 105.32 | 57.59 | 54.68 | | Kaduna | 81.87 | 43.34 | 52.94 | | Kano | 136.52 | 75.01 | 54.95 | | Port Harcourt | 155.03 | 110.35 | 71.18 | | Yola | 42.08 | 21.68 | 51.53 | | All DisCos | 2,196.71 | 1,659.76 | 75.56 | 7.4.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss The Aggregate Technical, Commercial and Collection (ATC&C) loss is the measure of the gross losses incurred by a DisCo in supplying electricity to end-use customers; it measures the revenue shortfall a DisCo suffers arising from a combination of billing (technical and commercial) as well as collection losses. The ATC&C loss comprises The Aggregate Technical, Commercial and Collection (ATC&C) loss is the measure of the gross losses incurred by a DisCo in supplying electricity to end-use customers; it measures the revenue shortfall a DisCo suffers arising from a combination of billing (technical and commercial) as well as collection losses. The ATC&C loss comprises the following components: * * * B. Commercial Loss: due to discrepancy in meter reading, erroneous billing, unmetered consumption, or energy theft. C. Collection Loss: unpaid bills. The formula for ATC&C loss is represented by equation 7.9. ATC&C Loss \[1 − (Billing Efficiency × Collection Efficiency)\] × 100 (7.9) The ATC&C loss is a critical performance parameter for tariff determination because it is used to set efficiency targets for the DisCos. The Tariff Orders issued to DisCos make allowance for specific ATC&C loss level targets for each DisCo. Just as the make allowance for specific ATC&C loss level targets for each DisCo. Just as the case of TLF explained in section 7.2.1, the Commission has the responsibility of constantly reviewing the allowed ATC&C for each DisCo to reflect the maturity of the market and investments being made by the DisCo. make allowance for specific ATC&C loss level targets for each DisCo. Just as the case of TLF explained in section 7.2.1, the Commission has the responsibility of constantly reviewing the allowed ATC&C for each DisCo to reflect the maturity of the market and investments being made by the DisCo. The average ATC&C loss for all the DisCos in 2024 was 37.95%, comprising 17.88% technical and commercial losses, and 24.44% collection loss. Collection losses (including unpaid bills from sensitive customers, disputed bills, etc.) continue to form a substantial part of the ATC&C loss. This reinforces the need for DisCos to intensify efforts in revenue collection to improve their cash flow and meet market The average ATC&C loss for all the DisCos in 2024 was 37.95%, comprising 17.88% technical and commercial losses, and 24.44% collection loss. Collection losses (including unpaid bills from sensitive customers, disputed bills, etc.) continue to form a substantial part of the ATC&C loss. This reinforces the need for DisCos to intensify efforts in revenue collection to improve their cash flow and meet market obligations. The overall ATC&C loss of 37.95% in 2024 was substantially higher than the efficient ATC&C loss provided in the MYTO for 2024 (24.73%). The inability of the DisCos to meet their allowed loss targets and the consequential inability to meet revenue requirements compromises their long-term financial position. * * * Table 7.11: ATC&C Loss of DisCos in 2024 | DisCos | MYTO Target ATC&C(%) | Actual ATC&C Loss(%) | Variance: target-actual(pp) | | --- | --- | --- | --- | | Abuja | 25.00 | 38.51 | -13.51 | | Benin | 25.00 | 31.98 | -6.98 | | Eko | 20.07 | 22.30 | -2.23 | | Enugu | 25.00 | 39.10 | -14.10 | | Ibadan | 25.00 | 34.62 | -9.62 | | Ikeja | 18.73 | 30.44 | -11.71 | | Jos | 32.72 | 60.74 | -28.02 | | Kaduna | 25.00 | 66.52 | -41.52 | | Kano | 25.00 | 55.97 | -30.97 | | Port Harcourt | 25.00 | 39.56 | -14.56 | | Yola | 56.00 | 54.63 | 1.37 | | Overall MYTO Level | 24.73 | | | | Aggregate technical, commercial & collection Loss | - | 37.95 | | | Technical & Commercial Losses | - | 17.88 | | | Collection Losses | - | 24.44 | | Eko DisCo (22.30%) recorded the lowest ATC&C, while Kaduna DisCo was the worst-performing DisCo with an ATC&C of 66.52% in 2024 (Table 7.11). This means that for every ₦100.00 worth of energy delivered by Eko and Kaduna, Eko recovered ₦77.70 in revenue while Kaduna recovered only ₦33.48 in revenue from customers. 7.4.5 Market Remittance Kaduna, Kano, and Jos DisCos had the widest variances relative to their allowed MYTO targets for the year with -41.52pp (target of 25.00% vs 66.52%), -30.97pp (target of 25.00% vs 55.97%), and -28.02pp (target of 32.72% vs 60.74%), respectively. * * * cost payable by DisCos to NBET at source in the form of a DisCo’s Remittance Obligation (DRO). The DRO represents the share of the total GenCo invoice that is 28 billed to the DisCos by NBET based on what the allowed DisCo tariffs can cover. 29 The DRO regime replaced the Minimum Remittance Obligation (MRO) framework in January 2024, and DisCos are expected to pay 100% of their DROs. The transition to the DRO regime was necessitated by the risk of unpaid tariff subsidy debts encumbering the balance sheets of the DisCos, thereby preventing them from raising finance to undertake critical investments in their distribution networks. Thus, the portion of GenCo invoices not covered by DRO is the tariff subsidy which is invoiced directly to the Federal Ministry of Finance by NBET. In addition, DisCos are also expected to remit 100% of the invoices received from the MO for transmission and administrative service costs. It is important to note that due to the absence of cost-reflective tariffs across all DisCos in 2024, the Government incurred a subsidy obligation of ₦1,941.78 billion (62.59% of total NBET invoice) during the year (Table 7.12), which translates to an average of ₦161.85 billion per month. This subsidy obligation of the FGN is largely attributable to the FGN's policy to freeze allowed tariffs paid by customers despite the increase in cost-reflective tariffs. (62.59% of total NBET invoice) during the year (Table 7.12), which translates to an average of ₦161.85 billion per month. This subsidy obligation of the FGN is largely attributable to the FGN's policy to freeze allowed tariffs paid by customers despite The gross invoice issued by NBET (DRO-adjusted) and MO for energy costs and administrative services to DisCos in 2024 was ₦1,370.35 billion. Out of this amount, the DisCos remitted a total of ₦1,184.88 billion, translating to a gross remittance 28 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. 29 For the MRO framework, DisCos are invoiced 100% of energy cost but only expected to pay MRO share of 29 For the MRO framework, DisCos are invoiced 100% of energy cost but only expected to pay MRO share of the invoice. * * * rate of 86.47%. The resultant deficit/underpayment of ₦185.47 billion is known as 30 “market shortfall” i.e. shortfall that is attributable to market participants. Table 7.12: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024 | DisCos | Total NBET Invoice (N' billion) | Final Obligation(N' billion) | FGN Subsidy(N' billion) | | --- | --- | --- | --- | | Abuja | 483.53 | 198.64 | 284.88 | | Benin | 272.41 | 103.21 | 169.20 | | Eko | 415.06 | 184.19 | 230.86 | | Enugu | 249.53 | 88.06 | 161.47 | | Ibadan | 375.69 | 139.63 | 236.06 | | Ikeja | 484.96 | 212.75 | 272.22 | | Jos | 158.38 | 40.49 | 117.89 | | Kaduna | 179.31 | 51.02 | 128.29 | | Kano | 180.20 | 56.01 | 124.19 | | Port Harcourt | 230.45 | 81.05 | 149.40 | | Yola | 72.66 | 5.34 | 67.32 | | All DisCos | 3,102.17 | 1,160.39 | 1,941.78 | A comparative analysis of DisCos’ market invoice (NBET + MO) and remittance in 2024 is presented in Figure 7.8. Eko, Ikeja, Yola and Abuja DisCos recorded remittance performances above 90% (98.56%, 94.61%, 92.10% and 90.80% respectively). Kaduna DisCo recorded the lowest remittance performance of 31.55% in 2024 due to its significant ATC&C loss underperformance, as reported in section 7.4.4. The DisCos’ disaggregated remittances to NBET and MO are summarised in Table 7.13. Out of the ₦1,160.39 billion invoice issued by NBET in 2024, DisCos remitted ₦1,005.51 billion, translating to a remittance performance of 86.65%. The topperforming DisCos were Eko (99.33%), Ikeja (94.43%) and Abuja (90.42%). Conversely, Kaduna DisCo (32.77%) recorded the lowest remittance performance to NBET in 2024. 