NIGERIAN ELECTRICITY REGULATORY COMMISSION 2022 Annual Report & Accounts * * * # 2022 Annual Report # & Accounts ## Nigerian Electricity Regulatory Commission ## Plot 1387 Cadastral Zone A00 ## Central Business District ## PMB 136, Garki Abuja **[www.nerc.gov.ng](http://www.nerc.gov.ng/)** * * * ## Preface and Content NERC Annual Report 2022 **NERC©2023** ## NERC Annual Report & Accounts is prepared in compliance with section 55 (1) ## of the Electric Power Sector Reform (EPSR) Act 2004, 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 * * * ## Preface and Content NERC Annual Report 2022 ## The Nigerian Electricity Regulatory Commission was **established by the Electric Power Sector Reform (EPSR) Act** **2004, with the principal objects outlined under section 32 to:** **1\. Create, promote, and preserve efficient industry and** **market structures, and ensure the optimal utilisation of** **resources for the provision of electricity services;** **2\. Maximise access to electricity services, by promoting and** **facilitating consumer connections to distribution systems in** **both rural and urban areas;** **3\. Ensure that an adequate supply of electricity is available** **to consumers;** **4\. 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;** **5\. Ensure the safety, security, reliability, and quality of service** **in the production and delivery of electricity to consumers;** **6\. Ensure that regulation is fair and balanced for licensees,** **consumers, investors, and other stakeholders and;** **7\. Present quarterly reports to the President and National** **Assembly on its activities.** ## Nigerian Electricity Regulatory Commission II * * * ## Preface and Content NERC Annual Report 2022 **Mission** **Promote and ensure an** **investor-friendly industry and** **efficient market structure to** **meet the needs of Nigeria for** **safe, adequate, reliable and** **affordable electricity.** **Vision** **“Electricity on demand”** **Motto:** **“Keeping the lights on”** ## Nigerian Electricity Regulatory Commission III * * * ## Preface and Content NERC Annual Report 2022 **Values** **NERC has four (4) guiding values:** **1\. Leadership: excellence, transparency,** **courage and discipline;** **2\. Professionalism: proficiency, diligence,** **respect, fairness and accountability;** **3\. Teamwork: creating an environment of** **loyalty, trust, collaboration, and** **stakeholder engagement;** **4\. Good Governance: making decisions** **in a fair, transparent and consistent** **manner, in compliance with the laws of** **Nigeria and our regulations.** ## Nigerian Electricity Regulatory Commission IV * * * TABLE OF CONTENTS PART 1: LEADERSHIP OF THE COMMISSION ..... 1 PART 2: EXECUTIVE SUMMARY ..... 14 PART 3: CORPORATE ACTIVITIES OF THE COMMISSION ..... 31 3.1. The Commission ..... 33 3.1.1. Background to the Creation of the Commission ..... 33 3.1.2. Objects and Functions of the Commission ..... 34 3.1.3. Mission, Vision and Motto of the Commission ..... 35 3.1.4. Values of the Commission ..... 35 3.1.5. Structure of the Commission ..... 36 3.2. Strategic Plan and Performance Monitoring System ..... 39 3.3. Staff Composition ..... 44 3.3.1. Distribution by Division ..... 44 3.3.2. Distribution by Cadre ..... 44 3.3.3. Distribution by Gender ..... 45 3.3.4. Distribution by age .. * * * Preface and Content 4.2.1. Energy offtake performance .....66 4.2.2. Energy Billed and Billing Efficiency .....69 4.2.3. Revenue and Collection Efficiency .....71 4.2.4. Aggregate Technical, Commercial and Collection (ATC&C) Loss ..73 4.2.5. Market Remittance .....75 PART 5: REGULATORY FUNCTIONS .....82 5.1. Regulations, Orders and Guidelines .....84 5.1.1. Regulations .....84 5.1.2. Orders .....84 5.1.3. Guidelines .....88 5.2 Licensing and Permits .....88 5.2.1. Generation, Trading and Distribution Licenses .....88 5.2.2. Captive Generation Permits .....90 5.2.3. Certification of Meter Asset Providers/Metering Service Providers91 5.2.4. Eligible Customer Authorisations .....92 5.2.5. Mini-grid Oper * * * ## Preface and Content NERC Annual Report 2022 ## LIST OF TABLES **Table 2.1: Cadre and Gender Distribution of the Commission’s Staff in 2022 ... 18** **Table 2.2: System Collapse (2018 – 2022) ... 20** **Table 2.3: Orders issued by the Commission in 2022 ... 25** **Table 3.1: Summary of Progress on the Commission’s Strategic Plan in 2022 ... 41** **Table 3.2: Distribution of the Commission’s Staff by Divisions in 2022 ... 44** **Table 3.3: Distribution of the Commission’s Staff by Cadre in 2022 ... 45** **Table 4.1: TLF Improvement Trajectory 2022 - 2026 ... 60** **Table 4.2: Total and Partial System Collapses ... 65** **Table 4.3: Energy Offtake Performance in 2022 ... 68** **Table 4.4: Energy Received and Billed by DisCos for 2021 and 2022 ... 70** **Table 4.5: Revenue Performance of DisCos in 2021 and 2022 ... 72** **Table 4.6: ATC&C Loss of DisCos in 2021 and 2022 ... 74** **Table 4.7: Minimum Remittance Obligation to NBET & MO by DisCos in 2022 ... 76** **Table 4.8: Annual Remittance Performance to NBET and MO ... 79** **Table 4.9: International and Bilateral Customers Invoices & Remittances in 2022... 81** **Table 5.1: Summary of New Licences Granted in 2022 ... 89** **Table 5.2: Captive Generation Plants Approved in 2022 ... 90** **Table 5.3: Category of Meter Service Providers Certified in 2022 ... 91** **Table 5.4: Eligible Customers Authorised in 2022 ... 92** **Table 6.1: Customers Metering Status by DisCos ... 100** **Table 6.2: Complaints Received and Resolved by DisCos in 2021 and 2022 ... 104** **Table 6.3: Appeals Handled by Forum Offices in 2022 ... 107** **Table 6.4: NESI Licensee Health and Safety Reports of 2021 and 2022 ... 109** **Table 6.1: Customers Metering Status by DisCos ... 100** **Table 6.2: Complaints Received and Resolved by DisCos in 2021 and 2022 ... 104** **Table 6.3: Appeals Handled by Forum Offices in 2022 ... 107** **Table 6.4: NESI Licensee Health and Safety Reports of 2021 and 2022 ... 109** ## Nigerian Electricity Regulatory Commission VII * * * ## Preface and Content NERC Annual Report 2022 ## LIST OF FIGURES **Figure 2.1: DisCos Billing and Collection Efficiencies in 2022 ... 22** **Figure 2.2: DisCos’ Remittance Performance in 2022 ... 23** **Figure 3.1: Organisational structure of NERC as at December 2022 ... 37** **Figure 3.2: Distribution of the Commission’s Staff by Gender in 2022 ... 46** **Figure 3.3: Distribution of the Commission’s Staff by Cadre & Gender in 2022 ... 46** **Figure 3.4: Staff Distribution by Age as at 31st December 2022 ... 47** **Figure 4.1: Average Daily Available Capacity in 2021 and 2022 ... 53** **Figure 4.2: Average Daily Generation in 2021 and 2022 ... 53** **Figure 4.3: Average Plant Load Factor (%) in 2021 and 2022 ... 56** **Figure 4.4: Average Share (%) of Generation Output by Plants in 2022 ... 57** **Figure 4.5: Share of Electricity Generated by Energy Sources ... 59** **Figure 4.6: Transmission Loss Factor in 2021 and 2022 ... 61** **Figure 4.7: Average System Frequency (Hz) in 2021 and 2022 ... 62** **Figure 4.8: System Voltage (kV) in 2021 and 2022 ... 63** **Figure 6.1: Meter Installation in 2021 and 2022 ... 102** **Figure 6.2: Categories of Complaints Received by DisCos ... 105** **Figure 6.3: Category of Complaints Received by Forum Offices in 2022 ... 108** **Figure 6.1: Meter Installation in 2021 and 2022 ... 102** **Figure 6.2: Categories of Complaints Received by DisCos ... 105** **Figure 6.3: Category of Complaints Received by Forum Offices in 2022 ... 108** ## Nigerian Electricity Regulatory Commission VIII * * * ADR Alternative Dispute Resolution AEDC Abuja Electricity Distribution Company Plc ANAN Association of National Accountants of Nigeria ATC&C Aggregate Technical, Commercial & Collection Losses BCR Business Continuity Regulations BEDC Benin Electricity Distribution Company 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 ECN Electricity Corporation of Nigeria EEDC Enugu Electricity Distribution Company Plc EKEDC Eko Electricity Distribution Company 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 Company Plc ICAN Institute of Chartered Accountants of Nigeria IEDN Independent Electricity Distribution Network IKEDC Ikeja Electricity Distribution Company Plc IPP Independent Power Plant JEDC Jos Electricity Distribution Company Plc KDEDC Kaduna Electricity Distribution Company Plc KNEDC Kano Electricity Distribution Company 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 NACCIMA Nigerian Association of Chambers of Commerce Industry, Mines and Agriculture NAEE Nigerian Association for Energy Economics NBA Nigerian Bar Association NBET Nigerian Bulk Electricity Trading plc NDA Niger Dams Authority NEPA National Electric Power Authority NEPP Nigerian Electric Power Policy NERC Nigerian Electricity Regulatory Commission NESCO Nigerian Electricity Supply Company Limited NESI Nigerian Electricity Supply Industry NICE Notices of Intention to Commence Enforcement NIGELEC Nigerien Electricity Society NIM Nigerian Institute of Management NIPP National Integrated Power Project NSE Nigerian Society of Engineers PP Percentage Points PHCN Power Holding Company of Nigeria PHEDC Port Harcourt Electricity Distribution Company Plc PRS Planning Research and Strategy REC Regulation on Eligible Customers SBEE Société Béninoise d'Energie Electrique TCN Transmission Company of Nigeria Plc TLF Transmission Loss Factor YEDC Yola Electricity Distribution Company Plc * * * # PART 1: LEADERSHIP OF Draft 2017 Annual Report # THE COMMISSION * * * # 1.1 Board of Commissioners 1.2 General Managers of the Divisions # 1.3 Secretary of the Commission Draft 2017 Annual Report # 1.4 Members of the Management Staff 1.5 Forum Office Secretaries * * * ## NERC Leadership NERC Annual Report 2022 **1.1 Board of Commissioners** 1.2 ## Nigerian Electricity Regulatory Commission * * * ## NERC Leadership NERC Annual Report 2022 ## Nigerian Electricity Regulatory Commission * * * 1.2. General Managers of the Divisions While the overall effective performance and management of the Divisions rest with the Commissioners, each Division has a General (or Deputy General) Manager who coordinates the day-to-day activities of the Division and also cover some functions of the Commissioner in his/her absence. The under-listed staff are the General Managers of the Divisions as at 31st December 2022. 1. Bassey N. Ayambem GM, Planning, Research & Strategy (PRS) 2. Dr Usman Abba-Arabi GM, Public Affairs, ’ (CO) 3. Sharfuddeen Mahmud GM, Market Competition and Rate (MCR) 4. Abdulkadir Shettima GM, Finance & Management Services (FMS) 5. Abdul B. Mohammed GM, Engineering Performance & Monitoring (EPM) 6. Zubairu T. Ahmadu GM, Legal Licencing & Compliance (LLC) 7. Maryam Y. Abubakar GM, Procurement (CO) 1.3. Secretary of the Commission The Secretary of the Commission provides administrative support, coordinates, and records minutes of the meeting of the Board of Commissioners. The Secretary of the Commission as at 31st December 2022 is: 8. Ada Ozoemena DGM, Secretariat, CO 1.4. Members of the Management Staff The General Managers of the Divisions, the Secretary of the Commission and the under-listed members of staff made up the Management Staff of the Commission as at 31st December 2022. † 9\. Chinedu Ukabiala DGM, Generation, EPM ‡ 10\. James O. Ewah DGM, Inspectorate, LLC 11. Shittu Shaibu DGM, Customer Service Standards, CA Retired voluntarily on September 30, 2022 † Retired voluntarily on October 10, 2022 13. Abdussalam Yusuf DGM, Research, PRS 14. Abba I. Terab DGM, Tariff & Rates, MCR † Retired voluntarily on October 10, 2022 ‡ Mr James Ewah unfortunately passed away on August 29, 2022 ‡ Mr James Ewah unfortunately passed away on August 29, 2022 * * * 14. Abdullah Adamu DGM, ICT, FMS 15. Razak Y. Afolayan AGM, Generation, EPM 16. Arit Uya AGM, Consumer Complaints, CA 17. Michael Faloseyi AGM, Public Affairs, CO 18. Kanneng Gwon AGM, Customer Service Standards, CA 19. Zubair B. Zubair AGM, Consumer Enlightenment & Education, CA 20. Iko Bolus AGM, Internal Audit, CO 21. Ene Effiom AGM, Compliance & Enforcement, LLC 22. John D. Joseph AGM, Engineering & Standards, EPM 23. Jonathan Okoronkwo AGM, Corporate Planning & Strategy, PRS 24. Friday E. Sule AGM, Market Analysis, MCR 25. Abu Kadiri AGM, Health Safety & Standards, EPM 26. Chuka Akunne AGM, Human Resources Development, FMS 27. Mary Anahve AGM, Public Affairs, CO 28. Rasheed Busari AGM, General Administration, FMS 29. Habib Kidaji AGM, Human Resources Development, FMS 30. Saidu Lawal AGM, ICT, FMS 31. Regina Osuagwu AGM, Consumer Affairs, CA 32. Umar Mohammed AGM, Research, PRS 33. Emeka Onyegbule AGM, Market Competition and Rates, MCR 34. Ahmed Ndanusa AGM ’ 35. Anthony Essien AGM, Consumer Affairs, CA 36. Okpale Daisy AGM, Licensing, LLC 37. Imam Mohammed AGM, Health Safety and Environment, EPM w ’ were set up pursuant to section 80(1)(b) of the EPSRA to hear and resolve ’ Complaints Units (DisCos-CCU). The forum office is managed by the forum secretariat while the hearings are conducted by five forum panel members who are not Commission staff. The daily activities ’ 1.5. Forum Office Secretaries 37. Imam Mohammed AGM, Health Safety and Environment, EPM 38. Bala Ado Shehu AGM, Finance and Accounts, FMS * * * ## NERC Leadership NERC Annual Report 2022 ## across Nigeria are coordinated by the under-listed staff members as Forum ## Secretaries as at 31st December 2022. ## 1\. Henritta Ene Abakaliki Forum Office, Ebonyi State ## 2\. Abubakar Kurna Abeokuta Forum Office, Ogun State ## 3\. Grace Ekpenyong Abuja Forum Office, Federal Capital Territory ## 4\. Samson Osi Onu Asaba Forum Office, Delta State ## 5\. Princess Agwu Awka Forum Office, Anambra State ## 6\. Samuel Andzenge\* Bauchi Forum Office, Bauchi State ## 7\. Benjamin A. Eboehi Benin Forum Office, Edo State ## 8\. Blessing Ikharo Calabar Forum Office, Cross River State ## 9\. Kabiru Musa Dutse Forum Office, Jigawa State ## 10\. Ado Jamilu Eko Forum Office, Lagos State ## 11\. Henrietta Ene\* Enugu Forum Office, Enugu State ## 12\. Bashir Adam Gombe Forum Office, Gombe State ## 13\. Ashiru Abdu Na Abdu Gusau Forum Office, Zamfara State ## 14\. Olaiya O. Abe Ibadan Forum Office, Oyo State ## 15\. Patrick Ezeocha Ikeja Forum Office, Lagos State ## 16\. Kabiru Musa Ilorin Forum Office, Kwara State ## 17\. J ’ \* Jigawa Forum Office, Jigawa State ## 18\. Samuel Andzenge Jos Forum Office, Plateau State ## 19\. Mansur Abdullahi Kaduna Forum Office, Kaduna State ## 20\. J ’ Kano Forum Office, Kano State ## 21\. Abubakar Kurna Katsina Forum Office, Katsina State ## 22\. Samuel Negedu Lafia Forum Office, Nasarawa State ## 23\. Nebo Joseph Lokoja Forum Office, Kogi State ## 24\. Pamela Ishaya Makurdi Forum Office, Benue State ## 25\. Afaoma Ubani Owerri Forum Office, Imo State ## 26\. Aminu Oguta Osogbo Forum Office, Osun State ## 27\. Ukongim P. Akubue Port-Harcourt Forum Office, River State ## 28\. Ashiru Abdu Na Abdu\* Sokoto Forum Office, Sokoto State ## 29\. Chioma Okechukwu Umuahia Forum Office, Abia State ## 30\. Peter A. Dickson Uyo Forum Office, Akwa Ibom State ## 31\. Mutari Aliyu Yola Forum Office, Adamawa State \* **Staff were deployed to temporarily oversee additional Forum Offices.** ## Nigerian Electricity Regulatory Commission * * * # PART 2: EXECUTIVE SUMMARY * * * # A. Corporate Strategy and Structure B. State of the Industry # C. Regulatory Functions D. Consumer Affairs # E. Financial Reporting * * * CORPORATE STRATEGY A AND STRUCTURE The Nigerian Electricity Regulatory Commission (NERC): In 2022, the Commission continued the implementation of its 2021- 2023 Strategic Plan focusing on its ten (10) critical goals targeted at addressing the challenges in the Nigerian Electricity Supply Industry (NESI). The overarching objectives of the plan include: The Commission has 7 Divisions sub-divided into 25 units. i) Making the sector financially sustainable. C C ii) Providing adequate and reliable power supply to Nigerians. iii) Improving customer care. D iv) Consolidating the achievements within the Commission. The Commission continues to reposition itself to provide robust regulatory interventions as the sector continues its transition from a state-owned monopoly to an unbundled competitive electricity market structure as enshrined in the Electric Power Sector Reform Act (EPSRA) 2004. ▪ Chairman’s Office (CO) ▪ Consumer Affairs (CA) ▪ Engineering Performance & Monitoring (EPM) ▪ Engineering Performance & Monitoring (EPM) Finance & Management Services (FMS) ▪ Finance & Management Services (FMS) Legal, Licensing & Compliance (LLC) The seven (7) Divisions of the Commission are further subdivided into twenty-five (25) Units. Each division is headed by a Commissioner who is charged with the responsibility of overseeing the affairs of the Division. In addition, a management staff not lower than the rank of Deputy General Manager (DGM) coordinates the day-to-day activities of each Division and reports to the Commissioner. ▪ Legal, Licensing & Compliance (LLC) Market Competition & Rates (MCR) ▪ Planning, Research & Strategy (PRS) ▪ Market Competition & Rates (MCR) ▪ Planning, Research & Strategy (PRS) * * * Staff Composition: In 2022, the count of the Commission’s total manpower was one hundred and forty-three (143) broken down as follows – ▪ Seven (7) Commissioners ▪ Thirty-five (35) Management staff ▪ Eighty (80) Mid-management staff, and ▪ Eighty (80) Mid-management staff, and ▪ Twenty-one (21) 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. In 2022, the Commission’s members of staff consisted of 7 Commissioners, 35 Management, 80 Mid- Management, & 21 junior staff. The Commission’s workforce cadre in 2022 was split as follows: • Management staff cadre (General Manager, Deputy General Manager and Assistant General Manager) account for 25.74% of the workforce. • Senior Staff cadre (Principal Manager, Senior • Senior Staff cadre (Principal Manager, Senior Manager, and Manager) account for 52.21% of the workforce. • Middle-level staff cadre (Assistant Manager and • Middle-level staff cadre (Assistant Manager and Analysts I–III) account for 6.62% of the workforce, and • Junior cadre (Drivers, Office Assistants) account for • Junior cadre (Drivers, Office Assistants) account for 15.44% of the Commission’s workforce in 2022. From a gender representation standpoint, the Commission strives to promote fair representation across all cadres. Table 2.1 shows that as at the end of December 2022, 26.47% of the professional staff of the Commission are female. The Commission is committed to promoting equitable female representation within the Commission and the wider NESI. * * * Table 2.1: Cadre and Gender Distribution of the Commission’s Staff