30 Government subsidy can also be referred to as “Tariff Shortfall” i.e., shortfall which is attributable to the government’s policy that the CRT should not be passed onto customers in its entirety. * * * atate of the Industry Figure 7.8: DisCos’ Remittance Performance to NBET and MO in 2024 The MO invoice issued to the DisCos in 2024 was ₦209.95 billion, and the DisCos collectively remitted ₦179.36 billion, translating to an 85.43% remittance rate. The top-performing DisCos were Yola (96.73%), Ikeja (95.71%), Eko (93.12%) and Abuja (92.97%) with remittance rates above 90% to the MO in 2024. Conversely, Kaduna DisCo recorded the lowest remittance rate (26.29%) to MO in 2024. Based on the remittance numbers contained above and non-funding of subsidies incurred in 2024 by the Federal government of the market continues to be plagued by liquidity challenges. Under the payment 32 assurance waterfall regime, DisCos’ inability to achieve 100% remittance to the upstream segment indicates that they were unable to earn significant portions of Based on the remittance numbers contained above and non-funding of subsidies 31 , it is clear that the upstream segment of the market continues to be plagued by liquidity challenges. Under the payment regime, DisCos’ inability to achieve 100% remittance to the upstream segment indicates that they were unable to earn significant portions of 31 NBET reported that the FGN paid only ₦371.34 million out of the ₦1,941.78 billion subsidy obligation for 2024; this translates to 0.019% settlement. 32 In June 2020, the remit of the fund manager responsible for the escrow was expanded to include the 2024; this translates to 0.019% settlement. 32 In June 2020, the remit of the fund manager responsible for the escrow was expanded to include the implementation of the payment waterfall framework which was designed by the Commission to increase upstream market remittance to NBET and TCN. This was to cover the cost of energy taken from GenCos, transmission charges (payable to the TSP) and the MO’s administrative charges. * * * their allowed revenues. Without this, they would also be unable to undertake necessary operational/capital investments. Table 7.13: DisCos Remittance Performance to NBET and MO in 2024 | DisCos | NBET(N'Billion) | | | MO(N'Billion)^{33}$ | | | | --- | --- | --- | --- | --- | --- | --- | | Invoice2024 | Remit.2024 | Performance2024(%) | Invoice2024 | Remit.2024 | Performance2024(%) | | | Abuja | 198.64 | 179.62 | 90.42 | 34.93 | 32.47 | 92.97 | | Benin | 103.21 | 87.96 | 85.22 | 18.64 | 15.89 | 85.24 | | Eko | 184.19 | 182.96 | 99.33 | 26.13 | 24.33 | 93.12 | | Enugu | 88.06 | 73.50 | 83.47 | 17.04 | 14.79 | 86.79 | | Ibadan | 139.63 | 121.21 | 86.81 | 26.59 | 23.85 | 89.70 | | Ikeja | 212.75 | 200.90 | 94.43 | 33.90 | 32.45 | 95.71 | | Jos | 40.49 | 28.71 | 70.90 | 10.49 | 7.37 | 70.26 | | Kaduna | 51.02 | 16.72 | 32.77 | 11.84 | 3.11 | 26.29 | | Kano | 56.01 | 42.20 | 75.35 | 10.68 | 7.74 | 72.44 | | Port Harcourt | 81.05 | 67.01 | 82.67 | 15.63 | 13.41 | 85.83 | | Yola | 5.34 | 4.73 | 88.56 | 4.09 | 3.95 | 96.73 | | All DisCos | 1,160.39 | 1,005.51 | 86.65 | 209.95 | 179.36 | 85.43 | | Special Customer:(N'Million) | | | | | | | | Ajaokuta Steel | 5,198.47 | 0.00 | 0.00 | 441.46 | 0.00 | 0.00 | 1. NBET and MO are the Nigerian Bulk Electricity Trader and Market Operator, respectively. Ajaokuta Steel Co. Ltd and the host community did not make any payment for the ₦5.19 billion and ₦0.44 billion energy invoices and service charges received from NBET and MO, respectively, in 2024. The Commission has escalated the issue of continual non-payment of electricity bills by Ajaokuta to the relevant federal ministries to find a lasting solution. Failure to settle the obligations may put the Ajaokuta complex at risk of being disconnected from its service providers (NBET and MO) on the grounds of gross indebtedness. 33 Based on the provisions of the SLA between the TCN and DisCos, the TSP has to pay a total of ₦2.41 billion to Jos, Kaduna, Kano and Yola DisCos due to service shortfalls in October and November 2024. The breakdown of the payments are as follows: Jos - Oct; ₦0.27 billion, Nov; ₦0.37 billion, Kaduna - Oct; ₦0.37 billion, Kano - Oct; ₦0.60 billion, Nov: ₦0.51 billion and Yola - Oct; ₦0.26 billion, Nov; ₦0.01 billion. * * * Nigerienne d’electricite – NIGELEC, Societe Beninoise d’Energie Electrique – SBEE and Compagnie Energie Electrique du Togo – CEET) received a total invoice of $56.07 million for ancillary services provided by the MO and made a total payment of $42.06 million, corresponding to a remittance performance of 75.01%. The local bilateral customers received a total invoice of ₦7,929.25 million for ancillary services provided by the MO and made a payment of ₦5,970.85 million, corresponding to a remittance performance of 75.30%. Table 7.14: International & Bilateral Customers Invoices & Remittances in 2024 | International Customers | Invoice(Million) | Remittance(Million) | Performance(%) | | --- | --- | --- | --- | | PARAS-SBEE($) | 12.89 | 12.89 | 100.00 | | PARAS-CEET($) | 2.62 | 2.62 | 100.00 | | TRANSCORP/SBEE-UGHELLI($) | 13.13 | 13.13 | 100.00 | | TRANSCORP/SBEE-AFAM3($) | 2.59 | 2.58 | 99.61 | | MAINSTREAM/NIGELEC($) | 10.84 | 10.84 | 100.00 | | ODUKPANI/CEET($) | 13.98 | 0.00 | 0.00 | | Total | 56.07 | 42.06 | 75.01 | | Bilateral Customers | Invoice(Million) | Remittance(Million) | Performance | | MAINSTREAM/INNER GALAXY(N) | | | | | MAINSTREAM/KAM INDUSTRIES(N) | | | | | MAINSTREAM/KAM INTEGRATED(N) | | | | | MAINSTREM/PRISM(N) | 4,815.39 | 4,814.78 | 99.99 | | MAINSTREAM/ZERBERCED | | | | | MAINSTREAM/KAM STEEL SHAGAMU(N) | | | | | MAINSTREAM/ADEFOLORUNSHOVENTURE(N) | | | | | NDPHC/WEEWOOD(N) | 351.50 | 133.68 | 38.03 | | NORTH SOUTH/STAR PIPE(N) | 131.49 | 110.39 | 83.95 | | TRANS-AMADI/FMPI | | | | | TRANS-AMADI/OAU(N) | 130.09 | 120.48 | 92.61 | | NDPHC/SUNFLAG(N) | | | | | OMOTOSHO 11/PULKIT(N) | 159.53 | 0.00 | 0.00 | | ALAOJI GENCO/APLE(N) | 1,646.18 | 350.00 | 21.26 | | TAOPEX/KAM STEEL SHAGAMU(N) | | | | | TAOPEX/KAM INTEGRATED | 580.10 | 441.52 | 76.11 | | SAPELE/PHOENIX | 114.94 | 0.00 | 0.00 | | Total | 7,929.25 | 5,970.85 | 75.30 | * * * # Appendices * * * APPENDICES A. Human Resource Management st Table A.1: Forum Secretaries of the Commission as of 31 December 2024 $$ 3 1 ^ {\\mathrm {s t}} $$ | S/N | Name | Forum Office | | --- | --- | --- | | 1 | Emeka Stanley Anako | Abakaliki Forum Office, Ebonyi State | | 2 | Adesoji Oluwo | Abeokuta Forum Office, Ogun State | | 3 | Grace Ekpenyong | Abuja Forum Office,FCT | | 4 | Nnabuife J. Ogana | Asaba Forum Office,Delta State | | 5 | Princess Agwu | Awka Forum Office,Anambra State | | 6 | Akiti Wilson Barguma | Bauchi Forum Office,Bauchi State | | 7 | Blessing Ikharo Abua | Calabar Forum Office,Cross River State | | 8 | Ado Jamilu | Dutse Forum Office,Jigawa State | | 9 | Chikaeze Osakumi | Eko Forum Office,Lagos State | | 10 | Abubakar Yuguda | Gombe Forum Office | | 11 | Bashir Adam | Damaturu Forum Office,Yobe State | | 12 | Aminu Dauda | Gusau Forum Office,Zamfara State | | 13 | Damilola Akintokunbo | Ikeja Forum Office,Lagos State | | 14 | Chukwunonso Joachim | Ikeja Forum Office,Lagos State | | 15 | Oluwakemi Mary Iyanda | Ilorin Forum Office,Kwara State | | 16 | Samuel Andzenge | Jos Forum Office,Plateau State | | 17 | Mansur Abdullahi | Kaduna Forum Office,Kaduna State | | 18 | Ja'afar Ibrahim | Kano Forum Office,Kano State | | 19 | Abubakar Kurna | Katsina Forum Office,Katsina State | | 20 | Jonathan Alanji | Lafia Forum Office,Nasarawa State | | 21 | Pamela Ishaya Zakari | Makurdi Forum Office,Benue State | | 22 | Afaoma Ubani | Owerri Forum Office,Imo State | | 23 | Azeez Mutiu Akofe | Osogbo Forum Office,Osun State | | 24 | Daniel Osumawei | Port-Harcourt Forum Office,River State | | 25 | Kabiru.U.Musa | Sokoto Forum Office,Sokoto State | | 26 | Chioma Okechukwu | Umuahia Forum Office,Abia State | | 27 | Peter A.Dickson | Uyo Forum Office,Akwa Ibom State | | 28 | Sydney W.Maksha | Yola Forum Office,Adamawa State | * * * Appendix B. Licence, Permit and Certification Table B.1: Licences issued and renewed by the Commission in 2024 | S/N | Applicants | Capacity(MW) | Licence Type | Location | FuelType | | --- | --- | --- | --- | --- | --- | | A. | New Issue | | | | | | 1 | Golden Penny Power Limited | 26.40 | Off-grid Generation | Lagos State | Gas | | 2 | Golden Penny Power Limited | 11.80 | Off-grid Generation | Oyo State | Gas | | 3 | Golden Penny Power Limited | 10.90 | Off-grid Generation | Oyo State | Gas | | 4 | Golden Penny Power Limited | 4.50 | Off-grid Generation | Cross River State | Gas | | 5 | Golden Penny Power Limited | 14.00 | Off-grid Generation | Ogun State | Gas | | 6 | Golden Penny Power Limited | 32.40 | Off-grid Generation | Lagos State | Gas | | 7 | Daybreak Power Solutions | 2.19 | Off-grid Generation | Niger State | Solar | | 8 | TIS Renewable Energy Limited | 6.00 | Off-grid Generation | Lagos State | Gas | | 9 | Auro Nigeria Private Limited | 1.50 | Off-grid Generation | Kaduna State | Gas | | 10 | Daybreak Power Solutions Limited | 2.00 | Off-grid Generation | Ogun State | Solar | | 11 | Daybreak Power Solutions Limited | 2.25 | Off-grid Generation | Ogun State | Solar | | 12 | Daybreak Power Solutions Limited | 2.41 | Off-grid Generation | Ogun State | Solar | | 13 | Daybreak Power Solutions Limited | 4.20 | Off-grid Generation | Lagos State | Solar | | 17 | Daybreak power Solutions | 2.41 | Off-grid Generation | Ogun State | Solar | | 18 | Daybreak power Solutions | 4.20 | Off-grid Generation | Lagos State | Solar | | 19 | TIS Renewable Energy Limited | 6.00 | Off-grid Generation | Lagos State | Gas | | 20 | Golden penny Power Ltd | 13.20 | Off-grid Generation | Ogun State | Gas | | 21 | Daybreak Power Solutions Limited | 2.41 | Off-grid Generation | Ogun State | Solar | | 22 | Daybreak power Solutions Limited | 2.634 | Off-grid Generation | Abia State | Solar | | 23 | Water Resources Asset Holding Co.Ltd | 40.00 | On-grid Generation | Taraba State | Hydro | | 24 | Bogi Power Generation Co.Limited | 26.00 | On-grid Generation | Cross River State | Gas | | 25 | Nigeria Independent System OperatorLimited | NA | System Operator | FCT, Abuja | NA | | 26 | Golden Triangle Electric Power Solutions Co.Ltd | NA | Trading Licence | Lagos State | NA | | 27 | Watts Exchange Limited | NA | Trading Licence | Abuja | NA | | 28 | Centum Dopemu Energy Services Ltd | NA | Trading Licence | Ogun State | NA | | 29 | DMD Electric Limited | NA | Trading Licence | Lagos State | NA | | 30 | Damcrest Energy Limited | NA | Trading Licence | FCT, Abuja | NA | | 31 | Zenith point limited | NA | Trading Licence | Lagos State | NA | | 32 | Capstone Energies Limited | NA | Trading Licence | FCT, Abuja | NA | | 33 | Ecovolt Trade Limited | NA | Trading Licence | Lagos State | NA | | 34 | Tendon Innovation Limited | NA | Trading Licence | Lagos State | NA | | B. | Renewal | | | | | | 35 | Mabon Limited | 39.00 | On-grid Generation | Gombe State | Hydro | \*IEDN is an acronym for an Independent Electricity Distribution Network * * * Table B.2: Captive power generation Permits granted by the Commission in 2024 | S/N | Applicants | Location | Capacity(MW) | | --- | --- | --- | --- | | 1 | SweetCo Foods Limited | Oyo State | 1.50 | | 2 | African Steel Mills Nigeria Limited | Lagos State | 20.00 | | 3 | West African Ceramics Limited | Kogi State | 10.00 | | 4 | Royal Engineered Stones Limited | Kogi State | 4.00 | | 5 | Armilo Plastics Limited | Lagos State | 1.13 | | 6 | MTN Nigeria Communication Limited | Lagos State | 5.46 | | 7 | MTN Nigeria Communication Limited | Lagos State | 3.28 | | 8 | MTN Nigeria Communication Limited | Lagos State | 3.60 | | 9 | MTN Nigeria Communication Limited | Lagos State | 3.60 | | 10 | University of Abuja | Gwagwalada, Abuja | 3.00 | | 11 | University of Calabar & Teaching Hospital | Cross River State | 7.00 | | 12 | University of Agriculture Micheal Okpara | Umetuke, Abia State | 3.00 | | 13 | University of Maiduguri & Teaching Hospital | Main Campus,Borno State | 12.00 | | 14 | Federal University of Agriculture,Abeokuta | Main Campus, Ogun State | 3.00 | | 15 | Federal University Gashuwa | Sabon Gari, Yobe State | 1.50 | | 16 | Nigerian Defence Academy | Kaduna State | 2.50 | | 17 | Nigeria Breweries Plc(Aba Breweries) | Aba,Abia State | 5.60 | | 18 | Nigeria Breweries Plc(Ibadan Breweries) | Ibadan,Oyo State | 7.20 | | 19 | Nigeria Breweries Plc(Ama Breweries) | Ama-Eke Ngwo,Enugu State | 10.59 | | 20 | Nigeria Breweries Plc(Aba Malting Plant) | Obingwa,Abia State | 7.97 | | 21 | Ro-Marong Nigeria Ltd | Amwo Odofin,Lagos | 4.40 | | 22 | Quantum Paper Limited | Lekki,Ogun State | 7.00 | | 23 | Psaltry International Company Limited | Alayide Village,Oyo State | 1.10 | | 24 | Nile University of Nigeria | Jabi,Abuja | 10.00 | * * * Table B.3: Mini-grid registrations and Permits approved by the Commission in 2024 | S/N | Name | Location | Capacity(kW) | | --- | --- | --- | --- | | | A. Registrations | | | | 1 | NXT Grid Nigeria Limited | Kaduna State | 91.00 | | 2 | Prince Albert Company Limited | Cross River State | 100.00 | | 3 | Crossboundary Energy Access Nigeria Assets Limited | Kogi State | 100.00 | | 4 | Crossboundary Energy Access Nigeria Assets Limited | Kogi State | 100.00 | | 5 | Crossboundary Energy Access Nigeria Assets Limited | Kogi State | 100.00 | | 6 | Crossboundary Energy Access Nigeria Assets Limited | Kogi State | 100.00 | | 7 | Crossboundary Energy Access Nigeria Assets Limited | Kogi State | 50.00 | | | B. Permits | | | | 8 | Havenhill Synergy Limited | Osun State | 100.00 | | 9 | Havenhill Synergy Limited | Osun State | 50.00 | | 10 | Havenhill Synergy Limited | Osun State | 132.00 | | 11 | Prado Limited | Benue State | 150.00 | | 12 | Prado Limited | Nasarawa State | 150.00 | | 13 | Prado Limited | Benue State | 100.00 | | 14 | Prado Limited | Niger State | 100.00 | | 15 | Prado Limited | Benue State | 100.00 | | 16 | Prado Limited | Niger State | 150.00 | | 17 | Prado Limited | Benue State | 600.00 | | 18 | Prado Limited | Niger State | 100.00 | | 19 | Prado Limited | Benue State | 100.00 | | 20 | Prado Limited | Benue State | 550.00 | | 21 | Prado Limited | Benue State | 250.00 | | 22 | Prado Limited | Benue State | 150.00 | | 23 | Prado Limited | Benue State | 150.00 | | 24 | Prado Limited | Benue State | 300.00 | | 25 | Prado Limited | Nasarawa State | 300.00 | | 26 | Prado Limited | Benue State | 100.00 | | 27 | Prado Limited | Nasarawa State | 400.00 | | 28 | Prado Limited | Benue State | 250.00 | | 29 | Prado Limited | Benue State | 100.00 | | 30 | Prado Limited | Benue State | 200.00 | | 31 | Prado Limited | Benue State | 300.00 | | 32 | Prado Limited | Ondo State | 200.00 | | 33 | Prado Limited | Kano State | 400.00 | | 34 | Prado Limited | Kano State | 300.00 | * * * Table B.4: Meter Service Providers and Meter Asset Providers certified by the Commission in 2024 | S/N | Applicant | Application Type | | --- | --- | --- | | 1 | Genobet Limited | Installer A1 | | 2 | Mojec Meter Asset Management | Installer A1 | | 3 | Epagad International Services Limited | Installer A1 | | 4 | Abdulrahman Ahmadu Zubairu | Installer C2 | | 5 | Bee-Spring Services Ltd | Installer A1 | | 6 | Armese Consulting Ltd | Installer A1 | | 7 | Shimi H & F Ltd | Installer A1 | | 8 | Integrated Power Nigeria Limited | Installer A1 | | 9 | Meter Service Hub | Installer A1 | | 10 | Caplan Integrated Services Limited | Installer A1 | | 11 | Cartlark international Limited | Installer A1 | | 12 | Gosslink Engineering Limited | Installer A1 | | 13 | MBH Power Limited | Installer A1 | | 14 | Arrowhead Electric solutions Ltd | Installer A1 | | 15 | Chapet Energy Ltd | Installer C1 | | 16 | Mojec Meter Asset Management | Installer A1 | | 17 | Omelus Integrated Solutions Limited | Installer A1 | | 18 | Unitar Hi-Tech Systems Limited | Installer A1 | | 19 | Smart Meters Company Limited | Manufacturer | | 20 | Crestflow Energy Limited | Manufacturer | | 21 | Mojec Meter Asset Management Co Limited | Manufacturer | | 22 | MBH Power Limited | Manufacturer | | 23 | Amal Technologies Limited | Manufacturer | | 24 | Sabrud Consortium Nigeria Ltd | Manufacturer | | 25 | Unitar H-Tech system Ltd | Manufacturer | | 26 | CWG Plc | Manufacturer | | 27 | Skyrun Electric Power Tech | Manufacturer | | 28 | Holley Metering Limited | Manufacturer | | 29 | Smart Meters Co Ltd | Manufacturer | | 30 | Mojec International Ltd | Manufacturer | | 31 | Integrated Power Nig Ltd | Vendor | | 32 | Utility Performance Ltd | Vendor | | 33 | Gosslink Engineering Ltd | Vendor | | 34 | Gosslink Engineering Ltd | Importer | | 35 | Phoenix Renewable Limited | Importer | | 36 | Kenpetrus Energy Resources Limited | Importer | | 37 | Smart Meters Asset Provider Limited | MAP | | 38 | Deep Vision Business Venturers Limited MAP | MAP | | 39 | Wellsun Intelligent Technology Ltd | MAP | | 40 | Kiggs Meters and Systems Ltd | MAP | | 41 | Skyrun Elec. Smart Metering System | MAP | | 42 | Paktim Engineering Consultants MGT | MAP | | 43 | Skipper Nigeria Limited | MAP | | 44 | Amal Tech Ltd | MAP | | 45 | Morgan Energy Limited | MAP | | 46 | Beacon Energy Development Services Ltd | MAP | | 47 | Anietronic Limited | MAP | | 48 | Utility Performance Limited | MAP | | 49 | Ams Smart Tech Solutions Nig. Ltd | MAP | | 50 | Susej Nigeria Limited | MAP | | 51 | Phisbond Nigeria Limited | MAP | | 52 | Marks & Adams Investment Ltd | MAP | | 53 | Chris Omonri Nigeria Enterprises Ltd | MAP | | 54 | TSL Engineering Limited | MAP | | 55 | BTS Power Limited | MAP | | 56 | Chintech Electro Nigeria Limited | MAP | | 57 | Domtech Consult Limited | MAP | | 58 | Dari Investment Limited | MAP | | 59 | Mahashakti Nigeria Limited | MAP | | 60 | Metub Services Limited | MAP | | 61 | Eve Electric Technology Co.Ltd | MAP | | 62 | Zenithpoint Limited | MAP | | 63 | Tesla Automation Limited | MAP | | 64 | Tetra-electric solutions Limited | MAP | | 65 | Bee-springs Services Limited | MAP | | 66 | Brooksfield Technologies Limited | MAP | | 67 | RLG-Adulawo Limited | MAP | | 68 | Incomtel Engineering Limited | MAP | | 69 | Lowpai Energy & Marine Limited | MAP | | 70 | Power Cap limited | MAP | | 71 | Regno Development Limited | MAP | | 72 | Hampcc Uti Limited | MAP | | 73 | Nicholas Ojo Alokomaro and Sons Limited | MAP | | 74 | M E Metering Company Limited | MAP | | 75 | Direct Credit E-Solutions Nigeria Limited | MAP | Class “A1” Certification authorises a holder to undertake installations of (i) Low Voltage single-phase and three-phase Metering systems for installation exceeding 750 metering Systems/Contract, and (ii) Installations at grid voltages exceeding 1 5 Metering Systems. Class “C1” Certification authorises a holder to undertake installations of Low Voltage Distribution singlephase and three-phase Metering Systems exceeding 500 Metering Systems/Contract. $$ "A 1" $$ * * * C. Customer Complaints Table C.1: Customer complaints received by DisCos in 2024 | DisCo | Customers' Complaints('000) | | | | | | --- | --- | --- | --- | --- | --- | | 2024/Q1 | 2024/Q2 | 2024/Q3 | 2024/Q4 | Y2024 | | | Abuja | 27.48 | 25.89 | 31.41 | 23.96 | 108.74 | | Aba | 3.33 | 4.28 | 4.93 | 5.51 | 18.05 | | Benin | 6.88 | 6.02 | 11.81 | 13.95 | 38.66 | | Eko | 47.90 | 53.38 | 64.99 | 48.96 | 214.16 | | Enugu | 35.58 | 22.02 | 20.77 | 15.81 | 93.99 | | Ibadan | 53.74 | 51.72 | 56.60 | 46.46 | 209.56 | | Ikeja | 23.00 | 20.54 | 22.97 | 24.09 | 89.74 | | Jos | 18.93 | 20.01 | 20.50 | 19.88 | 79.61 | | Kaduna | 6.90 | 6.55 | 7.41 | 5.90 | 25.02 | | Kano | 11.41 | 18.07 | 27.51 | 17.28 | 74.33 | | P/H | 53.45 | 56.93 | 56.94 | 54.28 | 222.00 | | Yola | 2.79 | 2.04 | 2.58 | 2.05 | 9.32 | | Total | 291.38 | 287.44 | 328.41 | 278.13 | 1,183.18 | * * * Appendix Table C.2: Category of customer complaints received by DisCos (2019-2024) | Complaint | 2024('000) | | | | | 2023('000) | | | | | 2022('000) | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Categories | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | Metering | 167.46 | 140.42 | 137.88 | 141.40 | 587.16 | 118.99 | 149.71 | 191.36 | 177.52 | 638.32 | 79.63 | 111.95 | 117.26 | 122.80 | 431.66 | | Interruption | 24.85 | 28.18 | 23.18 | 23.40 | 99.61 | 23.01 | 23.61 | 26.94 | 24.55 | 98.13 | 37.18 | 23.43 | 21.75 | 24.23 | 106.60 | | Voltage | 4.87 | 4.80 | 4.05 | 2.70 | 16.41 | 4.27 | 4.33 | 4.49 | 4.80 | 17.80 | 16.27 | 9.98 | 4.13 | 4.34 | 34.74 | | Load Shedding | 0.64 | 0.47 | 0.28 | 0.23 | 1.62 | 1.51 | 2.43 | 1.66 | 0.86 | 6.48 | 14.71 | 5.33 | 1.30 | 1.46 | 22.82 | | Billing | 28.45 | 41.08 | 69.96 | 29.51 | 168.99 | 56.72 | 53.36 | 43.02 | 42.86 | 195.97 | 41.64 | 32.93 | 49.92 | 61.02 | 185.52 | | Disconnection | 2.60 | 2.79 | 4.18 | 5.05 | 14.62 | 4.11 | 4.69 | 4.91 | 4.26 | 17.98 | 26.99 | 7.25 | 7.34 | 4.84 | 46.43 | | Connection Delay | 2.44 | 3.36 | 0.84 | 0.56 | 7.20 | 3.69 | 3.06 | 2.07 | 0.52 | 9.35 | 12.79 | 2.99 | 1.28 | 2.95 | 20.02 | | Others | 60.08 | 66.34 | 88.33 | 72.83 | 287.58 | 37.17 | 65.80 | 59.45 | 55.30 | 218.24 | 14.14 | 38.01 | 38.22 | 39.43 | 129.81 | | Total | 291.38 | 287.44 | 328.70 | 275.68 | 1,183.20 | 249.68 | 325.89 | 333.94 | 310.71 | 1,220.24 | 243.38 | 231.90 | 241.24 | 261.10 | 977.64 | | Complaint | 2021('000) | | | | | 2020('000) | | | | | 2019('000) | | | | | | Categories | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | Metering | 50.32 | 50.65 | 55.28 | 53.30 | 209.58 | 44.66 | 48.01 | 71.89 | 41.45 | 206.03 | 37.12 | 46.43 | 38.83 | 41.54 | 163.94 | * * * Table C.3: Appeals received and resolved by Forum Offices in 2024 | S/N | 2024/Q1 | | | | 2024/Q2 | | | | 2024/Q3 | | | | 2024/Q4 | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | | Customers' Complaints | | | | Customers' Complaints | | | | Customers' Complaints | | | | | | | | | | | Received | Resolved | Pending | Resolution Rate (%) | Received | Resolved | Pending | Resolution Rate (%) | Received | Resolved | Pending | Resolution Rate (%) | Received | Resolved | Pending | Resolution Rate (%) | | | | | | | | 1 | Abakaliki | 41 | 17 | 21 | 41 | 66 | 42 | 18 | 64 | 64 | 57 | 6 | 89 | 34 | 15 | 69 | 175 | 150 | 15 | 86 | | | 2 | Abeokuta | 122 | 17 | 33 | 34 | 152 | 14 | 63 | 9 | 180 | 90 | 30 | 50 | 228 | 82 | 48 | 36 | 556 | 228 | 48 | | | 3 | Abajia | 35 | 27 | 8 | 77 | 45 | 30 | 15 | 67 | 65 | 48 | 17 | 74 | 77 | 61 | 16 | 79 | 182 | 166 | 16 | | | 4 | Ade-Ekii | 16 | 10 | 6 | 63 | 19 | 11 | 8 | 89 | 24 | 17 | 7 | 71 | 10 | 7 | 3 | 70 | 48 | 45 | 3 | | | 5 | Aduaiu | 72 | 50 | 21 | 69 | 51 | 34 | 15 | 67 | 55 | 38 | 17 | 69 | 74 | 48 | 26 | 65 | 199 | 170 | 26 | | | 6 | Awka | 101 | 56 | 45 | 55 | 149 | 103 | 46 | 69 | 168 | 94 | 74 | 56 | 172 | 150 | 22 | 87 | 425 | 403 | 22 | | | 7 | Bauchi | 6 | 6 | 0 | 100 | 3 | 10 | 4 | 69 | 6 | 6 | 0 | 100 | 10 | 2 | 8 | 20 | 25 | 17 | 8 | | | 8 | Benin | 55 | 39 | 16 | 0 | 60 | 53 | 7 | 0 | 49 | 19 | 30 | 0 | 55 | 30 | 25 | 0 | 166 | 141 | 25 | 0 | | 9 | Damaturu | 3 | 3 | 0 | 0 | 3 | 2 | 1 | 0 | 5 | 3 | 2 | 0 | 4 | 4 | 0 | 1 | 12 | 12 | 0 | 0 | | 10 | Calabar | 27 | 17 | 10 | 63 | 26 | 19 | 7 | 73 | 31 | 20 | 11 | 65 | 35 | 28 | 3 | 80 | 91 | 84 | 7 | 92 | | 11 | Dutse | 7 | 5 | 2 | 71 | 4 | 2 | 2 | 50 | 3 | 2 | 1 | 67 | 3 | 0 | 3 | 0 | 12 | 9 | 3 | 75 | * * * Table C.4: List and addresses of NERC Forum Offices as of December 2024 | S/N | Forum Office | Location | Telephone | Email | | --- | --- | --- | --- | --- | | 1 | Abakaliki, Ebonyi State | 3, Ezekuna Crescent, Off Nsugbe Street, Abakaliki Ebonyi State | 9037808590 | [abakalikiforum@nerc.gov.ng](mailto:abakalikiforum@nerc.gov.ng) | | 2 | Abeokuta, Ogun State | 33, First Avenue, Ibara Housing Estate, Ibrar GRA, Abeokuta | 9139381008 | [abeokutaforum@nerc.gov.ng](mailto:abeokutaforum@nerc.gov.ng) | | 3 | Abuja, FCT | 14, Road 131, Gwarinpa, Federal Capital Territory, Abuja | 8146862225 | [abujiafforum@nerc.gov.ng](mailto:abujiafforum@nerc.gov.ng) | | 4 | Asaba, Delta State | Denis Osadebe Way, Beside Mobil Filling Station, Asaba, Delta State | 9062277247 | [asabiafforum@nerc.gov.ng](mailto:asabiafforum@nerc.gov.ng) | | 5 | Awka, Anambra State | Plot 80, Aroma Junction Layout, Opp., CBN, Awka, Anambra State | 9037808594 | [awkaforum@nerc.gov.ng](mailto:awkaforum@nerc.gov.ng) | | 6 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bauchi, Bauchi State | 9062924607 | [bauchifforum@nerc.gov.ng](mailto:bauchifforum@nerc.gov.ng) | | 7 | B/Kebbi, Kebbi State | 8, Ahmadu Bukub Road, Opp., Kebbi State Govt House, Kebbi State | 9062863161 | [birninkebbforum@nerc.gov.ng](mailto:birninkebbforum@nerc.gov.ng) | | 8 | 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) | | 9 | Damaturu, Yobe State | No. 5, AD Road, Abba Ibrahim Extension, Off Potiskum Road, Damaturu, Yobe State | 9169978243 | [damaturuforum@nerc.gov.ng](mailto:damaturuforum@nerc.gov.ng) | | 10 | Dute, Jigawa State | Dute G.R.A, Dute, Jigawa State | 7031704827 | [ijigawaforum@nerc.gov.ng](mailto:ijigawaforum@nerc.gov.ng) | | 11 | Eko, Lagos State | 61, Odunlami Street, Off Marina, Lagos Island, Lagos State | 8106807261 | [ekoforum@nerc.gov.ng](mailto:ekoforum@nerc.gov.ng) | | 12 | Gombe, Gombe State | Government Layout GDP/2, Along Ministry of Education Road, Gombe State | 8140400797 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) | | 13 | Gusau, Zamfara State | 2 Canteen Daji, J. B. Yakubu Road, Gusau, Zamfara State | 9062863163 | [gusauforum@nerc.gov.ng](mailto:gusauforum@nerc.gov.ng) | | 14 | Ikeja, Lagos State | 199, Obafemi Awolowo Way, Alausa, Ikeja, Lagos State | 8106807298 | [ikejaforum@nerc.gov.ng](mailto:ikejaforum@nerc.gov.ng) | | 15 | Ilorin, Kwara State | 30, Stadium Road, Off Taiwo Road, Ilorin, Kwara State | 9062924603 | [ilorinforum@nerc.gov.ng](mailto:ilorinforum@nerc.gov.ng) | | 16 | Jos, Plateau State | 5a, Ray-field Road, Jos, Plateau State | 9037808597 | [josforum@nerc.gov.ng](mailto:josforum@nerc.gov.ng) | | 17 | Kaduna, Kaduna State | 22, Ahmadu Bello Way, Opposite NNDC Building, Kaduna, Kaduna State | 8106807299 | [kadunaforum@nerc.gov.ng](mailto:kadunaforum@nerc.gov.ng) | | 18 | Kano, Kano State | 2, Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 8146862222 | [kanoforum@nerc.gov.ng](mailto:kanoforum@nerc.gov.ng) | | 19 | Katsina, Katsina State | 7, Abuja Crescent, Off Hassan Usman Katsina Road, Katsina State | 7031704821 | [katsinaforum@nerc.gov.ng](mailto:katsinaforum@nerc.gov.ng) | | 20 | Lafia, Nasarawa State | Manyi Street, Off Jos Road, Bukan Sidi, Lafia, Nasarawa State | 9062924599 | [lafiaforum@nerc.gov.ng](mailto:lafiaforum@nerc.gov.ng) | | 21 | Makurdi, Benue State | Hephzibah Plaza, Atom Kpera Road, Opp. Makurdi Int'l School, Benue State | 9062272494 | [makurdiforum@nerc.gov.ng](mailto:makurdiforum@nerc.gov.ng) | | 22 | Osogbo, Osun State | 51, Isiaka Adeleke Way, Along Okefia-Alekwodo Rd, Osogbo, Osun State | 9062924604 | [osogboforum@nerc.gov.ng](mailto:osogboforum@nerc.gov.ng) | | 23 | P/Harcourt, Rivers State | The Vhhelberg Imperial Hotel, Plot 122 & 122a, Bank Anthony Avenue, Off Ordinance Rd, P/Harcourt | 8146862223 | [phforum@nerc.gov.ng](mailto:phforum@nerc.gov.ng) | | 24 | Sokoto, Sokoto State | 1, Garba Duba Road, Sokoto, Sokoto State | 9036862157 | [sokotoforum@nerc.gov.ng](mailto:sokotoforum@nerc.gov.ng) | $$ J o s, $$ * * * D. Electricity Generation Table D.1: Updated nomenclature of Power Plants | 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 | * * * Table D.2: Available Capacity, Energy Generated and Energy Delivered (2021- 2024) | | Installed Available Capacity(MW) | | | | Energy Generated(MWh/h) | | | | Energy Delivered to the Grid(MWh/h) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | | January | 4,459 | 4,394 | 4,783 | 5,103 | 4,275 | 4,083 | 4,265 | 4,495 | 4,230 | 4,021 | 4,187 | 4,424 | | February | 3,957 | 4,726 | 4,863 | 5,513 | 3,796 | 4,502 | 4,317 | 4,561 | 3,763 | 4,441 | 4,255 | 4,482 | | March | 4,331 | 4,828 | 4,491 | 5,601 | 4,138 | 4,432 | 3,728 | 4,410 | 4,887 | 4,346 | 3,679 | 4,328 | | April | 4,223 | 4,334 | 5,099 | 5,023 | 3,960 | 4,177 | 3,813 | 4,308 | 3,921 | 4,095 | 3,764 | 4,229 | | May | 4,574 | 4,421 | 4,608 | 5,002 | 4,262 | 4,071 | 3,630 | 4,149 | 4,217 | 4,029 | 3,583 | 4,075 | | June | 4,391 | 4,426 | 3,845 | 4,505 | 3,834 | 3,949 | 3,224 | 3,774 | 3,793 | 3,863 | 3,178 | 3,705 | | July | 4,915 | 4,139 | 4,092 | 4,858 | 4,199 | 3,968 | 3,634 | 3,940 | 4,151 | 3,911 | 3,592 | 3,866 | | August | 4,854 | 4,060 | 4,575 | 5,593 | 4,150 | 3,946 | 3,939 | 4,003 | 4,125 | 3,891 | 3,882 | 3,934 | | September | 5,533 | 4,435 | 4,456 | 5,453 | 4,492 | 3,858 | 4,047 | 3,867 | 4,462 | 3,808 | 3,939 | 3,801 | | October | 5,397 | 4,964 | 4,233 | 5,764 | 3,906 | 4,452 | 3,976 | 4,138 | 3,904 | 4,399 | 3,936 | 4,078 | | November | 5,257 | 5,076 | 4,537 | 5,432 | 4,192 | 4,399 | 4,304 | 4,336 | 4,189 | 4,338 | 4,264 | 4,275 | | December | 5,237 | 4,450 | 4,740 | 5,200 | 4,524 | 4,450 | 4,265 | 4,495 | 4,503 | 4,021 | 4,394 | 4,424 | | Average | 4,761 | 4,521 | 4,527 | 5,254 | 4,144 | 4,191 | 3,929 | 4,206 | 4,179 | 4,096 | 3,888 | 4,159 | * * * Table D.3: Plants’ Average Load Factor (2021-2024) | | Load Factor(%) | | | | | --- | --- | --- | --- | --- | | GenCos | 2024 | 2023 | 2022 | 2021 | | Afam\_1 | 94.20 | 93.69 | 78.90 | 75.69 | | Afam\_2 | 98.06 | 100.00 | 97.72 | 92.91 | | Alaoji\_1 | 0.00 | 88.35 | 80.10 | 51.29 | | Ihovbor\_2 | 87.55 | 90.31 | 93.23 | 88.90 | | Dadin-Kowa\_1 | 93.30 | 95.93 | 97.93 | - | | Delta\_1 | 94.48 | 96.39 | 87.69 | 82.27 | | Egbin\_1 | 89.67 | 93.28 | 91.48 | 81.59 | | Geregu\_1 | 91.40 | 94.17 | 83.57 | 76.14 | | Geregu\_2 | 69.75 | 91.88 | 88.03 | 64.91 | | Ibom power\_1 | 67.49 | 54.57 | 52.37 | 80.69 | | Ihovbor\_1 | 43.24 | 81.16 | 84.02 | 50.60 | | Jebba\_1 | 86.02 | 93.18 | 98.44 | 85.08 | | Kainji\_1 | 92.97 | 95.52 | 98.09 | 95.05 | | Odukpani\_1 | 85.83 | 92.63 | 72.70 | 72.88 | | Okpai\_1 | 83.91 | 84.72 | 81.37 | 78.52 | | Olorunsogo\_1 | 96.08 | 99.83 | 84.90 | 75.45 | | Olorunsogo\_2 | 54.89 | 98.26 | 82.60 | 65.11 | | Omoku\_1 | 100.00 | 100.00 | 100.00 | 87.26 | | Omotosho\_1 | 90.79 | 97.40 | 89.66 | 84.07 | | Omotosho\_2 | 60.57 | 85.51 | 87.19 | 52.76 | | Ikeja\_1 | 88.58 | 87.39 | 82.84 | 79.20 | | Rivers\_1 | 76.56 | 89.23 | 92.03 | 71.72 | | Sapele Steam\_1 | 74.59 | 90.29 | 68.67 | 51.87 | | Sapele\_2 | 54.94 | 79.90 | 66.91 | 77.37 | | Shiroro\_1 | 82.35 | 85.53 | 89.63 | 74.54 | | Afam\_1 | 100.00 | 100.00 | 99.05 | 79.12 | | Total | 87.00 | 92.22 | 85.94 | 79.92 | * * * Table D6 : Annual Electricity Output and Share by Fuel Type (2021-2024) | | | Total Electricity Output(GWh) | | | | Fuel Share of Electricity Output(%) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | Fuel Type | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | | Q1 | Thermal | 6,582 | 6,979 | 6,497 | 7,683 | 74 | 75 | 73 | 78 | | Hydro | 2,306 | 2,370 | 2,350 | 2,227 | 26 | 25 | 27 | 22 | | | Aggregate | 8,888 | 9,350 | 8,848 | 9,910 | 100 | 100 | 100 | 100 | | | Q2 | Thermal | 6,409 | 7,068 | 6,324 | 7,373 | 73 | 80 | 81 | 82 | | Hydro | 2,368 | 1,798 | 1,442 | 1,628 | 27 | 20 | 19 | 18 | | | Aggregate | 8,777 | 8,867 | 7,766 | 9,001 | 100 | 100 | 100 | 100 | | | Q3 | Thermal | 6,370 | 6,456 | 6,027 | 6,729 | 67 | 74 | 72 | 77 | | Hydro | 3,081 | 2,208 | 2,512 | 1,962 | 33 | 26 | 28 | 23 | | | Aggregate | 9,451 | 8,664 | 8,850 | 8,692 | 100 | 100 | 100 | 100 | | | Q4 | Thermal | 6,261 | 7,087 | 6,438 | 6,832 | 67 | 72 | 70 | 72 | | Hydro | 3,029 | 2,702 | 2,926 | 2,648 | 33 | 28 | 30 | 28 | | | Aggregate | 9,290 | 9,789 | 9,365 | 9,481 | 100 | 100 | 100 | 100 | | | Annual | Thermal | 25,621 | 27,623 | 25,613 | 28,619 | 70 | 75 | 73 | 77 | | Hydro | 10,782 | 9,086 | 9,328 | 8,466 | 30 | 25 | 27 | 23 | | | Aggregate | 37,093 | 36,710 | 34,942 | 37,086 | 100 | 100 | 100 | 100 | | * * * Table D.5: Plant Share of Total Electricity Output (2021-2024) | | Electricity Output by Plant(GWh) | | | | Electricity Output by Plant(%) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | GenCos | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | | Afam\_1 | 363 | 344 | 432 | 585 | 0.98 | 0.94 | 1.24 | 1.59 | | Afam\_2 | 2,416 | 2,737 | 853 | 2,404 | 6.51 | 7.46 | 2.44 | 6.53 | | Alaoji\_1 | 0 | 58 | 579 | 505 | 0.00 | 0.16 | 1.66 | 