in 2022 | No | Position | Cadre | Male | Female | Total | | --- | --- | --- | --- | --- | --- | | 1 | General Manager | | 5 | 1 | 7 | | 2 | Deputy General Manager | Mgt. Cadre | 4 | 1 | 7 | | 3 | Assistant General Manager | | 20 | 4 | 25 | | 4 | Principal Manager | | 11 | 12 | 26 | | 5 | Senior Manager | Senior Cadre | 14 | 8 | 23 | | 6 | Manager | | 22 | 4 | 26 | | 7 | Assistant Manager | | 3 | 3 | 7 | | 8 | Analyst I | Middle Cadre | 0 | 3 | 3 | | 9 | Analyst II | | 0 | 0 | 0 | | 10 | Analyst III | | 0 | 0 | 0 | | 11 | Junior Staff | Junior Cadre | 21 | 0 | 21 | | | Total | | 105 | 40 | 145 | Note: The staff’s distribution in this table excludes the Commissioners and their Aides Capacity Development, Promotion and Exit: The Commission places a premium on staff capacity development, and on account of this, members of staff attended the required inperson and remote regulatory, management and leadership courses in 2022. In line with its condition of service, the Commission conducted the promotion exercise for eligible staff in 2022. Participants who were adjudged to have satisfied the stipulated requirements were duly promoted. In 2022, the Commission sponsored staff to attend trainings, workshops and Seminars on subjects/areas that are beneficial to its statutory responsibilities. Reporting Obligation of the Commission: Pursuant to section 55(3) of the EPSRA 2004, the Commission has published the Q1-Q4 2022 reports of its activities and is currently in the process of making copies available to Mr President and the National Assembly. The reports analyse the state of the industry (covering the technical, operational and commercial performances), regulatory functions, consumer affairs and the Commission’s finances. Also, in compliance with sections (55) & (56) of the EPSRA, mandating the Commission to keep proper accounts and other records relating to its activities, funds & property, the Commission has prepared its audited financial reports for the year ended 31st December 2022. * * * STATE OF THE INDUSTRY The Partial Activation of Contract regime took effect in July 2022. In 2022, the average capacity utilisation rate was 86.05%. Operational Performance: Pursuant to the regulatory authority vested on the Commission in the EPSRA 2004, the Commission continued overseeing the operational performance of the NESI. The summary of the NESI’s operational performance for 2022 is provided below. Available Capacity and Generation: In 2022, the average daily available capacity of the twenty-seven (27) active power plants was 4,526.83MW while the average daily generation was 3,988MWh/h. Compared to 2021, the available capacity decreased by 727.20MW (-13.84%) and the average daily generation also decreased by 209MWh/h (- 4.98%). The industry recorded its highest daily generation of 4,598.05MWh/h on 12th February 2022. The average utilisation of available generation capacity across all power plants increased from 79.92% in 2021 to 86.05% in 2022 (+6.13pp). The improved utilisation was due to the effect of the Partial Activation of Contract (PAC) regime which began in July 2022 and has improved licensees’ commitment to energy delivery and offtake within respective Partially Contracted Capacity (PCC). The PAC regime activation is one of the Commisison’s initiatives to fast track NESI maturity, improve market discipline, encourage investment for improvement, and achieve adequate electricity supply. Building on the escrow arrangement put in place by the Commission in collaboration with the Central Bank of Nigeria Commission in collaboration with the Central Bank of Nigeria (CBN) for improvement players on behalf of the DisCos in the sector, the Commission activated the Gas Supply Stabilisation Fund (GSSF) initiative in July 2022. The Commission continues its surveillance on the challenges in NESI with respect to gas supply and is committed to engaging relevant stakeholders to develop lasting solutions to this problem. Commission in collaboration with the Central Bank of Nigeria (CBN) for improvement in payment assurance to upstream players on behalf of the DisCos in the sector, the Commission activated the Gas Supply Stabilisation Fund (GSSF) initiative in July 2022. The Commission continues its surveillance on the challenges in NESI with respect to gas supply and is committed to engaging relevant stakeholders to develop lasting solutions to this problem. * * * ## Executive Summary NERC Annual Report 2022 ## to completely resolve the technical, operational and ## commercial challenges in the NESI. Pursuant to this effort, the ## Commission has finalised the review the Performance ## Improvement Plans (PIP) filed by the DisCos for relevant and ## qualified projects. The PIPs were prepared in line with the ## guidelines provided by the Commission, to cover the period ## 2021–2025 and have an overall objective of ensuring that ## utilities invest in projects critical to addressing their technical, ## operational and commercial constraints. ## National Grid Stability: A summary of the system stability ## performance of the national grid between 2018 and 2022 is ## contained in Table 2.2. The table shows that there was a ## decline in the stability of the grid network in 2022 as the ## number of total system collapses (i.e., total blackouts ## nationwide) increased relative to the preceding year. ## This decline in grid reliability in 2022 is further proven by the ## fact that the range of 1.73Hz between the average maximum ## and average minimum grid frequency in 2022 is higher than ## 1.41Hz which was recorded in 2021. Table 2.2: System Collapse (2018 – 2022) **2018 2019 2020 2021 2022** **No. of Partial Collapse 1 1 0 2 2** **No. of Total Collapse 12 10 4 2 4** ## While the grid reliability performance declined in 2022, ## overall, the network has recorded a downward trajectory in ## terms of number of grid incidents since 2018. To maintain this ## trajectory of improvements in network stability, the ## Commission continues to monitor the implementation of its ## directive to DisCos and the Transmission Company of Nigeria ## (TCN) to execute Service Level Agreements (SLAs) that will ## ensure grid discipline. The Commission is also exploring ## options for the enforcement of under frequency load-shedding ## scheme which has been put in place to provide an added layer ## Nigerian Electricity Regulatory Commission * * * ## Executive Summary NERC Annual Report 2022 ## of security for the grid in the case of a sudden loss of **generation.** ## Commercial Performance: As indicated earlier, the financial ## viability of the NESI remains a major priority of the ## Commission. The summary of the commercial performance of ## the NESI focused on the underlisted parameters is provided **below:** - **Energy offtake performance of DisCos** - **Energy billed and billing efficiency** - **Revenue and collection efficiency** - **Remittances by downstream market participants to the** **Market Operator (MO) and the Nigerian Bulk** **Electricity Trading Company (NBET)** ## Energy offtake performance: In 2022, the total energy ## received by DisCos at their trading points was ## 28,351.62GWh. This is a decrease of 2,142.48GWh (- **In 2022, the** **overall DisCos’ 7.03%) from the 30,494.10GWh which was recorded in** **billing and** **2021 and is partly attributable to the 4.98% decrease in the** **collection** **efficiencies total energy generated in 2022 relative to 2021. With the** **were 76.79%** **Commission’s effort to achieve market maturity and improved** **and 71.02%** **respectively. upstream payments, energy offtake by DisCos transited from** **1** **MYTO allocation to Partially Contracted Capacity (PCC) in** **July 2022. In the first half of 2022, only one (1) DisCo** **recorded positive variance on its load offtake compared to its** **MYTO allocations while five (5) DisCos recorded positive** **variances in their energy offtakes compared to their PCC in** **the second half of the year. Cumulatively, the energy offtake** **performance of the DisCos improved in 2022/H2** **(3,330.33MWh/h) by 6.02% compared to 2022/H1** **(3,141.09MWh/h) partly attributable to the transition to the** **PAC regime.** 1 **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 it associated payments) for most of the grid-** **connected power plants.** ## Nigerian Electricity Regulatory Commission * * * ## Executive Summary NERC Annual Report 2022 ## Billing and Collection efficiencies: Figure 2.1 shows the billing ## and collection efficiencies by all DisCos in 2022. Out of the ## 28,351.62GWh total energy received by all DisCos, ## 21,770.79GWh was billed to the end-users, resulting in a ## billing efficiency of 76.79% which represents a 0.22pp ## increase from the billing efficiency recorded in 2021 **(76.57%).** **Figure 2.1: DisCos Billing and Collection Efficiencies in 2022** **illing Ef ciency Collection Ef ciency** **00** **2** **0** **0 0 0** **0** **(%)** **2** **Ef ciency 0** **20** **0** **bu a enin Eko Enugu Ibadan Ike a Jos aduna ano ort ola** **arcourt** ## The total billings to electricity consumers by the DisCos was ₦1,185.31 **billion of which only** ₦841.81 **billion was** **collected, leaving a total outstanding balance of ₦343.50** **billion and corresponding to a collection efficiency of** **71.02%. This collection efficiency represents 1.60pp increase** **compared to 69.42% (₦775.33 billion collected out of a total** **bill of ₦1,116.93 billion) recorded in 2021.** ## Market Remittance: The financial viability of the industry is ## further assessed with the market settlement rate by DisCos and ## special customers to NBET and MO. ## Nigerian Electricity Regulatory Commission * * * ## Executive Summary NERC Annual Report 2022 ## Remittance by DisCos: In 2022, a total invoice of ₦816.25 ## billion was issued to all the DisCos for energy received from **The overall** **remittance was NBET and for service charges by the MO, out of which a sum** **6.11 percentage** ## of ₦632.25 billion was settled by DisCos, leaving a total **points higher than** **the overall deficit of ₦184.00 billion in the market. This payment** **remittance of** **translates to an overall remittance performance of 77.46%** **71.35% in 2021.** ## which is a 6.11pp increase compared to the overall remittance ## in 2021 (71.35%). The individual DisCo’s remittance ## performances to NBET and MO in 2022 are represented in **Figure 2.2.** Figure 2.2: DisCos’ Remittance Performance in 2022 **erformance to N ET erformance to MO** **00** **00** **02** **0** **(%)** **0** **erformance** **0** **20** **20** **0** **bu a enin Eko Enugu Ibadan Ike a Jos aduna ano ort ola** **arcourt** **The** **Ikeja and Eko DisCos had high remittance performances of** **International** **3** **102.04% and 99.81% respectively to NBET in 2022 while** **Customers made** **a total payment** **Kano and Kaduna achieved the lowest NBET remittance** **of $50.68 performances of 58.37% and 20.21% respectively. The** **million out of a** **highest remittance performances to the MO were recorded by** **total invoice of** **$52.72 million Yola and Ikeja at 98.08% and 89.45% respectively while** **issued to them** **Kaduna recorded the lowest MO remittance performance of** **by the MO.** **30.81% in 2022.** 2 **The NBET portion of the total invoice issued to DisCos has been adjusted for the Minimum Remittance** **Obligation (MRO) of the DisCos.** **3** **Remittance performance above the MRT could be due to retroactive review of the minimum remittance** **threshold or payment of arrears. Ikeja DisCos’s performance above MRT is due to payment of** **arrears/outstanding.** ## Nigerian Electricity Regulatory Commission * * * ## Executive Summary NERC Annual Report 2022 ## Remittances by Special and International Customers: In 2022, ## the NESI continued to provide electricity to 3 international ## customers. Cumulatively, the 3 international customers, i) ## Societe eninoise d’Energie Electrique; ii) Compagnie Energie ## Electrique du Togo; iii) Societe Nigerienne d’electricite, ## received an invoice of $52.72 million from MO and made a ## payment of $50.68 million. This corresponds to a remittance ## performance of 96.13% and a 61.41pp increase compared ## to 34.72% remittance performance in 2021 ($14.96 million ## paid against a total invoice of $43.09 million). The domestic ## bilateral customers operating in the NESI received a total ## invoice of ₦5,791.85 million from MO and made a payment **of** ₦5,516.76 **million corresponding to a remittance** **performance of 95.25%.** ## In 2022, the NESI also supplied electricity to one special ## customer - Ajaokuta Steel Co. Ltd and the host community. ## Unfortunately, the customer continued the same pattern of ## non-payment as it exhibited in 2021 with ₦0 paid against the ₦1.39 billion and ₦0.27 billion invoices received from NBET **and MO respectively in 2022. The MO and NBET must** **activate the relevant safeguards against continued non-** **settlement of market obligations by these market participants.** ## The financial viability of the NESI remained a major challenge ## in 2022. The liquidity challenge was largely driven by market ## shortfalls by DisCos i.e., non-payment of 100% of their market ## obligations. The DisCos were unable to pay their bills because ## of high ATC&C losses exacerbated by energy theft and ## consumers’ apathy to payments under the prevailing practice ## of estimated billing. Another major contributory factor to high ## ATC&C losses was the non-settlement of energy bills by MDAs ## across the three tiers of government (i.e., Federal, State and ## Local government). ## To address this existential liquidity challenges, DisCos must ## continue to improve on efforts toward reducing ATC&C losses ## by making necessary infrastructure investments, undertaking ## Nigerian Electricity Regulatory Commission * * * customer enumeration and mass metering. Governments across all tiers also need to take more responsibility for the timely settlement of their electricity bills. Regulations: Although no new regulation was issued in 2022, the Commission initiated the review of Mini-grid Regulation 20 through consultations and stakeholders’ engagements. The Commission also continued with monitoring compliance to the provisions of existing Regulations, Standards and other industry rules governing the NESI. Orders: The Commission issued thirty-nine (39) new orders in 2022; these are listed in Table 2.3 below: Table 2.3: Orders issued by the Commission in 2022 | S/N | Order No | Title of Order | Effective Date | | --- | --- | --- | --- | | 1 | NERC/307/2022 | Methodology for the determination of monthly energy caps for unmetered customers of successor distribution Licensees in the NESI | 1st July 2022 | | 2 | NERC/319/2022 | Securitisation of contracts and payment waterfall in the NESI | 1st July 2022 | | 3-15 | NERC/320-330,332/2022 | July 2022 Minor Review of the MYTO | 1st July 2022 | | 16-26 | NERC/316-318,319A-326A/2022 | Order on Performance Monitoring Framework | 1st October 2022 | | 27 | NERC/333/2022 | Securitisation of Gas Payments in the NESI | 1st July 2022 | | 28-38 | NERC/334-344/2022 | December 2022 Minor Review of MYTO for the DisCos | 1st December 2022 | • Renewal of four (4) generation licences with a total nameplate capacity of 2,290.00MW. • Two (2) new Independent Electricity Distribution Network • Two (2) new Independent Electricity Distribution Network (IEDN) Licence * * * In 2022, the Commission issued more than 140 licenses and permits. • Two (2) new Bulk Electricity Trading Licences. • Twenty-three (23) permits for Captive Power Generation • Twenty-three (23) permits for Captive Power Generation with a total capacity of 678.90MW. • Thirty-six (36) Meter Service Providers comprising nine (9) meter manufacturers, four (4) meter importers, twenty-two (22) meter installers and one (1) meter vendor. • Four (4) Meter Service Provider applications. • Four (4) Meter Service Provider applications. • Five (5) Eligible customer applications. • Forty-eight (48) Mini-grid permits and • Forty-eight (48) Mini-grid permits and 4 • Seventy (70) registration certificates . 4 • Seventy (70) registration certificates . violations, breaches and infractions of regulations, orders and technical codes of the NESI are key mandates of the technical codes of the NESI are key mandates of the Commission. In 2022, the Commission enforcement actions against some licensees for violations of rules and infractions. These include electric accidents and technical codes of the NESI are key mandates of the continued with enforcement actions against some licensees for violations of rules and infractions. These include electric accidents and rules and infractions. These include electric accidents and electrocution cases, and failure to comply with forum panel decisions without filing appeals within timeframe. within the stipulated timeframe. Pursuant to Section 42.3 of the market rules, the Commission has maintained a Dispute Resolution Panel (DRP) which is an Alternative Dispute Resolution (ADR) system of resolving disputes between market participants. In 2022, the DRP did not handle any case which continues a trend of limited utilisation of the DRP by market participants. In an attempt to correct this and in compliance with the Market Rules, the Commission appointed a new Dispute Resolution Councillor 4 Mini-Grid Permit means a permit granted by the Commission to an Isolated or Interconnected Mini-Grid developer, who applied, for the construction, operation and/or maintenance and where applicable ownership of a Mini-Grid. Registration means the submission to the Commission of a registration form as shown in Schedule 2 by a Mini-Grid developer for one or more system(s) of up to 100 kW of Distributed Power per site. * * * CONSUMER AFFAIRS (DRC) who has been tasked with developing a strategy to drive the uptake of the DRP by market participants. The Commission conducted town hall meetings with electricity consumers in Abuja, Benin, Eko, Ibadan, Kano, Katsina, Owerri, and Sokoto in 2022. Consumer Education and Enlightenment: To ensure continuous education of customers on their rights and obligations, as well as on other general service delivery matters in the industry, the Commission monitored all the customer enlightenment programs and activities of the DisCos in 2022 relative to their proposed plans for the year. On its part, the Commission conducted eight (8) town hall meetings with electricity consumers in Abuja, Benin, Eko, Ibadan, Kano, Katsina, Owerri, and Sokoto during the year. This is in addition to radio programs aired across twelve (12) states and the FCT to address key issues in the NESI through live discussions and pre-recordings. In the effort to educate the younger generation on the activities of the NESI, the Commission held the 2022 edition of the Annual Electricity Essay Competition for secondary school students across the country and winners were awarded prizes. In 2022, additional 589,997 enduse customer meters were installed. Metering: In 2022, additional 589,997 end-use customer meters were installed. This is significantly lower than the 836,702 meters installed in 2021 (-29.49%). The recorded decline in metering in 2022 was because of the winding down of the NMMP phase 0. As at 31 December 2022, only 5,134,871 out of the 12,152,106 registered end-use customers in the NESI (42.45%) were metered; as explained above, the resultant huge metering gap remains a key challenge for the financial sustainability of the NESI. The metering rate (percentage of metered customers) of the 11 DisCos is contained in Figure 2.3. The data indicates that between 2021 and 2022, eight (8) DisCos recorded increases in their metering rate with Abuja (15pp), Benin (13pp), and Ikeja (10pp) recording the most significant increases. Conversely, Kano DisCo recorded a decrease of -1pp in its metering rate. * * * As a safeguard against overbilling of unmetered customers, the Commission has set maximum limits to the amount of energy (in kWh) that may be estimated for an unmetered customer on a particular feeder, depending on the customer category and tariff band. The maximum limits are computed each month based on three-month data of actual consumption records of metered customers according to customer class and tariff band. The Commission continues to monitor the deployment of enduse energy meters for customers. It is also working with the CBN, World Bank and other relevant stakeholders on NMMP to accelerate the financial close and funds disbursement for the next round (Phase 1). Figure 2.3: Metering Status in NESI 2021 vs 2022 Metering, billing, and interruptions accounted for 74.03% of the total complaints received in 2022. Customer Complaints: In 2022, all the DisCos received 1,002,998 complaints from consumers, this is +5.78% more complaints than those received in 2021 (948,172). A review of the customer complaints data represented in Figure 2.4 indicates that metering, billing, and service interruption issues were the top categories of customer complaints, accounting for 74.03% (742,519) of the total complaints in 2022. * * * ## Executive Summary NERC Annual Report 2022 ## The DisCos collectively resolved 927,722 complaints ## representing 92.49% average resolution rate. With the ## exception of Enugu (89.05%), Ibadan, (83.53%), and Ikeja ## (86.04%), all other DisCos reported above 90% complaint ## resolution rate in 2022. Figure 2.4: Category of Complaints received by DisCos in 2022 **METERING** **INTERR TION** **2\. 0 %** **O T GE** **O DS EDDING** **I ING** **DISCONNECTION** **2\. %** **DE** **OT ERS** ## Forum Offices: Forum panels review unresolved disputes at ## DisCos’ Complaint Handling Units (DisCos-CCU) as enshrined ## in the Commission’s Customer Complaints andling Standards ## and Procedure Regulations. Figure 2.5 shows that in 2022, **Like complaints** **the Forum Offices had a total of 9,972 appeals (inclusive of** **categories of the 3,009 pending appeals carried over from 2021) from** **DisCos CCUs,** **metering and** **customers who were dissatisfied with DisCos’ decision on their** **billing complaints. Like the complaints received by the DisCos, billing** **dominated** **customers’** **(66.70%), metering (20.70%), and disconnection (5.51%)** **complaints at were the dominant issues in the categories of appeals at the** **Forum Offices.** **Forum Offices.** ## With concerted efforts on accelerating resolutions of ## increased complaints in 2022, the Forum panels held 274 ## sittings and 5,694 (57.10%) of the appeals were resolved ## either through hearings or preliminary engagements between ## Nigerian Electricity Regulatory Commission * * * ## Executive Summary NERC Annual Report 2022 **57.10% of the the Forum Secretaries and the concerned DisCos. This** **appeals that** ## represents a -8.62pp decrease in the resolution rate of **got to the** **Forum Offices 65.72% achieved in 2021. The Commission continues to** **in 2022 were** **monitor the operation and efficacy of its Forum Offices to** **resolved.** **ensure quick resolution of all outstanding and new appeals in** **line with the Forum Offices operating manual.** Figure 2.5: Appeals received at the Forum Offices in 2021 and 2022 **202 2022** **2,000** **0,000** **2** **,000** **,000** **2** **Number of ppeals,000** **00** **2,000** **0** **ppeals Received ppeals Resolved endings** ## Health and Safety: Compared to 2021, the number of safety ## accidents recorded in the NESI decreased from 176 to 173. ## The number of injuries increased from 61 to 93, however ## fatalities recorded decreased from 115 to 108. ## On account of the Commission’s zero-tolerance on safety ## breaches in the NESI, the Commission continues to intensify ## monitoring and implementation of various safety programmes ## aimed at reducing safety incidents. The programs being ## implemented include public enlightenment on the safe use of ## electricity, the standardisation of system protection schemes, ## review of operational procedures for Distribution System ## Operators (DSO) on fault clearing, and engagement of ## stakeholders on Right of Way (ROW) violations. ## Nigerian Electricity Regulatory Commission * * * Corporate Information NERC Annual Report 2021 # PART 3: CORPORATE ACTIVITIES OF THE # COMMISSION Nigerian Electricity Regulatory Commission * * * Corporate Information NERC Annual Report 2021 # 3.1 The Commission 3.2 Strategic Plan and Performance Monitoring # 3.3 Staff Composition 3.4 Capacity Development # 3.5 Promotions, Awards, and Retirement 3.6 Reporting Obligations Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## 3.1. The Commission ## 3.1.1. Background to the Creation of the Commission ## Prior to the year 2000, the Nigerian Electricity Supply Industry (NESI) faced ## several challenges inhibiting the efficient delivery of electricity to Nigerians. ## These included poor infrastructure, high technical and commercial losses, low ## power generation capacity, inadequate transmission and distribution facilities, ## non-cost reflective tariffs etc. ## This state of the industry led to the decision by the Federal Government to ## embark on power sector reforms in the NESI. The reforms aimed to liberate the ## power sector from the lingering problems and to attract private-sector ## investments. The Federal Government in March 2001 released the Nigerian ## Electric Power Policy (NEPP) which was subsequently adopted in 2002 and ## marked the beginning of the power sector reforms in Nigeria. ## A critical milestone in the transformation of the power sector reform 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 previous ## legislation on the power sector. The National Electric Power Authority (NEPA) ## 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. ## Section (31) of the EPSRA furthermore provided for the establishment of the ## Nigerian Electricity Regulatory Commission (NERC or the Commission). The **st** **Commission, which was officially inaugurated on the 31 of October 2005 with** **its headquarters in Abuja, serves as an independent regulatory body to drive** **the power sector reform by ensuring fairness, transparency and a level playing** **field for all stakeholders.** ## Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## Since its inception, the Commission has continued to position itself to give robust ## regulatory interventions as the power sector transits from a state-owned ## monopoly to a more competitive market structure. ## 3.1.2. Objects and Functions of the Commission ## The objects of the Commission as outlined under section 32 (1) of the EPSRA ## are the following; ## a) To create, promote, and preserve efficient 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 and; ## g) To present quarterly reports to the President and National Assembly on its **activities.** ## In furtherance to the objects highlighted above, the Commission performs the ## following functions outlined in Section 32 (2) of the EPSRA as follows: ## a) Promote competition and private sector participation, when and where **feasible;** ## Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## b) Establish or, as the case may be, approve appropriate operating codes ## and safety, security, reliability, and quality standards; ## c) Establish appropriate consumer rights and obligations regarding the ## provision and use of electricity services; ## d) License and regulate persons engaged in the generation, transmission, ## system operation, distribution, and trading of electricity; ## e) Approve amendments to the market rules; ## f) Monitor the operation of the electricity market; and ## g) Undertake such other activities, which are necessary or convenient for the ## better carrying out of or giving effect to the objects of the Commission. ## In the discharge of its functions, the Commission, in compliance with Section 32 ## (3), consults from time to time, and to the extent that it considers appropriate, **such persons or groups of persons who may or are likely to be affected by its** **decision or orders including but not limited to its licensees, consumers, potential** **investors, and other interested parties.** ## 3.1.3. Mission, Vision and Motto of the Commission ## Mission: Promote and ensure an investor-friendly industry and ## efficient market structure to meet the needs of Nigeria for ## safe, adequate, reliable, and affordable electricity ## Vision: Electricity on Demand ## Motto: Keeping the Lights on ## 3.1.4. Values of the Commission ## The Commission has four (4) guiding values: ## Leadership: Excellence, Transparency, Courage and Discipline; ## Nigerian Electricity Regulatory Commission * * * Professionalism: Proficiency, Diligence, Respect, Fairness and Accountability; Teamwork: Creating an environment of Loyalty, Trust, Collaboration, and Stakeholder Engagement; and Good Governance: Making decisions in a Fair, Transparent and Consistent manner, in compliance with the laws of Nigeria and our Regulations. 3.1.5. Structure of the Commission The Commission maintained the same organisational structure as in 2021. The structure seeks to allow an adequate flow of responsibility and authority along functional lines and staffing with professionally qualified personnel that have the requisite skills and experiences to carry out their functions appropriately. The current organisational structure of the Commission presented in Figure 3.1 consists of seven (7) Divisions. These are subdivided into twenty-five (25) Units, each tasked with unique roles and responsibilities that culminate into Divisional functions to drive the actualisation of the Commission’s goals. * * * Corporate Information Figure 3.1: Organisational structure of NERC as at December 2022 Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## i. Board of Commissioners: The Board has the overall responsibility for ## leadership. It directs the activities of the Commission in line with the ## provisions of the EPSRA. The Board performs quasi-judicial roles and ## conducts public hearings on matters of public interest in line with the **EPSRA.** ## ii. Chairman’s Office (CO): This Division is made up of four (4) units that ## provide overall governance and coordination of the activities of the ## Commission. The Units are the Secretariat, Public Affairs, Internal Audit, ## and Procurement. ## iii. Consumer Affairs (CA): This Division has the responsibility of leading the ## development of consumer regulations and ensuring that operators meet ## the minimum service standards provided in the regulations. It is also ## responsible for consumer enlightenment programmes and ensuring the ## speedy resolution of customer complaints by DisCos. In addition, it is ## responsible for the effective management of the Commission’s Forum ## Offices across the Country. ## iv. Engineering and Performance Monitoring (EPM): This Division is ## responsible for developing technical standards and monitoring ## compliance with technical codes & standards by industry operators. In ## addition, it is responsible for the technical evaluation of all license ## applications submitted to the Commission. ## v. Finance and Management Services (FMS): This Division provides support ## services to the Commission in critical areas that include finance and ## accounts, asset administration, human capital development, and ## information technology. ## Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## vi. Legal, Licensing and Compliance (LLC): This Division is responsible for ## coordinating and evaluating license applications before the Commission. ## It provides legal support and advisory services to the Commission, ## oversees the quasi-judicial functions of the Commission (hearings and ## dispute resolutions in the NESI), and the enforcement of Commission’s ## Orders and decisions. ## vii. Market Competition and Rates (MCR): This Division is responsible for ## reviewing tariff applications from licensees and conducting analyses of ## market performance. It monitors the electricity market to prevent abuse ## of market power and conducts commercial evaluations of licence ## applications. It is also responsible for the analyses and review of the ## financial reporting of all licensees in the NESI. ## viii. Planning, Research and Strategy (PRS): This Division is responsible for ## collating and analysing industry data to help the Commission make ## informed decisions. It is also responsible for the overall strategy ## development of the Commission and monitors the emerging trends in the ## electricity industry — this is with a view to advising the Commission on ## updates that may be required to the regulatory regime to help deliver ## on its objects as contained in the EPSRA. Furthermore, the Division ## coordinates the renewable energy activities of the Commission and is ## responsible for the preparation of the periodic NESI operational ## performance reports issued by the Commission. ## 3.2. Strategic Plan and Performance Monitoring System ## The Commission utilises strategic plans to convert its high-level objectives into ## specific tasks and deliverables which are geared towards the creation of the ## regulatory environment required to actualise the reforms needed at various ## Nigerian Electricity Regulatory Commission * * * stages of the evolution of the NESI as provided in the EPSRA 2004. The Performance monitoring system of the Commission gives vital information about current processes, how these processes are helping to achieve the strategic goals and suggests ways to achieve the goals more effectively. The 2021–2023 strategic plan is intended to drive continued growth and consolidate the Commission’s oversight functions in the NESI. Specifically, the plan provides for the realisation of the under-listed ten (10) critical goals: I. Creation of a financially viable electricity market; II. Metering for all customers; III. Effective compliance monitoring & enforcement; IV. Institutionalise code of corporate governance; VI. Sustained growth in availability & quality of supply; VII. Enhancement of the nation’s security of supply for electricity; VIII. Promotion of local content and manpower development in NESI; IX. Enforcement of safety standards; X. Review and enforcement of standards for customer care. These goals have been crafted to align with the overall objects of the Commission as outlined in Section (32) of the EPSRA, while also being consistent with the overarching policy directives issued by the Federal Government of Nigeria in line with Section (33) of the EPSRA. * * * Table 3.1: Summary of Progress on the Commission’s Strategic Plan in 2022 | S/N | Goal | Action Item | Status | | --- | --- | --- | --- | | 1. | Creation of a financially viable electricity market | Review of TCN Performance Improvement Plan(PIP) | Ongoing | | Regulatory Open Book Review(Regulatory Audit of Procurement Practices, Collection, Disbursement & Utilisation of Market funds by Licensees) | Completed | | | | Implementation of MYTO-2022 and Periodic Minor Review of MYTO | Completed | | | | Valuation of TCN,NDPHC and State Government Assets | Ongoing | | | | Review of USoA Framework | Ongoing | | | | Validation of customer enumeration exercise(geotagging to distribution assets, load profile,etc) | Ongoing | | | | Monitoring of the disbursement and utilisation of funding for Discos and TCN PIP | Completed | | | | Technical and Operational Audit of Market Operation and System Operations | Ongoing | | | | The establishment of Power Consumer Assistance Fund(PCAF) | Ongoing | | | | Review of Security Challenges and the resultant Revenue losses in the NESI Monitoring of World Bank/PSRO performance indicator for compliance with Disbursement Linked Indicator(DLI) | Completed | | | | | Implementation of Regulatory net offs and monitoring of credit notes | Completed | | | 2. | Metering of all customers within three years | Review of the guidelines for meter decommissioning procedures | Completed | | Partnership with NAPTIN for training and certification of meter installers | Ongoing | | | | Accreditation of test laboratories to carry out certification of meters to speed up meter deployment | Ongoing | | | | Monitoring and evaluation of meter deployment by DisCos | Completed | | | | | | Review of order on Prohibition of Bulk Metering & Introduction of CCA vis-à-vis Franchising guidelines | Ongoing | | 3. | Effective Performance Monitoring, Compliance and Enforcement | Development of a detailed compliance and enforcement strategy | Completed | | 4. | Institutionalise Corporate Governance | Issuance of Code of Corporate Governance for the NESI | Ongoing | | Issuance of order on Procurement in the NESI | Ongoing | | | | Facilitation of the Separation of ISO from TSP (TCN) | Completed | | | | 5. | Recapitalisation of Licensees in the sector | Determination of Capital Adequacy for DisCos | Completed | | 6. | Sustained growth in availability and quality of supply | Monitoring of the Implementation of DisCos PIPs | Ongoing | | Review of 2021 Proposed CAPEX by TCN | Ongoing | | | | Evaluation and alignment of investments required by TCN and DisCos at all TCN/DisCo interface points. | Completed | | | | NESI Assets(Feeders) Nomenclature | Completed | | | | Development of Ramp up trajectories for generation and supply | Ongoing | | | | 7. | Enhancement of the Nation's security supply for electricity | Development of regulatory guidance and recommended policy support for the realisation of clean coal-to-power generation, on-grid renewables, large hydros, small hydros and other alternative sources. | Completed | | Contract activation and securitisation of payment in the NESI | Completed | | | | | | Review of Mini Grid Regulations, 2016 | Ongoing | | 8. | Promotion of local content and manpower development in the NESI | Monitoring Compliance with Local Contents Regulations in NESI | On hold | | 9. | Enforcement of safety standards | Order on compensation for safety breach arising from licensees' negligence | Ongoing | | Develop a framework to ensure effective enforcement of Safety Code issued to licensees | Completed | | | | Review of Protective Schemes standards at 11kV and 33kV levels | Ongoing | | | | Review of operational procedures for Distribution System Operators | Ongoing | | | | Work with NAPTIN for the certification of Distribution and Transmission System Operators (TSO) and Safety Professionals in NESI | Completed | | | | Partnership with NEMSA to revise design and standards for construction/installations at the distribution level | Ongoing | | | | 10. | Review and Enforcement of standards for customer care | Establishment of a contact call centre for prompt response to customer needs and close monitoring of DisCos' customer complaints handling process | Ongoing | | Review of Customer Protection Regulations | Ongoing | | | | Review of the roles of the Forum in customer complaint/resolution in order to make Forum Offices more effective | Completed | | | * * * 3.3. Staff Composition The total manpower of the Commission in 2022 was one hundred and fortythree (143) consisting of Seven (7) commissioners, thirty-five (35) management staff, eighty (80) mid-management staff and twenty-one (21) junior staff. 