1.37 | | Ihovbor\_2 | 3,323 | 3,244 | 3,454 | 3,252 | 8.96 | 8.84 | 9.89 | 8.84 | | Dadin-Kowa\_1 | 210 | 205 | 234 | 0 | 0.57 | 0.56 | 0.67 | - | | Delta\_1 | 2,913 | 3,130 | 3,341 | 112 | 7.85 | 8.53 | 9.56 | 7.53 | | Egbin\_1 | 4,398 | 5,173 | 3,800 | 2,769 | 11.86 | 14.09 | 10.87 | 15.29 | | Geregu\_1 | 1,278 | 1,741 | 1,619 | 5,626 | 3.44 | 4.74 | 4.63 | 6.70 | | Geregu\_2 | 1,097 | 315 | 734 | 2,463 | 2.96 | 0.86 | 2.1 | 1.85 | | Ibom power\_1 | 428 | 349 | 309 | 681 | 1.16 | 0.95 | 0.88 | 0.30 | | Ihovbor\_1 | 110 | 217 | 529 | 111 | 0.30 | 0.59 | 1.51 | 0.40 | | Jebba\_1 | 2,858 | 2,961 | 2,859 | 149 | 7.71 | 8.07 | 8.18 | 8.37 | | Kainji\_1 | 3,263 | 3,410 | 3,202 | 3,078 | 8.80 | 9.29 | 9.16 | 7.70 | | Odukpani\_1 | 2,324 | 2,117 | 1,925 | 2,834 | 6.27 | 5.77 | 5.51 | 6.90 | | Okpai\_1 | 1,905 | 2,331 | 2,066 | 2,537 | 5.14 | 6.35 | 5.91 | 6.40 | | Olorunsogo\_1 | 1,026 | 832 | 953 | 2,356 | 2.77 | 2.27 | 2.73 | 2.94 | | Olorunsogo\_2 | 341 | 253 | 349 | 1,080 | 0.92 | 0.69 | 1 | 0.17 | | Omoku\_1 | 510 | 487 | 424 | 64 | 1.38 | 1.33 | 1.21 | 1.03 | | Omotosho\_1 | 990 | 1,006 | 918 | 377 | 2.67 | 2.74 | 2.63 | 2.77 | | Omotosho\_2 | 46 | 751 | 722 | 1,018 | 0.12 | 2.05 | 2.07 | 0.76 | | Ikkeja\_1 | 754 | 513 | 420 | 281 | 2.03 | 1.40 | 1.2 | 1.09 | | Rivers\_1 | 465 | 548 | 993 | 400 | 1.25 | 1.49 | 2.84 | 1.74 | * * * Table D6A: Average Monthly Transmission Loss Factor (2021-2024) | | Energy Injected into Grid(GWh) | | | | Energy Delivered to DisCos&Exported(GWh) | | | | Transmission Losses Factor(%) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Month | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | \*2024 | 2023 | 2022 | 2021 | | January | 3,128 | 3,263 | 3,136 | 3,295 | 2,870 | 2,755 | 2,812 | 3,043 | 8.26 | 7.32 | 8.15 | 7.64 | | February | 2,602 | 2,974 | 2,860 | 3,007 | 2,387 | 2,744 | 2,554 | 2,781 | 8.91 | 8.19 | 8.54 | 7.51 | | March | 3,028 | 2,983 | 2,754 | 3,220 | 2,778 | 2,982 | 2,487 | 2,982 | 8.26 | 8.19 | 7.38 | 7.37 | | April | 2,772 | 3,247 | 2,717 | 3,004 | 2,563 | 2,720 | 2,446 | 2,816 | 7.18 | 7.73 | 8.44 | 7.49 | | May | 2,925 | 2,948 | 2,662 | 3,033 | 2,846 | 2,715 | 2,081 | 2,809 | 2.68 | 9.56 | 8.43 | 7.41 | | June | 2,732 | 3,002 | 2,291 | 2,664 | 2,489 | 2,562 | 2,465 | 2,464 | 8.39 | 7.72 | 8.20 | 7.49 | | July | 3,075 | 2,776 | 2,677 | 2,834 | 2,792 | 2,664 | 2,593 | 2,654 | 9.19 | 8.17 | 8.08 | 6.34 | | August | 3,066 | 2,897 | 2,870 | 2,890 | 2,809 | 2,670 | 2,637 | 2,705 | 8.40 | 8.39 | 7.78 | 6.43 | | September | 3,201 | 2,912 | 2,847 | 2,714 | 2,901 | 2,544 | 2,701 | 2,522 | 9.54 | 7.26 | 7.50 | 7.07 | | October | 2,878 | 2,742 | 2,917 | 3,030 | 2,627 | 2,977 | 2,851 | 2,785 | 8.98 | 8.89 | 7.42 | 8.07 | | November | 2,982 | 3,266 | 3,059 | 3,091 | 2,711 | 2,944 | 3,012 | 2,828 | 9.28 | 8.83 | 6.81 | 8.50 | | December | 3,321 | 3,229 | 3,263 | 3,243 | 3,010 | 2,998 | 2,755 | 2,983 | 9.43 | 7.74 | 7.71 | 8.03 | | Average | 2,976 | 3,020 | 2,838 | 3,005 | 2,732 | 2,773 | 2,616 | 2,781 | 8.21 | 8.17 | 7.87 | 7.45 | | Total | 35,711 | 36,240 | 34,054 | 36,065 | 32,784 | 33,273 | 31,393 | 33,373 | 8.21 | 8.17 | 7.87 | 7.45% | \*MYTO TLF Assumption for 2024: 7% * * * Table D.7: Number of System Collapses (2011-2024) | Year | Type | Jan. | Feb. | Mar. | Apr. | May | Jun. | Jul. | Aug. | Sep. | Oct. | Nov. | Dec. | Total | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2011 | Total Collapse | 0 | 0 | 0 | 0 | 4 | 3 | 1 | 1 | 1 | 2 | 1 | 0 | 13 | | Partial Collapse | 0 | 1 | 1 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | 2 | 0 | 6 | | | 2012 | Total Collapse | 0 | 0 | 2 | 1 | 5 | 2 | 1 | 0 | 0 | 2 | 2 | 1 | 16 | | Partial Collapse | 0 | 0 | 2 | 3 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | 1 | 8 | | | 2013 | Total Collapse | 0 | 1 | 2 | 2 | 3 | 4 | 1 | 1 | 1 | 1 | 4 | 2 | 22 | | Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 2 | | | 2014 | Total Collapse | 2 | 0 | 0 | 2 | 0 | 3 | 1 | 0 | 0 | 1 | 0 | 0 | 9 | | Partial Collapse | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 2 | 1 | 4 | | | 2015 | Total Collapse | 1 | 0 | 1 | 0 | 2 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 6 | | Partial Collapse | 0 | 0 | 1 | 0 | 2 | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 4 | | | 2016 | Total Collapse | 0 | 0 | 2 | 3 | 6 | 5 | 0 | 0 | 1 | 1 | 2 | 2 | 22 | | Partial Collapse | 0 | 0 | 1 | 0 | 1 | 3 | 1 | 0 | 0 | 0 | 0 | 0 | 6 | | | 2017 | Total Collapse | 5 | 3 | 0 | 3 | 1 | 1 | 0 | 0 | 1 | 1 | 0 | 0 | 15 | | Partial Collapse | 1 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 3 | 3 | 0 | 0 | 9 | | | 2018 | Total Collapse | 5 | 1 | 0 | 0 | 0 | 1 | 1 | 0 | 2 | 0 | 0 | 2 | 12 | | Partial Collapse | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | | | 2019 | Total Collapse | 4 | 1 | 0 | 1 | 1 | 1 | 0 | 1 | 0 | 0 | 0 | 1 | 10 | | Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | | | 2020 | Total Collapse | 1 | 0 | 0 | 1 | 0 | 1 | 0 | 0 | 0 | 0 | 1 | 0 | 4 | | Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | * * * Table D.8: Average Daily System Frequency \[Hz\] (2021-2024) | | Average system frequency(upper bound) | | | | Average system frequency(lower bound) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | | January | 50.62 | 50.60 | 50.68 | 50.49 | 49.03 | 49.10 | 49.13 | 49.17 | | February | 50.73 | 50.96 | 50.60 | 50.59 | 48.93 | 49.11 | 49.05 | 49.38 | | March | 50.68 | 51.01 | 50.78 | 50.62 | 49.18 | 49.02 | 49.07 | 49.29 | | April | 50.86 | 50.93 | 51.12 | 50.72 | 48.99 | 48.98 | 49.08 | 49.12 | | May | 51.06 | 51.10 | 50.47 | 50.64 | 49.23 | 49.08 | 49.13 | 49.13 | | June | 50.99 | 51.06 | 50.73 | 50.70 | 49.17 | 49.06 | 49.09 | 49.07 | | July | 50.73 | 50.73 | 50.63 | 50.69 | 49.40 | 48.96 | 48.71 | 49.95 | | August | 50.73 | 50.56 | 51.14 | 50.81 | 49.63 | 48.98 | 48.65 | 49.35 | | September | 50.80 | 50.83 | 50.81 | 51.00 | 49.65 | 49.08 | 48.76 | 49.24 | | October | 51.20 | 50.69 | 50.66 | 50.96 | 49.54 | 48.88 | 49.08 | 49.43 | | November | 50.83 | 50.67 | 50.44 | 50.72 | 49.40 | 49.19 | 49.07 | 49.32 | | December | 50.69 | 50.62 | 50.56 | 50.59 | 49.22 | 49.05 | 49.09 | 49.20 | | Average | 50.83 | 50.81 | 50.72 | 50.71 | 49.28 | 49.04 | 48.99 | 49.30 | Higher stress limit - 51.25 Upper limit - 50.25 Upper limit - 50.25 Nominal standard – 50 Nominal standard – 50 Lower limit - 49.75 Lower limit - 49.75 Lower stress limit – 48.75 Lower stress limit – 48.75 * * * Table D.9: Average Daily System Voltage (2021-2024) | | Average system voltage(upper bound)(kV) | | | | Average system voltage(lower bound)(kV) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | 2024 | 2023 | 2022 | 2021 | 2024 | 2023 | 2022 | 2021 | | January | 350.80 | 357.50 | 352.90 | 349.81 | 299.93 | 300.50 | 297.74 | 298.48 | | February | 354.00 | 354.28 | 352.76 | 348.96 | 299.48 | 299.17 | 297.36 | 299.21 | | March | 348.29 | 349.55 | 351.18 | 350.87 | 298.55 | 292.75 | 297.00 | 296.07 | | April | 354.67 | 351.97 | 358.00 | 349.13 | 302.07 | 299.34 | 299.00 | 297.17 | | May | 355.29 | 354.30 | 357.00 | 351.75 | 307.93 | 296.33 | 300.00 | 294.78 | | June | 355.43 | 356.27 | 358.00 | 353.47 | 303.07 | 297.03 | 300.00 | 299.97 | | July | 354.65 | 350.77 | 335.42 | 353.35 | 299.55 | 300.00 | 299.53 | 300.16 | | August | 353.52 | 353.32 | 358.24 | 352.23 | 299.06 | 299.39 | 299.10 | 298.74 | | September | 349.87 | 355.73 | 353.21 | 352.90 | 300.30 | 299.20 | 299.83 | 297.74 | | October | 352.19 | 348.00 | 351.03 | 352.90 | 295.96 | 297.00 | 299.45 | 297.74 | | November | 352.27 | 348.00 | 352.96 | 352.76 | 291.30 | 299.00 | 299.93 | 397.36 | | December | 349.58 | 347.00 | 352.21 | 351.18 | 295.84 | 299.00 | 298.73 | 297.00 | | Average | 352.55 | 352.22 | 352.74 | 351.61 | 299.42 | 298.23 | 298.97 | 297.87 | Upper limit – 346.50 Nominal standard – 330.00 Nominal standard – 330.00 Lower limit – 313.50 Lower limit – 313.50 * * * E. Metering Table E.1: Number of registered, metered, and unmetered customers in 2024 | | Registered Customers(RC)by DisCos | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Distribution Company | 2024/Q1 | | 2024/Q2 | | 2024/Q3 | | 2024/Q4 | | | Registered Customers | % | Registered Customers | % | Registered Customers | % | Registered Customers | % | | | Aba | 194,354 | 1.45 | 198,531 | 1.50 | 202,523 | 1.52 | 206,540 | 1.53 | | Abuja | 1,446,609 | 10.82 | 1,244,245 | 9.43 | 1,263,483 | 9.47 | 1,195,429 | 8.85 | | Benin | 1,351,811 | 10.11 | 1,369,840 | 10.38 | 1,402,484 | 10.51 | 1,435,685 | 10.63 | | Eko | 766,329 | 5.73 | 773,171 | 5.86 | 724,213 | 5.43 | 729,169 | 5.40 | | Enugu | 1,396,440 | 10.44 | 1,396,440 | 10.59 | 1,396,440 | 10.47 | 1,396,440 | 10.34 | | Ibadan | 2,471,429 | 18.48 | 2,498,224 | 18.94 | 2,582,740 | 19.36 | 2,644,124 | 19.58 | | Ikeja | 1,257,046 | 9.40 | 1,208,581 | 9.16 | 1,249,385 | 9.37 | 1,286,026 | 9.52 | | Jos | 741,266 | 5.54 | 747,162 | 5.66 | 752,943 | 5.64 | 832,053 | 6.16 | | Kaduna | 870,449 | 6.51 | 877,528 | 6.65 | 881,749 | 6.61 | 884,647 | 6.55 | | Kano | 880,603 | 6.59 | 881,922 | 6.68 | 883,742 | 6.62 | 891,410 | 6.60 | | P/H | 1,179,194 | 8.82 | 1,179,194 | 8.94 | 1,179,194 | 8.84 | 1,179,194 | 8.73 | | Yola | 816,994 | 6.11 | 817,735 | 6.20 | 820,739 | 6.15 | 822,625 | 6.09 | | Total | 13,372,524 | 100.00 | 13,192,573 | 100.00 | 13,339,635 | 100.00 | 13,503,342 | 100.00 | Metered Customers by DisCos | Distribution Company | 2024/Q1 | | 2024/Q2 | | 2024/Q3 | | 2024/Q4 | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Metered Customers | % | Metered Customers | % | Metered Customers | % | Metered Customers | % | | | Aba | 62,321 | 1.04 | 71,135 | 1.19 | 76,052 | 1.24 | 78,281 | 1.24 | | Abuja | 883,443 | 14.75 | 873,083 | 14.57 | 896,753 | 14.57 | 910,942 | 14.49 | | Benin | 669,362 | 11.18 | 675,092 | 11.26 | 689,122 | 11.19 | 714,242 | 11.36 | | Eko | 452,875 | 7.56 | 438,462 | 7.32 | 455,496 | 7.40 | 460,187 | 7.32 | | Enugu | 630,606 | 10.53 | 635,042 | 10.60 | 654,770 | 10.64 | 671,760 | 10.68 | | Ibadan | 1,074,187 | 17.93 | 1,069,201 | 17.84 | 1,114,609 | 18.10 | 1,153,025 | 18.34 | | Ikeja | 920,448 | 15.37 | 926,272 | 15.46 | 956,469 | 15.54 | 998,986 | 15.89 | | Jos | 248,110 | 4.14 | 251,689 | 4.20 | 253,792 | 4.12 | 225,188 | 3.58 | | Kaduna | 209,090 | 3.49 | 210,229 | 3.51 | 214,113 | 3.48 | 217,033 | 3.45 | | Kano | 211,537 | 3.53 | 212,016 | 3.54 | 214,650 | 3.49 | 215,834 | 3.43 | | P/H | 500,821 | 8.36 | 502,409 | 8.38 | 512,429 | 8.32 | 524,256 | 8.34 | | Yola | 126,927 | 2.12 | 128,710 | 2.15 | 118,471 | 1.92 | 118,908 | 1.89 | | Total | 5,989,727 | 100.00 | 5,993,340 | 100.00 | 6,156,726 | 100.00 | 6,288,642 | 100.00 | | Metering Rate by DisCos | | | | | | | | | | Distribution | 2024/Q1 | | 2024/Q2 | | 2024/Q3 | | 2024/Q4 | | Metering Rate by DisCos | Distribution Company | 2024/Q1Metering rate(%) | 2024/Q2Metering rate(%) | 2024/Q3Metering rate(%) | 2024/Q4Metering rate(%) | | --- | --- | --- | --- | --- | | Aba | 32.07 | 35.83 | 37.55 | 37.90 | | Abuja | 61.07 | 70.17 | 70.97 | 76.20 | | Benin | 49.52 | 49.28 | 49.14 | 49.75 | | Eko | 59.10 | 56.71 | 62.90 | 63.11 | | Enugu | 45.16 | 45.48 | 46.89 | 48.11 | | Ibadan | 43.46 | 42.80 | 43.16 | 43.61 | | Ikeja | 73.22 | 76.64 | 76.56 | 77.68 | | Jos | 33.47 | 33.69 | 33.71 | 27.06 | | Kaduna | 24.02 | 23.96 | 24.28 | 24.53 | | Kano | 24.02 | 24.04 | 24.29 | 24.21 | | P/H | 42.47 | 42.61 | 43.46 | 44.46 | | Yola | 15.54 | 15.74 | 14.43 | 14.45 | | Total | 44.79 | 45.43 | 46.15 | 46.57 | * * * F. Commercial Performance Table F.1: DisCos’ energy received, energy billed and billing efficiency (2021- 2024) | DisCos | Total Energy Received (GWh) | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024 Quarters | | | | | | Annual | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2024 | 2023 | 2022 | 2021 | | | Abuja | 1,120 | 1,091 | 1,125 | 1,163 | 4,499 | 4,483 | 3,906 | 4,050 | | Benin | 569 | 563 | 694 | 765 | 2,592 | 2,552 | 2,698 | 2,683 | | Eko | 947 | 942 | 983 | 1,004 | 3,876 | 3,801 | 3,125 | 3,591 | | Enugu | 544 | 535 | 636 | 650 | 2,365 | 2,520 | 2,612 | 2,841 | | Ibadan | 834 | 815 | 958 | 966 | 3,574 | 3,556 | 3,450 | 4,092 | | Ikeja | 1,100 | 1,137 | 1,131 | 1,191 | 4,559 | 4,673 | 4,082 | 4,548 | | Jos | 407 | 334 | 429 | 301 | 1,470 | 1,559 | 1,566 | 1,403 | | Kaduna | 437 | 447 | 446 | 330 | 1,661 | 1,843 | 2,110 | 2,324 | | Kano | 433 | 449 | 476 | 329 | 1,687 | 1,871 | 1,923 | 1,951 | | Port Harcourt | 532 | 524 | 560 | 583 | 2,200 | 2,187 | 2,024 | 2,109 | | Yola | 210 | 129 | 168 | 138 | 645 | 935 | 856 | 902 | | Total | 7,133 | 6,965 | 7,607 | 7,421 | 29,126 | 29,980 | 28,352 | 30,494 | | | Total Energy Billed (GWh) | | | | | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2024 | 2023 | 2022 | 2021 | | Abuja | 846 | 835 | 911 | 918 | 3,510 | 3,239 | 2,677 | 2,682 | | Benin | 489 | 469 | 585 | 665 | 2,208 | 2,179 | 2,274 | 2,246 | | Eko | 849 | 845 | 878 | 896 | 3,468 | 3,402 | 2,786 | 3,141 | | Enugu | 444 | 469 | 477 | 475 | 1,865 | 1,868 | 1,852 | 2,035 | | Ibadan | 717 | 724 | 862 | 869 | 3,173 | 2,824 | 2,567 | 2,920 | | Ikeja | 908 | 937 | 953 | 1,005 | 3,803 | 4,104 | 3,613 | 4,081 | | Jos | 301 | 242 | 269 | 244 | 1,056 | 1,266 | 1,181 | 976 | | Kaduna | 252 | 279 | 286 | 234 | 1,051 | 980 | 1,349 | 1,767 | | Kano | 330 | 332 | 416 | 274 | 1,352 | 1,326 | 1,346 | 1,454 | * * * Table F.2: Revenue performance by DisCos (2021-2024) | DisCos | Total Billing(N'Billion) | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2024 Quarters | | | | Annual | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2024 | 2023 | 2022 | 2021 | | | Abuja | 58.30 | 84.49 | 99.26 | 107.91 | 349.97 | 212.25 | 154.22 | 140.63 | | Benin | 29.40 | 41.24 | 50.77 | 56.28 | 177.69 | 132.12 | 122.07 | 105.77 | | Eko | 56.52 | 85.46 | 103.11 | 107.31 | 352.40 | 211.24 | 151.31 | 145.61 | | Enugu | 26.40 | 40.88 | 46.71 | 49.24 | 163.23 | 111.67 | 101.34 | 98.00 | | Ibadan | 44.79 | 63.01 | 74.96 | 78.64 | 261.40 | 164.92 | 137.33 | 139.71 | | Ikeja | 55.86 | 92.28 | 99.73 | 123.35 | 371.22 | 236.90 | 182.42 | 184.22 | | Jos | 21.85 | 24.07 | 30.73 | 28.67 | 105.32 | 89.31 | 73.57 | 49.32 | | Kaduna | 13.59 | 24.25 | 24.57 | 19.45 | 81.87 | 58.16 | 71.98 | 89.77 | | Kano | 21.58 | 37.33 | 43.89 | 33.72 | 136.52 | 83.85 | 73.79 | 69.17 | | Port Harcourt | 27.69 | 42.02 | 41.31 | 44.01 | 155.03 | 110.08 | 90.34 | 76.23 | | Yola | 12.68 | 8.63 | 10.98 | 9.82 | 42.08 | 52.75 | 26.93 | 18.47 | | Total | 368.65 | 543.64 | 626.02 | 658.40 | 2,196.71 | 1,463.24 | 1,185.31 | 1,116.92 | | | Total Revenue Collected(N'Billion) | | | | | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2024 | 2023 | 2022 | 2021 | | Abuja | 48.60 | 70.19 | 78.28 | 81.45 | 275.81 | 170.20 | 127.80 | 117.61 | | Benin | 22.46 | 33.96 | 41.09 | 45.69 | 141.88 | 84.93 | 69.90 | 58.16 | | Eko | 48.74 | 75.23 | 87.02 | 96.58 | 306.05 | 178.09 | 127.79 | 120.89 | | Enugu | 21.24 | 30.39 | 36.07 | 39.49 | 126.05 | 83.28 | 70.93 | 69.83 | | Ibadan | 30.35 | 44.27 | 57.60 | 60.91 | 192.50 | 113.47 | 95.67 | 91.37 | | Ikeja | 57.88 | 87.36 | 83.55 | 101.92 | 309.48 | 222.43 | 168.31 | 157.40 | | Jos | 13.29 | 15.74 | 16.37 | 14.25 | 57.59 | 40.35 | 31.01 | 24.80 | * * * Table F.3: ATC&C losses performance (2020-2024) | | 2024 | | 2023 | | 2022 | | 2021 | | 2020 | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | | Abuja | 25.00 | 38.51 | 19.27 | 42.06 | 19.27 | 43.20 | 22.80 | 44.62 | 22.33 | 45.8 | | Benin | 25.00 | 31.98 | 17.37 | 45.11 | 17.37 | 51.73 | 21.71 | 53.96 | 23.91 | 55.41 | | Eko | 20.07 | 22.30 | 14.18 | 24.54 | 14.18 | 24.71 | 14.70 | 27.38 | 11.23 | 30.85 | | Enugu | 25.00 | 39.10 | 11.31 | 44.72 | 11.31 | 50.38 | 19.96 | 48.97 | 20.56 | 53.83 | | Ibadan | 25.00 | 34.62 | 15.47 | 45.36 | 15.47 | 48.16 | 18.55 | 53.33 | 19.67 | 56.74 | | Ikeja | 18.73 | 30.44 | 11.37 | 17.54 | 11.37 | 18.33 | 12.52 | 23.34 | 10.81 | 28.21 | | Jos | 32.72 | 60.74 | 27.27 | 63.32 | 27.27 | 68.22 | 35.98 | 65.02 | 39.12 | 67.79 | | Kaduna | 25.00 | 66.52 | 10.65 | 70.07 | 10.65 | 74.90 | 17.18 | 74.05 | 20.12 | 76.80 | | Kano | 25.00 | 55.97 | 15.85 | 54.27 | 15.85 | 53.61 | 18.65 | 48.94 | 22.06 | 50.78 | | PH | 25.00 | 39.56 | 21.45 | 43.66 | 21.45 | 47.30 | 25.85 | 51.76 | 29.70 | 60.80 | | Yola | 56.00 | 54.63 | 64.12 | 65.04 | 64.12 | 69.50 | 29.44 | 75.96 | 23.71 | 