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 distribution of staff by division, cadre, gender, position, age and geopolitical zone is detailed in the sections below: 3.3.1. Distribution by Division The distribution of staff across the different Divisions in the year is presented in Table 3.2. The Finance & Management Services Division had the highest number of staff; forty-three (43), while the PRS Division had eight (8) staff during the year. Table 3.2: Distribution of the Commission’s Staff by Divisions in 2022 | S/N | Divisions | Number of staff | Percentage Share | | --- | --- | --- | --- | | 1 | Chairman's office | 16 | 11.76% | | 2 | Consumer Affairs(including Forum Offices) | 40 | 29.41% | | 3 | Engineering, Performance&Monitoring | 10 | 7.35% | | 4 | Finance&ManagementServices(IncludingJuniorStaff) | 43 | 31.62% | | 5 | Legal Licensing&Compliance | 10 | 7.35% | | 6 | Market,Competition&Rates | 9 | 6.62% | | 7 | Planning,Research&Strategy | 8 | 5.88% | | | Total | 136 | 100.00% | 3.3.2. Distribution by Cadre Notes: 1. The staff distribution excludes the seven Commissioners and their seven aides. * * * eighty (80) mid-management staff, and twenty-one (21) lower level & junior staff representing 25.74%, 58.82% and 15.44% respectively of the total Commission’s staff. Table 3.3: Distribution of the Commission’s Staff by Cadre in 2022 | S/N | Position | Number of Staff | Cadre | Number of staff | Percentage share | | --- | --- | --- | --- | --- | --- | | 1 | General Manager | 6 | Mgt. Cadre | 35 | 25.74% | | 2 | Deputy General Manager | 5 | | | | | 3 | Assistant General Manager | 24 | | | | | 4 | Principal Manager | 23 | Senior Cadre | 71 | 52.21% | | 5 | Senior Manager | 22 | | | | | 6 | Manager | 26 | | | | | 7 | Assistant Manager | 6 | Middle Cadre | 30 | 22.05% | | 8 | Analyst I | 3 | | | | | 9 | Analyst II | 0 | | | | | 10 | Analyst III | 0 | | | | | 11 | Junior Staff | 21 | Junior Cadre | | | | | Total | 136 | All Cadre | 136 | 100.00% | Notes: The staff distribution excludes the seven Commissioners and their Aides 3.3.3. Distribution by Gender The distribution of staff by gender as at December 2022 illustrated in Figure 3.2 shows that approximately 26.47% of the professional workforce of the Commission were female in furtherance of the Commission’s commitment to gender balance. Figure 3.3 presents the gender distribution of staff of the Commission in 2022 for each Cadre. The representation of females in the cadre ranges from 15.38% (Manager cadre) to 100% (Analyst cadre). This further buttress the fact that the Commission acknowledges the key role women play in the power sector and is committed to increasing their participation. * * * Figure 3.2: Distribution of the Commission’s Staff by Gender in 2022 Figure 3.3: Distribution of the Commission’s Staff by Cadre & Gender in 2022 3.3.4. Distribution by age The age distribution of staff shown in Figure 3.4 indicates that the Commission has only one (1) staff below the age of thirty-five (35) and 88.97% of the staff are 40 years and above. Based on the 60 years mandatory retirement age for public servants, eighteen (18) staff are set to retire within the next 5 years and * * * ## Corporate Information NERC Annual Report 2022 ## another thirty-six (36) staff are to retire within 10 years. The Commission ## acknowledges the importance of succession planning and has developed a ## succession strategy. In line with this, the Commission initiated a recruitment ## process during the year to employ suitably qualified Nigerians to join its **workforce.** **Figure 3.4: Staff Distribution by Age as at 31st December 2022** **0 years** **0** ## 3.4. Capacity Development ## The Commission places a high premium on capacity development of its staff as ## it recognises that the quality of personnel impacts significantly on the quality of ## its operations and activities. The Commission continued the implementation of ## its capacity-building strategy by providing trainings to staff based on skill gaps ## which included soft skills, regulatory, management and leadership trainings. ## Staff were also sponsored to attend workshops, conferences, and meetings on ## issues pertinent to the discharge of the Commission’s functions. ## In addition, the Commission also organised a number of in-house virtual training ## and workshops for staff development. Members of staff of the Commission were ## Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## sponsored to attend annual conferences of their respective professional bodies ## among which included the Chartered Institute of Personnel Management of ## Nigeria (CIPM), Nigerian Institute of Public Relations (NIPR), Nigerian Institute ## of Management (NIM), Institute of Chartered Accountants of Nigeria (ICAN), ## Association of National Accountants of Nigeria (ANAN), Nigerian Society of ## Engineers (NSE) and the Nigerian Bar Association (NBA). ## 3.5. Promotion, Awards and Retirement ## Consistent with its policy to conduct regular and transparent promotion ## exercises for eligible staff, the Commission undertook performance appraisal ## for all staff and conducted the promotion exercise for all eligible staff. At the ## end of the exercise, members of staff who were adjudged to have satisfied the ## stipulated requirements were duly promoted. ## The Commission held an award ceremony to recognise staff who had exhibited ## excellence in the delivery of their duties as well as long-service awards to ## relevant staff. Eight (8) members of staff exited the Commission in 2022. ## 3.6. Reporting Obligations ## 3.6.1. Quarterly Reports ## Pursuant to Section 55(3) of the EPSRA which states that - “the Commission shall ## present quarterly reports on all its activities to the President and the National ## Assembly”, the Commission has published its four (4) quarterly reports for ## 2022\. The reports contain analyses of the state of the Nigerian electricity ## industry (covering both the operational and commercial indices), regulatory ## functions, consumer affairs, the Commission’s finances, and staff development ## during a given quarter. ## Nigerian Electricity Regulatory Commission * * * ## Corporate Information NERC Annual Report 2022 ## 3.6.2. Financial Reports ## The Commission’s financial statement for the year ended st December 2022 ## was prepared in compliance with Section 55(1) of the EPSRA, which 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”. ## Furthermore, in compliance with Section 56(1)-(3) of the EPSRA mandating the ## auditing of the Commission’s account within six (6) months after the end of each ## financial year, PricewaterhouseCoopers (PwC) was swiftly engaged to audit the ## account of the Commission for the 2022 financial year. ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 # PART 4: STATE OF THE NIGERIAN ELECTRICITY # SUPPLY INDUSTRY ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 # 4.1 Operational Performance 4.2 Grid Performance # 4.3 Commercial Performance ## Nigerian Electricity Regulatory Commission * * * 4.1. Operational Performance The Nigerian Electricity Regulatory Commission (NERC) in line with the mandate derived from the Electric Power Sector Reform Act (EPSRA) monitors the technical and operational performance of the Nigerian Electricity Supply Industry (NESI). This is to ensure that the Commission’s decision-making process is data-driven leading to the implementation of interventions that seek to optimise service delivery to customers. 4.1.1. Electricity Generation In 2022, the average daily available generation capacity of all grid-connected plants was 4,526.83MW. The average daily available capacity decreased by 727.20MW (-13.84%) from 5,254.03MW in 2021 to 4,526.83MW in 2022. Figure 4.1 summarises the average daily available capacity in 2021 and 2022. The available generation capacity in 2022 was notably lower than in 2021, except in the month of April. In 2022, generation capacity fell below 4,500MW (the lowest point in 2021) during the following four months: May, June, September, and October. Between April and June 2022, the four (4) hydro power plants; Kainji, Jebba, Shiroro and Dadin Kowa also experienced decreases in available capacity due to low water head and water management. This was due to seasonal variations occasioned by the commencement of the rainy season in Nigeria. * * * Figure 4.1: Average Daily Available Capacity in 2021 and 2022 Figure 4.2 presents a summary of the average daily electricity generation for each month in 2021 and 2022. On the 12th February 2022, the national grid recorded its highest average hourly generation of 4,598.05MWh/h. The average daily energy generated in 2022 declined by 209MWh/h (- 4.98%) from 4,197MWh/h in 2021 to 3,988MWh/h. This can be attributed * * * ## State of the Industry NERC Annual Report 2022 ## to the reduction in available capacity in 2022 compared to 2021 although it is ## noteworthy that the scale in reduction of generation was significantly lower than ## reduction in available generation, caused by increased utilisation of available ## capacity. Creating an incentive for the relevant licensees to work towards the ## complete resolution of the technical and operational challenges in the NESI ## remains a top priority of the Commission. ## As explained in each of the 2022 quarterly reports, the lack of liquidity and ## payment assurance for upstream players especially Gas suppliers has been a ## major contributory factor to the decline in available generation. Liquidity ## challenges also lead to delays or total lack of routine maintenance of machines ## which cause unscheduled outages. ## Since 2020, as part of the efforts to improve payment assurance to upstream ## players in the sector, the Commission in partnership with the Central Bank of ## Nigeria (CBN) has implemented an escrow arrangement which provides ## visibility into the collection performance of the DisCos with payments being ## made on their behalf to the upstream players. ## The Commission continued the execution of several actionable items identified ## in its Strategic Plan 2021-2023 to resolve the technical and operational ## challenges in the NESI. Pursuant to this, the Commission finalised the review ## and communicated its decisions on the Performance Improvement Plans (PIP) **1** **filed by the DisCos to ensure the execution of projects critical to improving** **their operational and technical performances. The PIPs review focused on the:** I. **Utilisation of capital and operating expenditure allowances for** **relevance and cost-efficiency.** **1** **The PIPs cover the period 2021-2025 and prepared with the guidelines provided by the Commission** **with an overall objective to ensure that utilities invest in projects critical to addressing the technical and** **operational constraints affecting their operational efficiency.** ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 II. **Investments required to address distribution network bottlenecks and free** **up part of the unutilised generation capacities and address other related** **constraints inhibiting the flow of energy.** ## 4.1.2. Load Factor and Average Generation of Power Plants ## The Load Factor is a measure of the utilisation of a power plant's capacity, ## calculated as the ratio of the average electricity generated to the maximum ## possible generation over the period, based on the available capacity. A higher ## load factor results in better capacity utilisation, 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 reflects both demand for energy ## and a plant's ability to supply it. The formula for Load Factor is represented by ## equation 4.1: **Tota Ener y enerated ( h)** **Load actor = ( . )** **era e ai a e Ca acity (**)× hrs× eriod (in days) ## The average load factor across all grid-connected power plants in 2022 was ## 86.05%, indicating that 13.95% of available capacity was not utilised. The ## load factor in 2022 (86.05%) represents an increase of 10.03pp from the ## 76.02% recorded in 2021. The increase in load factor during the year despite ## a decrease in total energy generated relative to 2021 indicates there was an ## improvement in load offtake by DisCos. Figure 4.3. shows the load factors of ## the seven (7) top performing power plants in 2021 and 2022. ## Nigerian Electricity Regulatory Commission * * * Figure 4.3: Average Plant Load Factor (%) in 2021 and 2022 Eleven (11) power-plants had over 90% of energy generated being evacuated by the TSP in 2022 with Omoku (99.03%), Jebba (98.44%), and Kainji (98.09%), being the best performers in this metric. The hydro plants had an average dispatch rate of 96.02%; Jebba (98.44%), Kainji (98.09%), Dadin Kowa (97.93%), and Shiroro (89.63%). The dispatch rate of these hydro plants complies with the Commission’s rder NERC/182/2019, declaring hydro ower ants as “must-run” y the S . This is to ensure that the hydro plants are efficiently dispatched given their low tariffs. Relative to 2021, all power plants with the exception of Ibom (-16.05pp) recorded improvements in load factor, with Jebba having the highest increase (+13.48pp). * * * generated. Egbin accounted for the highest share of 10.87% (15.04% share of energy generated in 2021), followed by Azura which accounted for 9.89% (8.85% share of energy generated in 2021) energy share. Delta GS, Kainji, Shiroro and Jebba were other top contributors to energy generated in 2022. Conversely, Dadin Kowa, being the grid connected plant with the lowest capacity (40MW), accounted for the lowest share of output contributing 0.67% of the total energy generated within the year. Figure 4.4: Average Share (%) of Generation Output by Plants in 2022 The share of generation output contained in Figure 4.4 indicates NESI overreliance on some power plants. The Commission has commenced the phased activation of contracted capacity effective 1st July 2022 to promote incremental growth in generation availability and utilisation of other plants especially those that have significant installed capacities that have not been utilised in prior years. * * * 4.1.4. Generation Mix The electricity generation mix refers to the combination of fuels used to generate electricity over a period of time. 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 variations. An ideal energy mix must balance the three key objectives of the energy trilemma: energy affordability, environmental sustainability, and energy security. The formula for electricity generation by fuel sources is given by equation 4.2: \\boxed{\\begin array}{rarray{l}{\ }}&\\{{}&{\\mathsf{S h a r e ~~o f~~ f u e l\_= ~~}\\frac{\\mathsf{T o l l~~}\\mathsf{E l e c t i c l y ~~}\\mathsf{G e n e r a t e d~~}\\mathsf{f r o m ~~F}e l l,(\\mathsf{N W h})}{\\mathsf{T o t a l~~}\\mathsf{E l e c t i i l y ~~}\\mathsf{G e n e r o t e d~~}\\mathsf{f r o m ~~a l l~~}\\mathsf{F u e l ~~}\\mathsf{S o u r c e s~~}(\\mathsf{M W h})}}\\end{array} ( . ) The share of electricity generation by energy sources for 2021 and 2022 is presented in Figure 4.5. The share of electricity generated from hydropower plants in 2022 was 26.70% representing an increase of 3.88pp from 22.82% in 2021. The country’s current ener y mix means that seasona ariation in water volume and security of gas supply both constitute high-risk factors for electricity supply. While both hydro and thermal (gas) plants being used on the grid are relatively clean sources from an emissions perspective, the Commission remains committed to monitoring the generation mix in furtherance of the o ernment’s c imate chan e miti ation commitments. * * * ## State of the Industry NERC Annual Report 2022 **Figure 4.5: Share of Electricity Generated by Energy Sources** **ydro Therma** **( )** **Share o E ectricity enerated** ## 4.1.5. Grid Performance ## The Transmission Company of Nigeria (TCN) which has the responsibility of ## wheeling energy from power plants to DisCos holds two licensees; 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 and load dispatch. To assess the performance of ## the grid, the Commission focuses on four (4) key performance indicators (KPI) ## that relate to power transmission. These are; - **Transmission loss factor** - **Stability of grid frequency** - **Voltage fluctuation** - **Incidence of system collapse** ## 4.1.5.1. Transmission Loss Factor ## Transmission Loss Factor (TLF) refers to the proportion of energy lost during the ## transmission of power from GenCos to the DisCos. The TLF has an inverse ## relationship with system efficiency which means that a decline in the TLF ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 ## indicates an improvement in transmission efficiency. The formula for TLF is ## represented by equation 4.3: **Ener y de i ered to a isCos + Ener y Ex orted** **TL = (** −) **× ( . )** **Ener y Sent out y a enCos** ## As illustrated in Figure 4.6, the average TLF in 2022 was 7.87%; a 7.87% TLF ## implies that for every 100 MWh of energy injected into the grid from the ## generation stations in 2022, 7.87MWh of the energy was dissipated in transit ## as transmission loss and utilised to power the transmission substations. This is ## 0.37pp higher than the allowed Multi-Year Tariff Order (MYTO) reference loss ## factor of 7.50% which became effective in January 2022. ## Since TLF is supposed to cover efficient losses for which customers are meant to ## pay, the Commission has an obligation to review TLF targets to reflect the ## maturity in the NESI taking into account investments made by the TSP. In view ## o considera e im ro ements recorded in TCN’s o erationa e iciency with an ## average TLF of 7.68% and 7.29% in 2019 and 2020 respectively, as against ## the 8.05% TLF provided in transmission tariff since 2012, the Commission ## reviewed the efficiency target for TCN in 2021 and set TLF reduction trajectory ## for the next five (5) years to encourage the TCN towards better operational ## efficiency as shown in Table 4.1 **Table 4.1: TLF Improvement Trajectory 2022 - 2026** ## Year 2022 2023 2024 2025 2026 ## Regulated Loss 7.50% 7.25% 7.00% 6.75% 6.50% ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 **Figure 4.6: Transmission Loss Factor in 2021 and 2022** **ctua Transmission Loss actor ( ) T TL Tar et ( )** **.** **.** **..** **..** **.** **.** **( )..** **.** **.** \\*\\* ... \*\* **..** **.** **..** **.** **..** **Transmission Loss actor** **era e TL . era e TL .** **onths** ## 4.1.5.2. Grid Frequency ## Frequency is a major power quality parameter that consumers (especially ## industrial customers) are concerned about because of the sensitivity of their ## machines to frequency fluctuation. Most industrial production assembly lines ## have machines that are frequency sensitive and would not operate outside the ## pre-set frequency tolerance limits. As specified in the Grid Code, the system ## frequency under normal circumstances is expected to be between a lower limit ## of 49.75Hz and an upper limit of 50.25Hz (allowance of +/- 0.5%) but may ## reach an upper bound stress limit of 51.25Hz and a lower bound stress limit of ## 48.75Hz in extreme circumstances (allowance of +/- 2.5%). ## A summary of the system frequency performance in 2021 and 2022 is ## presented in Figure 4.7. The average highest and lowest daily system frequency ## readings in 2022 were 50.72Hz and 48.99Hz with a range of 1.73Hz. ## Comparatively, in 2021, the average highest and lowest daily system ## frequency readings were 50.71Hz and 49.30Hz with a range of 1.41Hz. ## Based on this, it can be deduced that the grid operated with more stability in ## Nigerian Electricity Regulatory Commission * * * 2021 than 2022 - the lower the deviation from the specified range, the better the frequency performance. In 2022, the upper and lower bounds of the system frequency were all outside the normal operation limits but within the stress limits except in July and August (when the lower bounds exceeded the limits). It is clear that the SO struggled more with managing the lower bound frequency of the system which is an indication that demand often outstripped supply. This is consistent with the reduction in available generation which was experienced in 2022 (discussed earlier). The S ’s ac o systems to rant it real-time visibility of the network e.g., Supervisory Control and Data Acquisition (SCADA) is a major causal factor leading to poor frequency management in the NESI. Figure 4.7: Average System Frequency (Hz) in 2021 and 2022 To guarantee high-quality power, the Grid Code specifies a nominal system voltage of 330kV with a tolerance range of +/- 5% (313.5kV to 346.5kV). Fluctuations in grid voltage, including spikes, dips, flickers, brownouts, and blackouts, can cause significant harm to consumers and result in substantial 4.1.5.3. Voltage Fluctuation commercial losses. Extreme cases of voltage fluctuations, particularly at the distribution network level, can cause severe damage to industrial machines thereby compelling industrial customers to seek alternative sources of power generation. The system voltage performance for 2021 and 2022 is shown in Figure 4.8. The average upper and lower operating voltage bounds for the network in 2022 were 352.74kV and 298.97kV respectively with a range of 53.77kV. Both values are outside the respective specified limits which indicates that the voltage performance in 2022 did not meet the expected levels. Comparatively, in 2021, the average upper and lower operating voltage bounds for the network were 351.61kV and 297.87kV respectively with a range of 53.74kV. Figure 4.8: System Voltage (kV) in 2021 and 2022 The lower range in 2021 indicates that overall system voltage performance in 2021 was better than 2022. This is consistent with the findings on system frequency performance as discussed above and highlights the importance of renewed efforts by the SO/TSP to improve the overall technical performance of the NESI. * * * ## State of the Industry NERC Annual Report 2022 ## 4.1.5.4. System Collapse ## The national power grid, a network of electrical transmission lines connecting ## generating stations to loads over the entire country, is designed to operate ## within certain stability limits in terms of voltage (330kV±5%) 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. This can ## range from a partial collapse of a section of the grid to a full system-wide **blackout.** ## The SO is responsible for ensuring that the frequency remains within a ±0.5% ## tolerance threshold. When there is a significant deviation between demand and ## supply on the grid, this can cause grid parameters to move outside of their ## stability ranges indicated above thereby creating the risk of a collapse. This ## usually occurs when demand is greater than supply, thereby causing the grid ## frequency to drop outside safe operational range which causes the most ## sensitive plants to shut down automatically. These shutdowns further exacerbate ## the frequency imbalance and can lead to a full or partial system collapse. On ## the other hand, if supply surpasses demand, the frequency increases, and in ## severe cases, some power plants may shut down, causing a sudden drop in **generation.** ## The frequency trend throughout the year 2022 showed that the grid was ## operating close to extreme stress frequencies, making it susceptible to ## significant disruptions. Table 4.2 shows the total grid incidents from 2018 to ## 2022; the total number of grid incidents increased from four (4) in 2021 to six ## (6) in 2022. ## Nigerian Electricity Regulatory Commission * * * Table 4.2: Total and Partial System Collapses | | Years | | | | | | --- | --- | --- | --- | --- | --- | | Category | 2018 | 2019 | 2020 | 2021 | 2022 | | Number of Partial Collapses | 1 | 1 | 0 | 2 | 2 | | Number of Total Collapses | 12 | 10 | 4 | 2 | 4 | The year 2022 marked the first year of the last 5 in which the system recorded an increase in collapses. The Commission has intensified efforts to compel TCN to deliver improvements in grid stability and prevent recurrent system collapses. Further to this, the Commission has also continued the strict monitoring of enCos’ com iance with the S ’s directi es to enerators on ree o ernor and frequency control mode in line with the provisions of the subsisting operating codes in the industry. Over the course of the year, the Commission called for meetings between TCN and DisCos focused on the enforcement of under frequency load-shedding scheme instituted to provide an added layer of security for the grid in case of a sudden loss of generation. Furthermore, the Commission gave directives to TCN to undertake a review of the calibration of relay settings across the network to improve the grid stability. 4.2. Commercial Performance • Energy offtake performance The commercial performance of the NESI is a measure of the flow of funds from customers to upstream electricity industry players. The financial performance is critical because funds are required to keep all the players along the value chain operational. In evaluating the commercial performance of the NESI in 2022, the following parameters have been considered: • Energy billed and billing efficiency • Revenue and collection efficiency * * * ## State of the Industry NERC Annual Report 2022 - **Aggregate Technical, Commercial and Collection (ATC&C) loss** - **Remittances to the Market Operator (MO) and the Nigerian Bulk** **Electricity Trading Company (NBET).** ## 4.2.1. Energy offtake performance ## The amount of energy received by DisCos at their trading points in 2022 was ## 28,351.62GWh, a decrease of 2,142.48GWh (-7.03%) from the ## 30,494.10GWh recorded in 2021. This decrease is partly attributable to the ## 4.98% decrease in the total energy generated and the increase in TLF ## (+0.43pp) in 2022 relative to 2021. Shortfall not attributable to either of these ## 2 factors was caused by increased energy offtake by bilateral customers (local ## and/or international) connected to the grid. **st** **For the 1 half of the year, the share of available generation on the national** **grid that was allocated to each DisCo was based on the share of the energy** **contracted with NBET as contained in the vesting contracts signed upon** **privatisation in 2013. The allocation under the framework for each DisCo is** **referred to as the Multi-Year Tariff Order (MYTO) load allocation. Effective July** **1, 2022, the NESI transitioned into the Partial Activation of Contract (PAC)** **regime which enabled the DisCos to determine their unconstrained power** **requirements in absolute MW known as their Partially Contracted Capacity** **(PCC) that replaced the MYTO load allocation.** ## The PAC 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** **practices in power procurement contracts and it increases the predictability of** **revenue flows for the GenCos, thus allowing for critical routine maintenance** **activities to improve the availability of their plants.** ## Nigerian Electricity Regulatory Commission * * * ## State of the Industry NERC Annual Report 2022 ## The PAC regime reinforces the DisCos capacity payment scheme which took ## effect on 1st January 2020 and acts as a deterrent against discretionary non- ## offtake of load. To further improve contract discipline along the upstream ## segment of the NESI, the PAC regime provided for Liquidated Damages (LD) **to be paid by GenCos or TCN to the DisCos in situations where the DisCo does** **not receive the contracted capacity due to challenges at the generation and/or** **transmission sub-segments. In July 2022, updated Service Level Agreements** **(SLA) were signed between DisCos and TCN to further institutionalise the** **com ensation mechanism or isCos when TCN’s imitations re ent them rom** **getting their contracted energy.** **Each isCo’s oad o ta e er ormance ( s. MYTO allocation – H1 2022) and** **(vs. PCC – H2 2022) is presented in Table 4.3. Relative to H1 2022, there** **were increases both in available generation (partly attributable to the** **introduction of the PCC) as well as energy offtake by the DisCos. The isCos’** **offtake performance increased in H2 (-1.47%) relative to H1 (-13.03%). This** **improvement can be partly attributed to the introduction of the PAC regime** **which put a penalty against DisCos when they do not offtake their pro-rated** **PCC.** ## In H1 2022, only Abuja DisCo (0.43%) recorded positive variance on its load ## offtake compared to its MYTO allocations. In H2 2022, five (5) DisCos ## recorded positive variance in their offtake compared to the PCC (i.e., the DisCo ## took more energy than their allocation) with Eko (12.11%) and Abuja ## (11.78%), recording the most significant positive variances. The Commission ## has approved Performance Improvement Plans (PIPs) for DisCos and has set up ## a monitoring process to review the implementation of the constituent projects. ## Nigerian Electricity Regulatory Commission * * * Table 4.3: Energy Offtake Performance in 2022 | DisCos | Jan-Jun 2022 | | | Jul-Dec 2022 | | | | --- | --- | --- | --- | --- | --- | --- | | Offtake(MWh/h) | MYTO share(MWh/h) | Variance(%) | Offtake(MWh/h) | PCC(MWh/h) | Variance(%) | | | Abuja | 417.30 | 415.34 | 0.43 | 474.18 | 424.22 | 11.78 | | Benin | 305.37 | 325.05 | -6.05 | 310.51 | 328.02 | -5.34 | | Eko | 334.35 | 397.28 | -15.84 | 378.85 | 337.94 | 12.11 | | Enugu | 310.07 | 325.05 | -4.61 | 286.46 | 320.67 | -10.67 | | Ibadan | 385.90 | 469.51 | -17.81 | 401.72 | 400.43 | 0.32 | | Ikeja | 445.98 | 541.74 | -17.68 | 485.63 | 481.78 | 0.80 | | Jos | 167.51 | 198.64 | -15.67 | 189.85 | 244.01 | -22.20 | | Kaduna | 246.09 | 288.93 | -14.83 | 235.73 | 228.74 | 3.06 | | Kano | 209.00 | 288.93 | -27.66 | 229.81 | 235.66 | -2.48 | | Port Harcourt | 218.95 | 234.76 | -6.73 | 242.90 | 249.51 | -2.65 | | Yola | 100.75 | 126.41 | -20.30 | 94.69 | 128.93 | -26.56 | | All DisCos | 3,141.09 | 3,611.63 | -13.03 | 3,330.33 | 3,379.91 | -1.47 | As explained in the quarterly reports, inadequate gas supply continues to be a major challenge for the NESI as it limits available generation. In an effort to address this problem, the Commission also introduced the Gas Supply Stabilisation Fund (GSSF) in July 2022 to provide payment assurance to gas suppliers and increase the quantity of gas supplied to the GenCos. The GSSF is a revolving fund (seed funding was obtained from legacy FGN debt obligations to the DisCos) which is used to settle gas invoices at source i.e., the Gas Aggregation Company of Nigeria (GACN) compiles and sends all gas-topower invoices to NBET for payment at source. Once NBET receives the market remittance for the next month, the GSSF is refunded wholly with the balance being used to settle the GenCo invoices2. 2 The amount paid to the GSSF is netted-o the enCo’s in oice to N ET. * * * ## State of the Industry NERC Annual Report 2022 ## 4.2.2. Energy Billed and Billing Efficiency ## Billing efficiency is the ratio of the proportion of energy that has been billed ## (both billing-post-paid customers and vending-prepaid customers) to customers ## in comparison to the total energy supplied to an area within a given period. ## The formula for billing efficiency is represented by equation 4.4: **Tota nits i ed ( h)** **i in E iciency ( ) = × ( . )** **Tota Ener y ecei ed y the Networ ( h)** ## The amount of energy received, billed and billing efficiency by DisCos in 2021 ## and 2022 are presented in Table 4.4. Out of the 28,351.62GWh total energy ## received by all DisCos in 2022, 21,770.79GWh was billed to the end-users, ## resulting in a billing efficiency of 76.79%. This is a 0.22pp increase from the ## billing efficiency in 2021 (76.57%). Billing Efficiency covers the technical and ## commercial loss components in the Aggregate, Technical, Commercial and ## Collection (ATC&C) loss. This implies that there was very marginal improvement ## (0.22pp) in technical and commercial loss that was recorded in 2022 (23.21%) ## relative to 2021 (23.43%). Some of the major factors that contribute to billing ## losses include: - **Poor customer enumeration: this is the inability of DisCos to identify all** **electricity consumers** - **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.** - **Energy theft: this is the deliberate action by some electricity consumers** **to consume electricity without making payments** - **Technical loss: this is the energy loss to wires and transformers (technical** **losses) which a so contri utes to isCos’ i in inefficiency and this is** ## Nigerian Electricity Regulatory Commission * * * particularly relevant for areas of the network with substandard or aged infrastructure. The billing efficiency performance of all DisCos contained in Table 4.4 shows that Eko and Ikeja had the highest billing efficiencies with 89.15% and 88.51% respectively for 2022. Conversely, Yola recorded the lowest billing efficiency of 56.79%, indicating that Yola DisCo lost 43.21% of the energy received to technical and commercial inefficiencies in 2022. In addition to those factors identified as causes of low billing efficiency in the industry, the state of insecurity within the franchise areas of Yola DisCo has contributed to the low operational performance of the utility. Table 4.4: Energy Received and Billed by DisCos for 2021 and 2022 | | Total Energy Received(GWh) | | Total Energy Billed(GWh) | | Billing Efficiency(%) | | | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2021 | 2022 | 2021 | 2022 | 2021 | 2022 | | Abuja | 4,050 | 3,906 | 2,682 | 2,677 | 66.22 | 68.54 | | Benin | 2,683 | 2,698 | 2,246 | 2,274 | 83.73 | 84.29 | | Eko | 3,591 | 3,125 | 3,141 | 2,786 | 87.47 | 89.15 | | Enugu | 2,841 | 2,612 | 2,035 | 1,852 | 71.62 | 70.90 | | Ibadan | 4,092 | 3,450 | 2,920 | 2,567 | 71.37 | 74.41 | | Ikeja | 4,548 | 4,082 | 4,081 | 3,613 | 89.73 | 88.51 | | Jos | 1,403 | 1,566 | 976 | 1,181 | 69.57 | 75.40 | | Kaduna | 2,324 | 2,110 | 1,767 | 1,349 | 76.03 | 63.95 | | Kano | 1,951 | 1,923 | 1,454 | 1,346 | 74.52 | 69.99 | | Port Harcourt | 2,109 | 2,024 | 1,625 | 1,639 | 77.06 | 81.00 | | Yola | 901 | 856 | 420 | 486 | 46.56 | 56.79 | | All DisCos | 30,494 | 28,352 | 23,348 | 21,771 | 76.57 | 76.79 | In 2022, relative to 2021, all DisCos with the exception of Kaduna, Kano, Ikeja and Enugu recorded an improvement in their billing efficiency. The highest increase was recorded by Yola and Jos DisCos with +10.23pp and +5.83pp respectively. Kaduna DisCo recorded the most significant loss of -12.08pp in billing efficiency (76.03% in 2021 compared to 63.95% in 2022). * * * ## State of the Industry NERC Annual Report 2022 ## The Commission continues to engage DisCos on regulatory interventions ## required to address some of the factors dri in isCos’ i in ine iciency. A **ey e ement or reducin i in osses is the isCos’ asset ma in and ta in** **the customer enumeration process. This is designed to identify illegal consumers** **and enrol them on the isCos’ i in at orms.** ## In its effort to improve isCos’ technica and commercia e iciency, the ## Commission has finalised the review of the 2021–2025 Performance ## Improvement Plans (PIP) filed by DisCos. The PIPs are developed based on the ## Commission’s directi e or isCos to su mit I s containin ro osed ## investments that are targeted towards critical infrastructure to free up stranded ## capacity and improve service delivery to customers. ## 4.2.3. 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. For various reasons, ## many customers continue to default in payment of their billed amounts resulting ## in collection losses. The formula for collection efficiency is represented by ## equation 4.5: **e enue Co ected** **Co ection E iciency ( ) = × ( . )** **i ed mount** ## The total revenue collected by the DisCos from customers in 2022 was ₦841.81 ## billion out of the total bill of ₦1,185.31 billion to customers, leaving an ## outstanding balance of ₦343.50 billion. This translates to a collection efficiency ## of 71.02% which implies that for every ₦100.00 worth of energy billed to ## customers by DisCos in 2022, approximately ₦28.98 was not recovered from ## customers. The low collection efficiency combined with billing inefficiency has ## Nigerian Electricity Regulatory Commission * * * continued to adversely impact the financial liquidity of the industry, ultimately limiting the NESI’s a i ity to row and attract in estment. In 2022, only Ikeja had a collection efficiency above 90% which can be partly attributable to the fact that it leads the DisCos in terms of overall metering rate (58.82%) as at the end of 2022. This was followed by Eko and Abuja DisCos with collection efficiencies of 84.45% and 82.87% respectively while Kaduna DisCo had the lowest collection efficiency of 39.25%. As shown in Table 4.5 the overall collection efficiency for all DisCos in 2022 was 71.02% representing an increment of 1.60pp from 69.42% reported in 2021\. On the DisCo-by-DisCo level, Ikeja, Kaduna, Ibadan, Port Harcourt, Benin, Yola and Eko DisCos recorded improvements in collection efficiency between 2021 and 2022 with Ikeja having the highest increase of +6.83pp (85.44% in 2021 vs 92.27% in 2022). Conversely, four (4) DisCos recorded reductions in their collection efficiency performance in 2022 relative to 2021 with Jos DisCo having the most significant reduction of -8.13pp (50.29% in 2021 vs 42.15% in 2022). Table 4.5: Revenue Performance of DisCos in 2021 and 2022 | DisCos | Total Billings(#’Million) | | Revenue Collected(#’Million) | | Collection Efficiency(%) | | | --- | --- | --- | --- | --- | --- | --- | | 2021 | 2022 | 2021 | 2022 | 2021 | 2022 | | | Abuja | 140,633 | 154,221 | 117,612 | 127,804 | 83.63 | 82.87 | | Benin | 105,773 | 122,073 | 58,159 | 69,903 | 54.98 | 57.26 | | Eko | 145,614 | 151,312 | 120,886 | 127,788 | 83.02 | 84.45 | | Enugu | 98,004 | 101,343 | 69,826 | 70,927 | 71.25 | 69.99 | | Ibadan | 139,714 | 137,330 | 91,365 | 95,675 | 65.39 | 69.67 | | Ikeja | 184,220 | 182,418 | 157,399 | 168,309 | 85.44 | 92.27 | | Jos | 49,318 | 73,592 | 24,800 | 31,013 | 50.29 | 42.15 | | Kaduna | 89,769 | 71,978 | 30,643 | 28,249 | 34.14 | 39.25 | | Kano | 69,170 | 73,791 | 47,388 | 48,906 | 68.51 | 66.28 | | Port Harcourt | 76,234 | 90,344 | 47,718 | 58,775 | 62.59 | 65.06 | | Yola | 18,474 | 26,930 | 9,539 | 14,463 | 51.63 | 53.71 | | All DisCos | 1,116,923 | 1,185,312 | 775,336 | 841,811 | 69.42 | 71.02 | * * * ## State of the Industry NERC Annual Report 2022 ## 4.2.4. Aggregate Technical, Commercial and Collection (ATC&C) Loss ## The Aggregate Technical, Commercial and Collection (ATC&C) loss is a ## summation of billing losses incurred by the DisCo due to its inability to bill 100% ## of delivered energy to consumers (technical and commercial losses) and the ## collection losses arising from the isCo’s ina i ity to co ect o the ## invoices issued out to consumers. The ATC&C loss is a critical performance ## parameter for tariff determination because it represents the efficient losses ## which the DisCos are allowed to recover from customers. The tariff orders ## issued to DisCos make allowance for specific ATC&C loss level targets for each ## DisCo. Just as the case of TLF explained earlier, 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 ATC&C loss comprises the following components: ## a. Technical Loss: heat loss due to load flow in electrical lines and ## transformation loss in transformers. ## b. Commercial Loss: due to discrepancy in meter reading, erroneous billing, ## unmetered consumption, or energy theft; ## c. Collection Loss: unpaid bills. ## The formula for ATC&C loss is represented by equation 4.6: **TC&C Loss = \[** − ( i in E iciency × Co ection E iciency)\] **× ( . )** ## The average ATC&C loss for all the DisCos in 2022 was 45.46% comprising ## 23.21% technical and commercial losses, and 28.98% 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. Non-payment of bills by Federal/State ## Nigerian Electricity Regulatory Commission * * * Ministries, Departments and Agencies (MDA) also continue to contribute to the ATC&C loss incurred by DisCos. To avoid a moral hazard that may hinder regulatory action on underperforming DisCos, it is critical for the government across all tiers to pay their bills fully and in a timely manner. Table 4.6: ATC&C Loss of DisCos in 2021 and 2022 | DisCos | MYTO Targets | Average ATC&C Loss | | | --- | --- | --- | --- | | 2022 | 2021 | 2022 | | | Abuja | 19.27% | 44.62% | 43.20% | | Benin | 17.37% | 53.96% | 51.73% | | Eko | 14.18% | 27.38% | 24.71% | | Enugu | 11.31% | 48.97% | 50.38% | | Ibadan | 15.47% | 53.33% | 48.16% | | Ikeja | 11.37% | 23.34% | 18.33% | | Jos | 27.27% | 65.02% | 68.22% | | Kaduna | 10.65% | 74.05% | 74.90% | | Kano | 15.85% | 48.94% | 53.61% | | Port Harcourt | 21.45% | 51.76% | 47.30% | | Yola | 64.12% | 75.96% | 69.50% | | Overall MYTO Level | 20.75% | | | | Aggregate technical, commercial & collection Loss | - | 46.85% | 45.46% | | Technical & Commercial Losses | - | 23.43% | 23.21% | | Collection Losses | - | 30.58% | 28.98% | The overall ATC&C loss of 45.46% in 2022 was substantially higher than the expected allowable ATC&C loss (20.75%) provided in the MYTO applicable in 2022. In absolute terms, Ikeja maintained its record of having the lowest ATC&C in the market (18.33%) for the fifth consecutive year. Conversely, Kaduna was the worst performing DisCo with an ATC&C of 74.90% in 2022, this means that for every ₦100.00 worth of energy delivered to the DisCo in 2022, it only collected ₦25.09 in revenue from customers. * * * ## State of the Industry NERC Annual Report 2022 ## variances relative to their allowed MYTO targets for the year with -64.25pp ## (74.90% vs a target of 10.65%), -40.95pp (68.22% vs a target of 27.27%), ## and -39.07pp (50.38% vs a target of 11.31%) respectively. ## As shown in Table 4.6 the ATC&C loss improved in 2022 by 1.39pp from the ## ATC&C loss of 46.85% reported in 2021. The reduction in ATC&C loss is due ## to the combined decrease in both technical & commercial, as well as in ## collection loss which decreased by 0.22pp and 1.60pp respectively, in 2022 ## relative to 2021. ## At the micro (DisCo) level, seven (7) DisCos recorded improvements ## (reductions) in their ATC&C performance between 2021 and 2022 with the ## biggest improvements being achieved at Yola, Ibadan and Ikeja which reduced ## their ATC&C losses by 6.46pp, 5.17pp and 5.00pp respectively. Conversely, ## four (4) DisCos; Kano (+4.67pp), Jos (+3.20pp), Enugu (+1.41pp) and ## Kaduna (+0.86pp) recorded increases in ATC&C loss between 2021 and **2022.** ## As highlighted earlier, none of the eleven (11) DisCos had an actual ATC&C **loss that was less than or equal to the target contained in their tariff orders for** **2022\. The inability of the DisCos to meet their allowed loss targets means they** **are unable to meet revenue requirements thereby compromising their long-term** **financial position.** ## 4.2.5. Market Remittance ## In the absence of cost-reflective tariffs, the Government commits to cover the ## resultant gap (difference between the cost-reflective and allowed tariff) in the **form of tariff shortfall subsidy – this is applied to the NBET invoices that are to** **be paid by DisCos. The Commission is saddled with the responsibility of** **determinin each isCo’s inimum emittance i ation ( ) ased on its** **allowed tariff – the MRO is contained in the periodic Tariff Orders issued by** ## Nigerian Electricity Regulatory Commission * * * the Commission. For ease of administration of the subsidy, the MRO is only applied on the NBET invoice – the MRO represents the share (in percentage) of an NBET invoice for which the DisCo is expected to make payments. DisCos are required to pay 100% of the invoice issued to them by the MO. The implementation of the MRO sought to end the discretionary remittance by DisCos, ensure transparency and equity in the disbursement of market funds for the benefit of all participants in the industry and ultimately address the liquidity crisis facing the industry3. The applicable MRO (%) for each DisCo to NBET and MO in 2022 is contained in Table 4.7. Table 4.7: Minimum Remittance Obligation to NBET & MO by DisCos in 2022 | DisCos | Minimum Remittance Obligation(NBET) | Minimum Remittance Obligation(MO) | Remittance Obligation(NBET&MO) | | --- | --- | --- | --- | | Abuja | 90.04% | 100% | 91.59% | | Benin | 83.53% | 100% | 86.35% | | Eko | 85.88% | 100% | 88.26% | | Enugu | 88.98% | 100% | 90.88% | | Ibadan | 80.52% | 100% | 83.87% | | Ikeja | 85.57% | 100% | 87.87% | | Jos | 63.08% | 100% | 69.61% | | Kaduna | 82.76% | 100% | 85.34% | | Kano | 82.46% | 100% | 85.30% | | Port Harcourt | 81.00% | 100% | 84.15% | | Yola | 10.50% | 100% | 23.00% | | All DisCos | 81.32% | 100% | 84.38% | An MRO adjusted invoice of ₦816.25 billion was issued by NBET and MO for energy costs and administrative services to DisCos in 2022. The DisCos remitted a total of ₦632.25 billion, resulting in a deficit of ₦184.00 billion during the year – this under ayment is nown as “mar et short a ”. The remittance performance by DisCos to the market (NBET and MO) in 2021 and 2022 is detailed in Figure 4.9. The overall remittance performance increased by 3 Specifically, low remittance in the industry adversely affects the ability of NBET to honour its financial obligations to GenCos while service providers (i.e., TSP, SO, MO, NBET and NERC) struggle with paucity of funds which adversely impact on their ability to optimally discharge their functions. * * * State of the Industry 6.11pp from 71.35% in 2021 to 77.46% in 2022. Between 2021 and 2022, all DisCos except Port Harcourt, Jos and Kano recorded improvements in their remittance performances with Yola recording the highest increase of +58.80pp. Figure 4.9: Remittance Performance by DisCos in 2021 and 2022 Figure 4.9: Remittance Performance by DisCos in 2021 and 2022 com arati e ana ysis o isCos’ mar et in oice and remittance er ormance in 2022 is presented in Figure 4.10. Only 3 DisCos namely Ikeja, Eko, and Yola recorded remittance performances above 90% (99.76%, 97.67% and 93.51% respectively). Kaduna DisCo recorded the lowest remittance rate of com arati e ana ysis o isCos’ mar et in oice and remittance er ormance in 2022 is presented in Figure 4.10. Only 3 DisCos namely Ikeja, Eko, and Yola recorded remittance performances above 90% (99.76%, 97.67% and 93.51% respectively). Kaduna DisCo recorded the lowest remittance rate of 93.51% respectively). Kaduna DisCo recorded the lowest remittance rate of 22.07% in 2022 due to its significant ATC&C losses, as mentioned previously. * * * Figure 4.10: isCos’ emittance er ormance to N ET and in The isCos’ disa re ated remittances to N ET and are summarised in Table 4.8. The overall remittance performance by all DisCos to NBET for energy costs in 2022 was 78.08% which translates an increase of 8.68pp compared to 69.40% performance in 2021. Only Ikeja and Eko DisCos had remittance rates above 90% (102.04% and 99.81% respectively). On the other end of the spectrum, Kaduna DisCo recorded the lowest remittance performance to NBET in 2022 (20.21%). The largest improvement in remittance to NBET was recorded by Yola with an increase of +46.79pp (2022 - 86.46% vs. 2021 - 39.67%). The DisCos had an overall remittance performance of 74.89% to the MO in 2022\. Yola (98.08%) is the only DisCo with remittance above 90% to the MO in 2022. Conversely, 2 DisCos recorded MO remittance rates below 60%; Kaduna (30.81%) and Kano (58.09%). The biggest improvement in remittance was recorded by Yola where its 2022 remittance rate (98.08%) represents a +70.44pp increase compared to 2021 (27.64%). * * * Table 4.8: Annual Remittance Performance to NBET and MO | DisCos | NBET(№’Billion) | | | | MO(№’Billion) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Invoice | Remit. | Performance | | Invoice | Remit. | Performance | | | | 2022 | 2022 | 2022 | 2021 | 2022 | 2022 | 2022 | 2021 | | | Abuja | 98.69 | 83.07 | 84.17% | 73.33% | 20.27 | 17.46 | 86.16% | 108.48% | | Benin | 62.56 | 46.64 | 74.55% | 67.02% | 15.44 | 10.39 | 67.13% | 75.32% | | Eko | 72.50 | 72.37 | 99.81% | 92.40% | 17.14 | 15.12 | 88.59% | 97.82% | | Enugu | 66.75 | 51.08 | 76.53% | 67.37% | 15.59 | 10.02 | 64.30% | 78.60% | | Ibadan | 80.89 | 64.18 | 79.35% | 61.66% | 20.87 | 18.54 | 88.82% | 73.17% | | Ikeja | 100.89 | 102.95 | 102.04% | 91.63% | 22.30 | 19.95 | 89.45% | 73.10% | | Jos | 28.74 | 21.05 | 73.25% | 69.70% | 9.79 | 6.27 | 64.10% | 74.76% | | Kaduna | 50.02 | 10.11 | 20.21% | 17.56% | 10.63 | 3.28 | 30.81% | 31.65% | | Kano | 47.49 | 27.72 | 58.37% | 56.46% | 11.12 | 6.46 | 58.09% | 66.28% | | Port Harcourt | 46.39 | 31.96 | 68.88% | 69.30% | 11.36 | 7.23 | 63.59% | 77.43% | | Yola | 2.68 | 2.31 | 86.46% | 39.67% | 4.14 | 4.06 | 98.08% | 27.64% | | All DisCos | 657.60 | 513.43 | 78.08% | 69.40% | 158.65 | 118.82 | 74.89% | 76.64% | | Special Customer:(‘Million） | | | | | | | | | | Ajaokuta Steel(№) | 1,394.20 | 0.00 | 0.00% | 0.00% | 271.25 | 0.00 | 0.00% | 0.00% | 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. 2. Remittances above 100% are due to payment of outstanding invoices. 3. Remittances above 100% are due to payment of outstanding invoices. It is clear from the remittance figures above that the upstream market liquidity challenges reported in 2021 persisted in 2022. With the payment assurance waterfall in place, DisCos inability to remit also confirms that they were unable to earn their entire revenue requirement, this will have prevented them from having the funds to undertake necessary operational/capital investments. Therefore, the imperative is on DisCos to implement solutions geared towards reducing their ATC&C loss to the levels approved in their respective tariffs. This will allow them earn revenue to meet their market obligations, cover operational costs and provide return on investment for their shareholders. * * * ## State of the Industry NERC Annual Report 2022 ## No payment was made by the special customers (Ajaokuta Steel Co. Ltd and ## the host community) in respect of the ₦1.39 billion and ₦0.27 billion energy ## invoices and service charges received from NBET and MO respectively. The **st** **total debt obligation of Ajaokuta to NBET and the MO as at 31 December** **4** **2022 stands at ₦22.98 billion and ₦2.08 billion respectively.** ## The issue of Ajaokuta has been a pressing one for the Commission and ## engagements have been held with the responsible federal ministries to find a ## lasting solution to the non-payment of its electricity bills. Failure to settle the ## obligations may put the Ajaokuta complex at the risk of being disconnected by ## its service providers (NBET and MO) on the grounds of gross indebtedness. ## The remittance performance of international and bilateral customers to MO in ## 2022 are contained in Table 4.9. The international customers (i.e., Societe ## Ni erienne d’e ectricite – NI ELEC, Societe eninoise d’Ener ie E ectri ue – ## SBEE and Compagnie Energie Electrique du Togo – CEET) received a total ## invoice of $52.72 million from the MO and made a total payment of $50.68 ## million corresponding to a remittance performance of 96.13%. The 2022 ## remittance performance translates to a 61.41pp increase from 34.72% ## remittance performance to the MO that was recorded in 2021. The bilateral ## customers received a total invoice of ₦5,791.85 million from MO and made a ## payment of ₦5,516.76 million corresponding to a remittance performance of **95.25%.** ## The Commission has requested the MO to ensure that all International ## Customers are registered as market participants in line with the market rules ## and particularly, enforce the provision that allows the use of security deposit to ## settle unpaid market invoices. The MO has an obligation to enforce all payment **4** **This comprises of outstanding invoice of ₦8.62 billion and accrued interest of ₦14.36 billion as at** **December 2022** ## Nigerian Electricity Regulatory Commission * * * securitisation mechanisms provided in the agreements for the different international transactions to improve payment discipline going forward. Table 4.9: International & Bilateral Customers Invoices & Remittances in 2022 | | Invoice(Million) | Remittance(Million) | Performance(%) | | --- | --- | --- | --- | | International Customers | | | | | PARAS-SBEE($) | 9.91 | 9.56 | 96.59 | | TRANSCORP/SBEE($) | 10.46 | 10.46 | 100.00 | | MAINSTREAM/NIGELEC($) | 23.17 | 22.83 | 98.53 | | ODUKPANI/CEET($) | 9.18 | 7.81 | 85.14 | | Total | 52.72 | 50.68 | 96.13 | | Bilateral Customers | | | | | EKO EGBIN(N) | 0.00 | 0.00 | - | | EKO PARAS(N) | 0.00 | 0.00 | - | | IKEJA EGBIN(N) | 0.00 | 0.00 | - | | MAINSTREAM/INNER GALAXY(N) | | | | | MAINSTREAM/KAM INDUSTRIES(N) | | | | | MAINSTREAM/CROWN FLOOR MILLS(N) | | | | | MAINSTREAM/LORD'S MINT(N) | | | | | MAINSTREAM/KAM INTEGRATED(N) | 3,580.94 | 3,647.92 | 101.7 | | MAINSTREM/PRISM(N) | | | | | KAM STEEL SHAGAMU(N) | | | | | MAINSTREAM/ADEFOLORUNSHOVENTURE(N) | | | | | NDPHC/SUNFLAG(N) | 0.00 | 0.00 | - | | NDPHC/WEEWOOD(N) | 0.00 | 0.00 | - | | TRANSCORP/PREMIUM STEEL(N) | 0.00 | 0.00 | - | | NORTH SOUTH/STAR PIPE(N) | 75.38 | 75.38 | 100.00 | | TRANS-AMADI/OAU(N) | 99.09 | 99.10 | 100.01 | | OMOTOSHO 11/EKOEDC(N) | 1,214.91 | 1,214.91 | 100.00 | | OMOTOSHO 11/PULKIT(N) | 9.18 | 7.81 | 85.14 | | APLE(N) | 760.70 | 420.00 | 55.21 | | TAOPEX/KAM STEEL SHAGAMU(N) | 51.61 | 51.61 | 100.00 | | Total | 5,791.85 | 5,516.76 | 95.25 | * * * ## Regulatory Functions NERC Annual Report 2022 # PART 5: REGULATORY FUNCTIONS ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 # 5.1 Regulations, Orders and Guidelines 5.2 Licensing and Permits # 5.3 Captive Power Generation Permits 5.4 Certification of Meter Asset/Service Providers # 5.5 Eligible Customer Authorisation 5.6 Mini-grid Registrations # 5.7 Public Consultation and Awareness 5.8 Compliance Monitoring and Enforcement # 5.9 Litigation and Alternative Dispute Resolution ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## 5.1. Regulations, Orders and Guidelines ## 5.1.1. Regulations ## The Commission issues regulations to optimise the performance of licensees and ## achieve the goals of the Electric Power Sector Reform Act (EPSRA) 2004. In ## 2022, no new regulations were issued by the Commission. The Commission ## however commenced the amendment process for the review of the Mini-grid ## Regulations, 2016. A consultation paper was released to the public in ## September 2022 for a period of 21 days. This was followed by a series of ## stakeholder consultation and engagement workshops. The workshops and ## meetings provided a platform and opportunity for robust stakeholder ## engagement and input on proposed amendments to the Regulation. ## The Commission also continued with the monitoring of compliance based on the ## provisions in the existing Regulations, Standards and other industry rules ## governing the NESI. ## 5.1.2. Orders ## The Commission issued thirty-nine (39) new Orders in 2022. The highlights of ## these Orders are summarised below: 1. **NERC/307/2022 –Methodology for the determination of monthly energy** **caps for unmetered customers of successor distribution Licensees in the** **NESI: This Order is dated 30th June 2022 and became effective 1st July** ## 2022\. The objective of the Order is to adopt a more dynamic methodology ## for the determination of monthly energy caps in the interest of end-use ## customers and DisCos. The new methodology will compute monthly energy ## caps to reflect the availability of supply to end-use customers within a ## DisCo’s network over the preceding three (3) months. ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 2. **NERC/319/2022 – Securitisation of contracts and payment waterfall in the** **NESI: This Order is dated 11th May 2022 and became effective 1st July** ## 2022\. The objectives of this Order are to; - **Provide visibility and certainty of market payments to market participants** **and gas suppliers, thereby ensuring certainty and stability in generation.** - **Enforce the fulfilment of financial obligations between contracting parties** **to boost liquidity and investment in the NESI, and** - **Secure the commitment for gas supply.** ## The Order is intended to address the constraints to gas supply, ## transportation contracts and the challenges surrounding securitisation of ## payments across the NESI value chain. ## 3-13. NERC/316–318, 319A–326A/2022 – Order on Performance ## Monitoring Framework: ## This Order was issued by the Commission on September 29, 2022, and ## became effective on October 1, 2022. The Order sets specific Key ## Performance Indicators (KPIs) for the DisCos to ensure market discipline, ## operational efficiency required to improve reliability, quality of service, ## long-term performance improvement and sector sustainability. The ## objectives of the Order are to: - **Ensure that DisCos maintain market discipline and operate in compliance** **with industry targets.** - **Ensure improved reliability and quality of supply in accordance with** **DisCos’ commitment in the Performance Improvement Plan (PIP).** - **Lay the foundation for long term sustainability of DisCos.** - **Hold the Board and management of DisCos accountable for meeting** **operational targets specified in the Order.** ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## 14-26.NERC/320–330, 332/2022 – July 2022 Minor Review of the Multi- ## year Tariff Order 2022 issued to the 11 DisCos and TCN: The objectives ## of the Tariff Orders which took effect from July 1, 2022, are to; - **Reflect the impact of changes in the projected Minor Review Variables** **for the period January to June 2022 for the determination of Cost** **Reflective Tariffs (CRT).** - **Ensure sustained improvement in reliability and supply in line with DisCos** **CAPEX proposal and PIP commitment.** - **Ensure that tariffs payable by customers are commensurate and aligned** **with the quality and availability of power supply committed to customer** **clusters by DisCos, and** - **Steer the market to gradual transitioning to CRT and activation of market** **contracts in line with power sector reform objectives.** ## 27\. NERC/333/2022 – Securitisation of Gas Payments in the Nigerian ## Electricity Supply Industry (NESI): The objectives of the Tariff Order ## which took effect from 1st July 2022 are; - **The provision of payment assurance for the supply and transportation of** **gas to generators under PPAs with the NBET.** - **Ensure adequacy and reliability in the supply of gas to generators.** - **Provide visibility and payment certainty to market participants and gas** **suppliers.** ## The Gas Supply Stabilisation Fund (GSSF) was introduced to provide ## assurance to gas suppliers and increase the quantity of gas supplied to the ## GenCos. The GSSF is a revolving fund (seed funding was obtained from ## legacy FGN debt obligations to the DisCos) which is used to settle gas ## invoices at source i.e., the Gas Aggregation Company of Nigeria (GACN) ## compiles and sends all gas-to-power invoices to NBET for payment at source. ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## Once NBET receives the market remittance for the next month, the GSSF is ## refunded wholly with the balance being used to settle the GenCo invoices. ## Note that the amount paid to the GSSF is netted off the GenCo’s invoice to **NBET.** ## 28-38. NERC/334–344/2022 – December 2022 Minor Review of Multi-Year ## Tariff Order- 2022: The objectives of the Tariff Order which took effect ## from 1st December 2022 are to; - **Reflect the impact of changes in the projected Minor Review Variables** **for the period January to December 2022 for the determination of Cost** **Reflective Tariffs.** - **Ensure sustained improvement in reliability and supply in line with** **DisCos’ CAPEX proposal and PIP commitment.** - **Ensure that tariffs payable by customers are commensurate and aligned** **with the quality and availability of power supply committed to customer** **clusters by DisCos, and** - **Sustain the improved contracting framework heralded by the partial** **activation of Generation Company contracts in July 2022, steer the** **market to gradually transition to CRT and move the market towards** **direct bilateral contracting between DisCos and GenCos in line with** **power sector reform objectives.** ## 39\. NERC/348/2022 – December 2022 Minor Tariff Review of Multi-Year ## Tariff Order (MYTO) 2022 for the TCN: The objectives of the Tariff ## Order which took effect from 1st January 2023 are to; - **Provide appropriate incentives towards ensuring continuous improvement** **in TCN’s performance in reducing network losses.** ## Nigerian Electricity Regulatory Commission * * * • Apply the impact of changes in the projected Minor Review Variables for the period January to June 2022 for the determination of Cost-Reflective Tariffs (CRT). • Reaffirm the interim payment arrangements and flow of funds from DisCos to the Market Operator. • Steer the market to gradually transition into CRT and activate market contracts in line with the requirements of the Transitional Electricity Market (TEM). • Reaffirm the obligation of the System Operator (SO) Division of the TCN to comply with the EMOD prescribed in this Order towards ensuring compliance with the projected least generation cost prescribed in this Order. • Reaffirm the obligation of the Transmission System Provider (TSP) under the TCN for the payment of “generation capacity charge” and “loss revenue” to DisCos based on the deviation between energy delivered to a DisCo and the MYTO allocation arising from the TCN’s inability to deliver power to the affected DisCo. • Reaffirm the obligation of DisCos for the payment of “loss of revenue” in favour of the TCN in line with the provisions of the executed Service Level Agreement. 5.2.1. Generation, Trading and Distribution Licenses 5.1.3. Guidelines The Commission did not issue any Guideline in 2022. * * * generation, trading and distribution licences to qualified applicants in 2022. The details of on-grid, off-grid and embedded generation licences issued by the Commission in 2022 are provided in Table 5.1. The Commission issued a total of twenty-five (25) new and approved the renewal of four (4) licences with a total nameplate capacity of 2,290.00MW. The Commission also approved the transfer of two (2) generation license. In addition, the Commission approved the amendment of two (2) on-grid generation licences from Ibom Power Company Limited and Omotosho Generation Company Limited. The amendments allowed the plants to sell their energy to third-party consumers other than NBET. Table 5.1: Summary of New Licences Granted in 2022 | S/N | Category | | New issue | | Renewal | | | --- | --- | --- | --- | --- | --- | --- | | | | Count | Capacity(MW) | Count | Capacity(MW) | | | 1. | On-grid Licence | 1 | 50.00 | 3 | 2,270.00 | | | 2. | Off-grid Licence | 15 | 45.29 | 1 | 20.00 | | | 3. | Embedded Generation | 4 | 46.50 | - | - | | | 4. | Independent Electricity Distribution Network(“IEDN”)Licence | 2 | N/A | - | - | | | 5. | Bulk Electricity Trading Licence | 2 | N/A | - | - | | | 6. | License amendment | 1 | 561.00 | - | - | | | 8. | Licence Transfer | - | - | 2 | 400.00 | | | | Total | 25 | 702.79 | 6 | 2,690.00 | | Furthermore, the Commission also approved the issuance of two (2) trading licences to Commercio Electricity Exchange Limited and Ecof Nigeria Limited. It is noteworthy that these are the first private electricity trading licensees within the NESI. This is pursuant to the Commission’s commitment to transition the market into a bilateral one with little to no Government intervention along the value chain in compliance with the provisions of the EPSRA 2004. With such licences, both companies may, subject to specific approval from the * * * Commission, undertake generation aggregation and sale to eligible customers or the DisCos. 5.2.2. Captive Generation Permits Captive power plants are energy-generating plants owned and maintained by the generating entity for its own consumption and not for sale to a third party. In 2022, the Commission granted twelve (12) new captive power generation permits and approved the renewal of eleven (11) permits with a total nameplate capacity of 160.98MW and 517.92MW respectively. Details of the captive generation permits approved in 2022 are presented in Table 5.2. Table 5.2: Captive Generation Plants Approved in 2022 | S/N | Company Name | Location/State | Capacity(MW) | | --- | --- | --- | --- | | | New Approvals | | | | 1 | African Natural Resources&Mines Limited | Abuja | 50.00 | | 2 | Duport Midstream Company Limited | Edo State | 2.00 | | 3 | Julius Berger Company Limited | Abuja | 6.00 | | 4 | Niger Mills Limited | Cross River | 8.80 | | 5 | Mikano International Limited | Lagos State | 22.90 | | 6 | Premier Polypack Limited | Lagos State | 3.48 | | 7 | Cadbury Nigeria Limited | Lagos State | 5.80 | | 8 | Ariel Foods FZE | Lagos State | 5.60 | | 9 | Aspira Nigeria Limited | Kano State | 4.00 | | 10 | BUA International Limited | Kwara State | 15.00 | | 11 | Honeywell Flour Mills | Lagos State | 26.60 | | 12 | Honeywell Flour Mills | Ogun State | 10.80 | | | Renewals | | | | 13 | Nigeria LNG Limited | Abuja | 360.00 | | 14 | Speciality Pulp and Paper Limited | Ogun State | 3.50 | | 15 | The Shell Petroleum Company Nigeria Limited | Bayelsa State | 50.00 | * * * | Regulatory Functions | | NERC Annual Report 2022 | | | --- | --- | --- | --- | | 16 | The Shell Petroleum Company Nigeria Limited | Bayelsa State | 6.00 | | 17 | The Shell Petroleum Company Nigeria Limited | Bayelsa State | 2.00 | | 18 | The Shell Petroleum Development Company of Nigeria Limited | Bayelsa State | 3.98 | | 19 | The Shell Petroleum Development Company of Nigeria Limited | Bayelsa State | 15.86 | | 20 | The Shell Petroleum Development Company of Nigeria Limited | Bayelsa State | 4.29 | | 21 | The Shell Petroleum Development Company of Nigeria Limited | Bayelsa State | 4.29 | | 22 | Mobil Producing Nigeria Limited | Akwa Ibom State | 18.00 | | 23 | Greenvile Oil and Gas Limited | Rivers State | 50.00 | 5.2.3. Certification of Meter Asset Providers/Metering Service Providers A Metering Service Provider (MSP) is an entity that is certified by the Commission as a manufacturer, supplier, vendor, or installer of electric energy meters and/or metering systems. A Meter Asset Provider (MAP) is an entity to which the Commission has issued a permit to provide metering services, including meter financing, procurement, supply, installation, maintenance, and replacement. In 2022, the Commission issued 4 permits to MAP applicants and certified 36 MSPs. A summary of the MSP certificates approved by the Commission in 2022 is presented in Table 5.3. The full list of companies issued with MAP permits and MSP certificates in 2022 is presented in Table D.4 of the Appendix. Table 5.3: Category of Meter Service Providers Certified in 2022 | S/N | Meter Service Providers Category | Quantity | | --- | --- | --- | | 1. | Meter Manufacturer | 9 | | 2. | Meter Importers | 4 | | 3. | Meter Installers | 22 | | 4. | Meter Vendor | 1 | | | Total | 36 | * * * 5.2.4. Eligible Customer Authorisations The Eligible Customer Regulations set a framework for electricity generation companies and Independent Power Producers (IPP) to sell electricity bilaterally to "Eligible Customers" while leveraging the national grid system (transmission network and sometimes distribution). Eligible Customers must have an average consumption of not less than 2MWh/h, and the regulation provides a framework for the owners of electricity transportation infrastructure to be compensated through “Use of System” charges. 2M W h/h In 2022, the Commission approved five (5) Eligible customer applications as presented in Table 5.4 below; Table 5.4: Eligible Customers Authorised in 2022 | S/N | Applicant | Supplier | Capacity | Date | | --- | --- | --- | --- | --- | | 1 | Inner Galaxy Steel Company Limited | Kianji Hydro Electric Power Plc | 25MW | Nov 2022 | | 2 | Prism Steel Mills Limited | Mainstream Energy Solutions | 8MW | Jan 2022 | | 3 | Pulkit Alloy and Steel Limited | Calabar Generation Company Limited | 2MW | April 2022 | | 4 | Sunflag Steel Mills Limited | Calabar Generation Company Limited | 2MW | April 2022 | | 5 | Adefolorunsho Tech Ventures Limited | Mainstream Energy Solutions | 5MW | Sept 2022 | 5.2.5. Mini-grid Operators Registered with the Commission The Commission in 2022 approved forty-eight (48) Mini-grid permits and issued seventy (70) registration certificates. The details of the successful Mini-grid applicants in 2022 are provided in Table D.3 of the Appendix. * * * ## Regulatory Functions NERC Annual Report 2022 ## 5.3. Public Consultation and Awareness ## In 2022, the Commission commenced the process to amend the Mini-Grid ## Regulations, 2016. A series of stakeholder consultation workshops and ## engagement meetings were conducted across selected locations in the country. ## The consultation meetings provided a platform for stakeholders to make ## necessary input and contributions with respect to proposed changes to the ## Regulations. Stakeholder feedback from the consultation programmes are ## currently undergoing collation and review at the Commission. ## In addition, the Commission conducted several customer and stakeholder ## engagements through radio programs (e.g., Electricity Update) and eight (8) ## town hall meetings. These engagements aim to improve stakeholders' ## understanding of existing regulations, consumer rights and obligations, and ## industry rules. ## 5.4. Compliance Monitoring and Enforcement ## The Commission initiated several enforcement actions against licensees in the ## NESI within the year. These enforcement actions were to ensure compliance ## with industry rules and regulations. The infractions include violations of ## regulations and orders, accidents and electrocution cases, failure to provide ## required data within stipulated timelines, and failure to comply with Forum ## decisions within the designated timeframe. ## In line with its strategic goals, the Commission has intensified efforts at ## implementing various safety programmes aimed at minimising accidents in the ## industry. Some of the safety programmes implemented by the Commission ## include the standardisation of protective schemes, public enlightenment on ## health & safety, engagement of government agencies on Right of Way (RoW) ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## violations, and a review of an operational procedure for distribution system ## operators on fault clearing. ## 5.5. Litigation and Alternative Dispute Resolution ## 5.5.1. Litigation ## The Commission was involved in some litigations during the year. New ## litigations involving the Commission in 2022 include: ## 1\. Suit No: FHC/ABJ/CS/113/2022- Vigeo Power Limited v. Fidelity Bank ## Plc, NERC & 6 Others. An order of interlocutory injunction restraining ## the 1st Defendant, whether directly by itself or indirectly, through its ## directors, managers, officers, employees, servants, consultants, ## attorneys, agents, representatives, privies, however so-called, persons ## acting under its instructions and control, including the entities set out in ## the schedule to this application from altering or further altering the ## board composition of BEDC Electricity Plc (BEDC) or working in concert ## with any person or party to alter the board composition of BEDC, ## pending the hearing and determination of the substantive suit. The ## matter was adjourned to 1st March 2023 for the hearing of pending **applications.** **2\. Suit No: FHC/ABJ/CS/1135/2022- Northwest Power Limited v. Fidelity** **Bank, NERC, BPE & FGN. An Order of interlocutory Injunction** **restraining the 1st Defendant by itself, servants, agents, privies or** **howsoever described from dealing with any of the assets, be it fixed or** **floating, belonging to the Plaintiff, its directors, shareholders, privies,** **agents, and proxies used as one form of collateral or the other for the** **Term Loan Facility granted by the 1st Defendant pending the** **determination of the Plaintiff’s Suit. The matter has been transferred to** ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## Court 10 from Court 8 (Vacation Judge) but the Court is yet to ## communicate a date for hearing. ## 3\. Suit No: FHC/L/CS/1351/19 - PIPP LVI Disco v. NERC. The Plaintiff ## challenged the Order of the Commission on the grounds that they were ## not given a fair hearing and that the matter was sub-judice when the ## Commission intervened. The Commission issued an Order after a Notice ## of Intention to Commence Enforcement (NICE) had been sent to PIPP. ## The matter was adjourned to 8th March 2023 for a hearing of all ## pending applications. ## 4\. Suit No: FHC/ABJ/CS/681/21 – Ibadan Electricity Distribution ## Company Plc v. NERC and two others. The matter was adjourned to ## 26th January 2023 for all pending applications to be heard. ## 5\. Suit No: NICN/ABJ/04/2021 – Mr O. Expo v. NERC and Another. The ## matter was adjourned indefinitely pending the outcome of an arbitration ## proceeding. The arbitration was adjourned to the 5th and 6th of April ## 2023 for hearing. ## 5.5.2. Alternative Dispute Resolution among market participants ## Alternative Dispute Resolution (ADR) refers to the settlement process instituted ## by the Commission for the resolution of disputes that may arise among market ## participants. In accordance with Market Rule 42.3.7, the Commission ## constitutes a Dispute Resolution Panel (DRP) responsible for arbitrating or ## otherwise resolving disputes between market participants. Market Rule 42.3.8 ## stipulates that the DRP shall consist initially of at least three members and, upon ## the initiation of the Medium-Term Market, shall consist of at least ten (10) ## qualified persons, each of whom shall be appointed by the Commission. The ## DRP currently consists of twelve (12) members. The DRP did not handle any ## Nigerian Electricity Regulatory Commission * * * ## Regulatory Functions NERC Annual Report 2022 ## dispute between stakeholders of the industry as there was no pending dispute ## and no new dispute was reported in 2022. ## Section 42.3 of the Market Rule empowers the Commission to appoint a Dispute ## Resolution Counsellor (DRC) and constitute a Dispute Resolution Panel (DRP). ## The DRC, usually with extensive knowledge and experience in dispute ## resolution, is appointed by the Commission to administer and ensure an ## effective operation of the dispute resolution provisions of Market Rules and the ## Grid Code. In 2022, the Commission appointed a DRC as provided for under ## the Market Rules. The DRC is expected to work very closely with the DRP in ## discharging its duties. ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2022 # PART 6: CONSUMER AFFAIRS ## Nigerian Electricity Regulatory Commission * * * ## Consumer Affairs NERC Annual Report 2022 # 6.1 Consumer Education and Enlightenment # 6.2 Metering of End-use Customers # 6.3 Customer Complaints # 6.4 Forum Office # 6.5 Health and Safety 6.1 **Nigerian Electricity Regulatory Commission** 6.2 * * * 6.1 Consumer Education and Enlightenment Section 4 of the Electricity Distribution License NERC/LC/049 states that “The Licensee shall; (a) draw the attention of the consumers to the existence of the consumer protection standards, and substantive revisions and they may inspect or obtain a copy of the code in their latest form, (b) make copies of the standards available for inspection by members of the public at each of the relevant premises during normal working hours”. In furtherance of this, the Commission continued to monitor the customer enlightenment programmes across all the DisCos. In 2022, the Commission conducted eight (8) town hall meetings with electricity consumers as listed below; • Benin (March 15th – 17th) • Eko (May 11th – 13th) • Port-Harcourt (June 8th – 10th) • Sokoto (June 21st – 23rd) • Owerri (July 6th – 8th) • Ibadan (November 15th – 17th) • Katsina (November 22nd – 24th) and • Abuja (December 6th – 9th). During the meetings, discussions centered around several critical items including: • Issues around Service Based Tariff (SBT) • Capping of estimated billing • Strategies being adopted by the Commission to bridge the metering gap in the industry. • Metering gaps, and • Customers’ rights and obligations * * * During the year, the Commission continued the airing of a pre-recorded radio enlightenment program, ‘Electricity Update’ across twelve (12) states in the country including the Federal Capital Territory (FCT). Live radio sessions where the Commission’s staff addressed key issues in the Nigerian Electricity Supply Industry (NESI) were also aired. The Commission continued its Annual Electricity Essay Competition for secondary school students across the country in 2022. An award gala was held at the Commission on February 13th 2023 where the 3 best performers were presented with awards. 6.2. Metering of End-use Customers The status of the metering of end-use customers is presented in Table 6.1. The total number of registered customers as of December 2022 was 12,152,106 with 5,134,871 (42.25%) of them metered — metering rate increased by +5.79pp from 36.46% in 2021. | DisCos | Registered Customer 2022 | Metered Customer 2022 | Metered Customer 2021 | Metering Progress as 2022 | Metering Gap 2022 | | --- | --- | --- | --- | --- | --- | | Abuja | 1,290,977 | 757,458 | 701,781 | 58.67% | 41.33% | | Benin | 1,186,922 | 607,902 | 622,429 | 51.22% | 48.78% | | Eko | 689,237 | 391,398 | 347,116 | 56.79% | 43.21% | | Enugu | 1,391,562 | 537,408 | 545,035 | 38.62% | 61.38% | | Ibadan | 2,220,266 | 905,824 | 782,105 | 40.80% | 59.20% | | Ikeja | 1,298,323 | 763,680 | 633,562 | 58.82% | 41.18% | | Jos | 705,249 | 226,611 | 212,265 | 32.13% | 67.87% | | Kaduna | 844,996 | 197,442 | 166,814 | 23.37% | 76.63% | | Kano | 849,311 | 205,280 | 190,834 | 24.17% | 75.83% | | Port Harcourt | 1,179,194 | 445,174 | 404,439 | 37.75% | 62.25% | | Yola | 496,069 | 96,694 | 84,774 | 19.49% | 80.51% | | Total | 12,152,106 | 5,134,871 | 4,691,154 | 42.25% | 57.75% | * * * ## Consumer Affairs NERC Annual Report 2022 ## In 2022, 589,997 end-use customer meters were installed under the four (4) ## metering frameworks; Meter Asset Provider (MAP), National Mass Metering ## Programme (NMMP), Vendor Financed and DisCo Financed Metering. This ## was a 29.49% decrease compared to the 836,702 meters installed in 2021. ## The decrease in customer metering is attributed largely to the winding down of ## the NMMP phase 0. The metering gap for end-use customers remains a key ## challenge in the NESI with meter deployment being a critical strategy for ## reducing collection losses. ## Under the MAP framework, a total of 480,344 (+757.16%) meters were ## installed in 2022 compared to 56,039 installations in 2021. The increase is ## largely attributable to the winding down of the NMMP; when the distribution ## of free meters to customers ended, there was increased willingness for ## customers to procure meters under the MAP. MAP uptake was also aided by ## the issuance of the Meter Asset Provider and National Mass Metering ## Regulations (NERC-R-113-2021) which addressed some challenges with the ## implementation of the MAP. ## In the same period, 103,436 meters were installed under the NMMP ## framework, compared to 771,754 meters in 2021. The decrease is due to the ## winding down of phase 0 of the NMMP scheme. Except for Kaduna (30,920, ## +105.94%) and Yola (30,384, +410.23%), all other DisCos recorded a ## decline in their customer metering under the NMMP in 2022. The highest ## reduction was recorded by Ikeja DisCo as it had fully utilised its NMMP phase ## 0 meter allocation as at December 2021. As at the end of 2022, Abuja, ## Ibadan, Ikeja and Port Harcourt achieved 100% installation of their phase 0 ## meter allocation under the scheme while Eko, Enugu, Jos and Kano have ## attained over 90% installation of their meter allocations. ## Nigerian Electricity Regulatory Commission * * * Figure 6.1: Meter Installation in 2021 and 2022 In terms of annual meter deployment, Yola (+410%), Kaduna (+86.62%), Ibadan (+54.86%), and Ikeja (+15.32%) had increase in number of meters installed in 2022 compared to 2021. Conversely, Kano (-98.79%), Benin (- 91.10%), Jos (-85.07%), Port Harcourt (-63.75%), Eko (-46.88%), Enugu (- 40.24%) and Abuja (-4.69%) recorded decrease in total meter installations in 2022 compared to 2021 (Figure 6.1). The MAP and NMMP frameworks continue to provide the clearest path for mass customer metering. On NMMP, the Commission is actively engaging with the CBN, World Bank and other relevant stakeholders to accelerate the financial close and funds disbursement for the subsequent phases of the program (Phase 1 – funded by CBN and phase 2 – funded by the World Bank). On MAP, DisCos have been tasked to undertake extensive customer enlightenment campaigns to increase the uptake of MAP by customers. Furthermore, the Commission is working on finalising its regulatory directive to DisCos for customer refund under the MAP; it is expected that this will further incentivise other customers to procure meters under MAP. * * * ## Consumer Affairs NERC Annual Report 2022 ## The December 2022 Minor Review of MYTO 2022 provides that N0.75/kWh ## from the isCo’s revenue requirement be set aside as a contribution to the ## Meter Acquisition Fund (MAF) in 2023. The fund shall be centrally managed ## and used as securitisation for long-term financing to fund rapid closure of the ## current metering gap in the NESI – currently estimated at over 50%. ## 6.3. Customers Complaints ## The complaints received and resolved by DisCos in 2021 and 2022 are ## presented in Table 6.2. The total number of complaints received in 2022 was ## 1,002,998 across all DisCos and 927,722 of these complaints were resolved. ## The average resolution rate in 2022 was 92.49%. Compared to 2021, the ## number of complaints received, number of cases resolved, and average ## resolution rate changed by 54,826 (+5.78%), 21,132 (+2.33%) and -3.12pp **respectively.** ## Within the year, Port Harcourt DisCo had the highest number of complaints ## (192,443 representing 19.19% of total complaints received), while Yola DisCo ## had the lowest number of complaints (8,802 representing 0.88% of the total ## complaints received). All the DisCos except Eko, Ikeja and Ibadan had over ## 90% resolution rates in 2022. ## Compared to 2021, Ibadan (+233.59%), Port Harcourt (+60.35%), Yola ## (+28.63%) and Jos (+13.87%) DisCos recorded an increase in the number of ## complaints received. Conversely, Benin (-46.56%), Eko (-25.02%), Abuja (- ## 13.25%), Kaduna (-12.72%), Kano (-11.06%) and Ikeja (-7.13%) recorded ## decreases in their number of complaints received. ## Nigerian Electricity Regulatory Commission * * * Table 6.2: Complaints Received and Resolved by DisCos in 2021 and 2022 | DisCos | 2021 complaints | | | 2022 complaints | | | | --- | --- | --- | --- | --- | --- | --- | | Received | Resolved | Resolution Rate | Received | Resolved | Resolution Rate | | | Abuja | 131,857 | 128,570 | 97.51% | 114,388 | 112,324 | 98.20% | | Benin | 57,290 | 54,374 | 94.91% | 30,616 | 28,168 | 92.00% | | Eko | 197,603 | 194,182 | 98.27% | 148,165 | 136,075 | 91.84% | | Enugu | 101,979 | 94,441 | 92.61% | 103,666 | 92,313 | 89.05% | | Ibadan | 37,339 | 33,103 | 88.66% | 124,560 | 104,039 | 83.53% | | Ikeja | 149,578 | 137,063 | 91.63% | 138,918 | 119,525 | 86.04% | | Jos | 50,121 | 48,310 | 96.39% | 57,072 | 55,530 | 97.30% | | Kaduna | 36,864 | 33,688 | 91.38% | 32,175 | 29,876 | 92.85% | | Kano | 58,681 | 57,381 | 97.78% | 52,193 | 51,785 | 99.22% | | Port Harcourt | 120,017 | 118,794 | 98.98% | 192,443 | 189,391 | 98.41% | | Yola | 6,843 | 6,684 | 97.68% | 8,802 | 8,696 | 98.80% | | Total | 948,172 | 906,590 | 95.61% | 1,002,998 | 927,722 | 92.49% | In 2022, customer complaints were predominantly on metering (44.15%), billing (19.98%), and service interruptions (10.90%), accounting for over 74% of total complaints (Figure 6.2). To address these major customer concerns, the Commission has introduced a few initiatives. For instance, the Commission has initiated a process to independently verify DisCos' compliance with capping regulations to protect unmetered customers from overbilling with respect to issues on billing and metering. The Commission now has access to the DisCos' billing platforms, allowing it to access billing records for each unmetered customer and compare the energy billed with the energy cap set by the Commission. Any DisCo that bills a customer above the approved energy cap will be subject to enforcement action by the Commission as stipulated in the Commission’s Order on Performance Monitoring Framework (NERC/316-326/2022) issued in September 2022. * * * Figure 6.2: Categories of Complaints Received by DisCos In furtherance of its mandate to ensure adequate and timely customer complaints resolution, the Commission continues to monitor complaints handling and resolution processes adopted by DisCos. In this regard, it requires monthly submission of customer complaints reports from DisCos to ensure timely submission of customer complaints reports from DisCos to ensure timely regulatory intervention when necessary. Within the year, the Commission also regulatory intervention when necessary. Within the year, the Commission also commenced the review of its strategy for monitoring DisCos' customer complaints handling and resolution processes to further enhance regulatory oversight. This review includes the operations of the Commission's Forum Offices, which are established to address customer complaints that are not satisfactorily resolved at the isCos’ Customer Complaints Units ( isCos-CCU). regulatory intervention when necessary. Within the year, the Commission also commenced the review of its strategy for monitoring DisCos' customer complaints handling and resolution processes to further enhance regulatory oversight. This review includes the operations of the Commission's Forum Offices, which are established to address customer complaints that are not satisfactorily resolved at the isCos’ Customer Complaints Units ( isCos-CCU). n line with the Commission’s mandate on customer protection Forum Offices are set up pursuant to section 80(1)(b) of the EPSRA to hear and resolve customer complaints that are not satisfactorily resolved at the isCos’ Customer Complaints Units (DisCos-CCU). The Forum Office is managed by the Forum * * * ## Consumer Affairs NERC Annual Report 2022 ## Secretariat (staff of the Commission) while the Hearings are conducted by five ## Forum Members who are not Commission staff and are selected from the ## following groups/agencies – ## 1\. One representative of Industrial customers to be nominated by the ## anufacturers’ ssociation of igeria ( ) ## 2\. One representative of Commercial customers to be nominated by the ## Nigerian Association of Chambers of Commerce, Industry, Mining and ## Agriculture (NACCIMA). ## 3\. One representative of household customers to be nominated by the ## Federal Competition and Consumers Protection Commission (FCCPC). ## 4\. One representative of an NGO based in the DisCos operating area to be ## nominated by the Commission. ## 5\. One nominee based in the DisCos operating area who has an electrical ## engineering background to be nominated by the Commission. ## The Forum enables customers and DisCos to explore options to resolve service- ## related disputes as enshrined in the E C’s Customer Complaints andling ## Standards and Procedures (CCHSP) Regulations. As at 31st December 2022, ## the Commission had thirty-one (31) operational Forum Offices in twenty-nine ## (29) states and the FCT, Abuja. The details, including names, addresses and ## contacts of the Commission’s Forum Offices are presented in Table E.7 of the **appendix.** **Table 6.3 presents a summary of the appeals across the Forum Offices in 2022.** ## A total of 9,972 (6,963 new appeals and 3,009 pending appeals from 2021) ## appeals were received across all Forum Offices. This represents an increase of ## 13.62% compared to 8,777 appeals in 2021. The Forum Office serving Ikeja ## DisCo received the highest number of appeals (1,886) while Yola DisCo ## Nigerian Electricity Regulatory Commission * * * received the fewest (104) corresponding to 18.91% and 1.04% of total appeals respectively. Cumulatively, the Forum Offices resolved 57.10% of the total active appeals. This is a decline of -8.62pp in resolution rate compared to 65.72% achieved in 2021\. This decrease is attributed to the higher number of appeals received in 2022\. The Commission is taking steps to increase the frequency of sittings; this is intended to hasten the resolution of appeals at Forum Offices. Fifty-nine (59) cases (0.59%) of the undecided appeals at the Forum Offices were due to incomplete submissions. Table 6.3: Appeals Handled by Forum Offices in 2022 | Forum Offices | DisCos | Appeals Received | Appeals Resolved | Appeals Pending | Resolution Rate | No of Sittings | | --- | --- | --- | --- | --- | --- | --- | | Abuja, Lafia & Lokoja | Abuja | 254 | 226 | 28 | 88.98% | 22 | | Asaba & Benin | Benin | 464 | 434 | 30 | 93.53% | 31 | | Eko | Eko | 328 | 263 | 65 | 80.18% | 16 | | Abakaliki, Akwa, Enugu, Owerri & Umuahia | Enugu | 928 | 771 | 157 | 83.08% | 57 | | Ibadan, Ilorin & Osogbo | Ibadan | 1352 | 1088 | 264 | 80.47% | 40 | | Ikeja | Ikeja | 1886 | 1157 | 729 | 61.35% | 25 | | Bauchi, Gombe, Jos & Makurdi | Jos | 243 | 176 | 67 | 72.43% | 14 | | Gusau, Kaduna, Kebbi & Sokoto | Kaduna | 395 | 353 | 42 | 89.37% | 24 | | Jigawa, Kano & Katsina | Kano | 136 | 91 | 45 | 66.91% | 5 | | Calabar, Port Harcourt & Uyo | P/H | 1279 | 982 | 297 | 76.78% | 34 | | Yola | Yola | 104 | 98 | 6 | 94.23% | 6 | | All Forum Offices | All | 9972 | 5694 | 4278 | 57.10% | 274 | The breakdown of the various categories of appeals received at the Forum Offices is presented in Figure 6.3. Billing was the most prevalent complaint within the year, accounting for 66.67% of the total. Complaints about metering and disconnection represented 20.70% and 5.51% of the appeals respectively. To ensure DisCos comply with the forum rulings, the Commission has introduced “Compliance with forum rulings” as one of the indices contained in the Order 3\. Some of the pending appeals are still within the regulatory timeframe of 2 months to resolve. * * * on Performance Monitoring Framework. As contained in the KPI order, a DisCo is fined N10,000 per day for non-compliance with the forum ruling. Furthermore, the Commission is reviewing its customer service standards regulations and also exploring other measures to increase definitive and mutually satisfactory case resolution at the DisCos-CCU. This will reduce the number of complaints escalated to the Forum Offices. Figure 6.3: Category of Complaints Received by Forum Offices in 2022 6.5. Health and Safety ursuant to its ob ective “to ensure the provision of safe and reliable electricity to consumers” as specified in ection 2(1)(e) of the E SRA, the Commission monitors health and safety performance of the NESI. * * * ## Consumer Affairs NERC Annual Report 2022 ## Accident statistics for the NESI in 2021 and 2022 are presented in Table 6.4. ## The total number of accidents in 2022 was one hundred and seventy-three ## (173), which resulted in 93 injuries and 109 fatalities. Compared to 2021, the ## total number of accidents, injuries and fatalities changed by –1.70%, +52.46% ## and -5.22% respectively. **Table 6.4: NESI Licensee Health and Safety Reports of 2021 and 2022** ## Year Net ## Item 2021 2022 Change **Number of accidents 176 173-3** **Number of injuries 61 93 +32