73.24 | | All DisCos: | | | | | | | | | | | | MYTO Level | 24.73 | | 20.75 | | 20.75 | | 21.58 | | 22.11 | | | ATC&C Losses | | 37.95 | | 41.67 | | 45.46 | | 46.85 | | 50.57 | | ATC Losses | | 17.88 | | 20.79 | | 23.21 | | 23.43 | | 25.67 | | C Losses | | 24.44 | | 26.36 | | 28.98 | | 30.58 | | 33.50 | MYTO is Multi-Year Tariff Order; ATC&C is Aggregate Technical, Commercial and Collection; ATC is aggregate Technical & Commercial losses; and C is Collection loss * * * Table F.4: NBET and MO invoice to DisCos (2019-2024) | | Jan24 | Feb24 | Mar24 | Apr24 | May24 | Jun24 | Jul24 | Aug24 | Sep24 | Oct24 | Nov24 | Dec24 | 2024 | 2023 | 2022 | 2021 | 2020 | 2019 | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | NBET Invoice | | | | | | | | | Amount in (N'Billion) | | | | | | | | | | | | Abuja | 5.67 | 4.62 | 5.31 | 18.14 | 19.76 | 19.81 | 21.98 | 20.68 | 20.41 | 20.83 | 20.79 | 19.85 | 198.64 | 202.41 | 109.61 | 101.33 | 89.91 | 87.88 | | | Benin | 1.73 | 1.44 | 1.56 | 7.93 | 9.32 | 10.23 | 11.57 | 10.99 | 11.62 | 11.81 | 12.24 | 12.12 | 103.21 | 110.25 | 74.89 | 72.87 | 64.93 | 54.28 | | | Eko | 4.63 | 3.46 | 4.19 | 16.59 | 19.13 | 18.82 | 19.99 | 18.67 | 20.58 | 18.87 | 18.74 | 19.77 | 184.19 | 147.71 | 84.43 | 93.01 | 84.12 | 77.99 | | | Enugu | 1.02 | 0.69 | 0.76 | 6.77 | 8.23 | 9.17 | 10.17 | 10.39 | 10.04 | 9.71 | 10.12 | 10.08 | 88.06 | 112.91 | 75.01 | 75.05 | 62.88 | 52.94 | | | Ibadan | 2.82 | 2.42 | 2.60 | 11.07 | 13.74 | 13.95 | 15.95 | 15.53 | 15.63 | 14.86 | 15.24 | 15.08 | 139.63 | 150.49 | 100.45 | 108.07 | 97.72 | 83.21 | | | Ikeka | 4.75 | 3.66 | 4.38 | 20.29 | 22.38 | 22.39 | 22.46 | 21.94 | 23.04 | 22.35 | 21.72 | 22.61 | 212.75 | 206.65 | 117.90 | 122.51 | 107.19 | 89.52 | | | Jos | 0.81 | 0.73 | 0.81 | 4.48 | 3.40 | 4.00 | 4.77 | 6.08 | 4.07 | 2.99 | 3.61 | 4.41 | 40.49 | 69.73 | 45.56 | 41.33 | 37.44 | 29.46 | | | Kaduna | 0.43 | 0.40 | 0.44 | 5.69 | 6.63 | 6.92 | 7.56 | 6.72 | 3.62 | 2.46 | 4.56 | 5.19 | 51.02 | 79.34 | 60.44 | 63.97 | 58.34 | 45.69 | | | Kano | 0.79 | 0.69 | 0.76 | 6.11 | 7.37 | 6.82 | 8.33 | 7.62 | 4.12 | 2.33 | 4.74 | 5.91 | 56.01 | 81.60 | 57.59 | 58.66 | 52.43 | 41.27 | | NBET and MO are Nigeria Bulk Electricity Trader and Market Operator, respectively. 2024 NBET invoices are DRO-adjusted in the invoices * * * Table F.5: Remittances to NBET and MO by DisCos (2019-2024) | | Jan24 | Feb24 | Mar24 | Apr24 | May24 | Jun24 | Jul24 | Aug24 | Sep24 | Oct24 | Nov24 | Dec24 | 2024 | 2023 | 2022 | 2021 | 2020 | 2019 | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Amount in (N'Billion) | | | | | | | | | | | | | | | | | | | | | Remittances to NBET | | | | | | | | | | | | | | | | | | | | | Abuja | 5.69 | 4.62 | 5.31 | 15.59 | 16.20 | 16.18 | 17.42 | 18.84 | 20.43 | 19.75 | 20.79 | 18.80 | 179.62 | 98.96 | 83.07 | 64.90 | 34.23 | 34.98 | | | Benin | 1.75 | 1.44 | 1.56 | 7.21 | 6.38 | 8.32 | 8.96 | 9.23 | 10.53 | 10.27 | 11.12 | 11.18 | 87.96 | 50.64 | 46.64 | 33.09 | 19.70 | 14.10 | | | Eko | 4.64 | 3.46 | 4.19 | 16.59 | 18.09 | 19.17 | 20.04 | 18.76 | 20.62 | 18.87 | 18.74 | 19.77 | 182.96 | 89.75 | 72.37 | 64.12 | 35.60 | 31.92 | | | Enugu | 1.04 | 0.69 | 0.76 | 5.21 | 6.31 | 7.51 | 7.88 | 8.67 | 8.38 | 8.48 | 9.49 | 9.06 | 73.50 | 52.80 | 51.08 | 42.26 | 19.74 | 12.45 | | | Ibadan | 2.86 | 2.42 | 2.60 | 9.87 | 9.44 | 10.18 | 12.96 | 13.04 | 15.42 | 11.80 | 15.24 | 15.08 | 121.21 | 65.75 | 64.18 | 53.36 | 30.31 | 22.74 | | | Ikeja | 4.79 | 3.66 | 4.38 | 16.57 | 17.04 | 18.08 | 18.35 | 21.77 | 23.20 | 22.35 | 21.72 | 22.61 | 200.90 | 120.03 | 102.95 | 93.37 | 47.99 | 34.37 | | | Jos | 0.81 | 0.73 | 0.81 | 3.59 | 2.17 | 2.08 | 3.67 | 3.44 | 2.57 | 2.99 | 2.43 | 3.42 | 28.71 | 21.82 | 21.05 | 13.13 | 4.66 | 2.12 | | | Kaduna | 0.26 | 0.27 | 0.15 | 1.81 | 1.81 | 1.99 | 2.05 | 1.74 | 1.62 | 1.18 | 2.29 | 1.53 | 16.72 | 6.14 | 10.11 | 14.28 | 12.42 | 6.92 | | | Kano | 0.80 | 0.69 | 0.74 | 4.17 | 4.11 | 5.92 | 6.47 | 5.33 | 1.59 | 2.33 | 4.74 | 5.31 | 42.20 | 25.20 | 27.72 | 31.72 | 13.02 | 10.20 | | NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. * * * Table F.6: Annual Market shortfalls to NBET and MO by DisCos (2019-2024) | | Jan24 | Feb24 | Mar24 | Apr24 | May24 | Jun24 | Jul24 | Aug24 | Sep24 | Oct24 | Nov24 | Dec24 | 2024 | 2023 | 2022 | 2021 | 2020 | 2019 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Shortfalls toNBET | Amount in(N'Billion) | | | | | | | | | | | | | | | | | | | Abuja | (0.02) | 0 | 0 | 2.55 | 3.56 | 3.63 | 4.56 | 1.84 | (0.02) | 1.08 | 0 | 1.05 | 19.02 | 103.45 | 26.54 | 36.43 | 55.68 | 52.89 | | Benin | (0.02) | 0 | 0 | 0.72 | 2.94 | 1.91 | 2.61 | 1.76 | 1.09 | 1.54 | 1.12 | 0.94 | 15.25 | 59.61 | 28.26 | 39.77 | 45.22 | 40.18 | | Eko | (0.01) | 0 | 0 | 0 | 1.04 | (0.35) | (0.05) | (0.09) | (0.04) | 0 | 0 | 0 | 1.23 | 57.96 | 12.06 | 28.89 | 48.52 | 46.07 | | Enugu | (0.02) | 0 | 0 | 1.56 | 1.92 | 1.66 | 2.29 | 1.72 | 1.66 | 1.23 | 0.63 | 1.02 | 14.56 | 60.11 | 23.93 | 32.79 | 43.14 | 40.49 | | Ibadan | (0.04) | 0 | 0 | 1.20 | 4.30 | 3.77 | 2.99 | 2.49 | 0.21 | 3.06 | 0 | 0 | 18.42 | 84.74 | 36.27 | 54.72 | 67.41 | 60.47 | | Ikeja | (0.04) | 0 | 0 | 3.72 | 5.34 | 4.31 | 4.11 | 0.17 | (0.16) | 0 | 0 | 0 | 11.85 | 86.62 | 14.95 | 29.13 | 59.20 | 55.14 | | Jos | 0 | 0 | 0 | 0.89 | 1.23 | 1.92 | 1.10 | 2.64 | 1.50 | 0 | 1.18 | 0.99 | 11.78 | 47.91 | 24.51 | 28.20 | 32.78 | 27.34 | | Kaduna | (0.17) | 0.13 | 0.29 | 3.88 | 4.82 | 4.93 | 5.51 | 4.98 | 2.00 | 1.28 | 2.27 | 3.66 | 34.30 | 73.20 | 50.33 | 49.69 | 45.92 | 38.77 | | Kano | (0.01) | 0 | 0.02 | 1.94 | 3.26 | 0.90 | 1.86 | 2.29 | 2.53 | 0 | 0 | 0.60 | 13.81 | 56.39 | 29.87 | 26.94 | 39.41 | 31.07 | | Port Harcourt | (0.01) | 0 | 0 | 1.19 | 1.12 | 2.18 | 1.30 | 2.02 | 3.16 | 0 | 1.05 | 1.63 | 14.04 | 53.86 | 25.32 | 29.66 | 39.46 | 37.22 | NBET and MO are Nigeria Bulk Electricity Trader and Market Operators, respectively. * * * Table F.7: Market invoice, remittance and shortfall by DisCos (2019-2024) \| \| Invoice (N' Billion) \| \| \| \| \| \| Remittances (N' Billion) \| \| \| \| \| \| \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \| DisCos \| 2024 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| 2024 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| \| Abuja \| 233.57 \| 158.12 \| 118.96 \| 126.93 \| 109.57 \| 102.99 \| 212.09 \| 119.76 \| 100.53 \| 92.68 \| 50.91 \| 46.07 \| \| Benin \| 121.85 \| 68.25 \| 78.00 \| 93.08 \| 78.44 \| 63.61 \| 103.85 \| 62.87 \| 57.01 \| 48.32 \| 33.34 \| 21.19 \| \| Eko \| 210.32 \| 104.85 \| 89.64 \| 116.44 \| 102.14 \| 91.37 \| 207.29 \| 107.90 \| 87.55 \| 87.05 \| 53.58 \| 43.94 \| \| Enugu \| 105.10 \| 79.78 \| 82.33 \| 95.47 \| 75.96 \| 62.03 \| 88.29 \| 62.66 \| 61.10 \| 58.32 \| 32.81 \| 19.21 \| \| Ibadan \| 166.21 \| 91.29 \| 101.76 \| 137.1 \| 118.53 \| 97.50 \| 145.06 \| 82.33 \| 82.72 \| 74.61 \| 50.58 \| 33.98 \| \| Ikeja \| 246.65 \| 151.81 \| 123.19 \| 154.67 \| 128.80 \| 104.82 \| 233.35 \| 144.47 \| 122.90 \| 116.88 \| 69.60 \| 47.72 \| \| Jos \| 50.98 \| 35.03 \| 38.53 \| 53.65 \| 44.84 \| 34.52 \| 36.08 \| 28.29 \| 27.33 \| 22.34 \| 11.70 \| 5.70 \| \| Kaduna \| 62.86 \| 45.70 \| 60.65 \| 79.82 \| 70.20 \| 53.58 \| 19.83 \| 7.30 \| 13.39 \| 19.3 \| 21.64 \| 12.62 \| \| Kano \| 66.69 \| 50.70 \| 58.61 \| 71.5 \| 62.52 \| 48.38 \| 49.94 \| 30.79 \| 34.18 \| 40.22 \| 22.21 \| 15.12 \| \| Port Harcourt \| 96.67 \| 63.29 \| 57.76 \| 67.57 \| 58.53 \| 53.63 \| 80.42 \| 51.25 \| 39.18 \| 34.92 \| 18.39 \| 14.28 \| \| Yola \| 9.43 \| 9.23 \| 6.81 \| 31.59 \| 33.20 \| 31.07 \| 8.68 \| 9.11 \| 6.37 \| 4.4 \| 5.59 \| 6.88 \| \| Total \| 1,370.35 \| 858.03 \| 816.25 \| 1,027.83 \| 882.73 \| 743.50 \| 1,184.88 \| 706.73 \| 632.25 \| 599.04 \| 370.34 \| 266.71 \| \| \| Shortfalls (N' Billion) \| \| \| \| \| \| Remittance Performance (%) \| \| \| \| \| \| \| DisCos \| 2024 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| 2024 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| NBET and MO are Nigeria Bulk Electricity Trader and Market Operator, respectively. 2024 market data is based on DRO, while 2023 and 2022 market data are based on MRO * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION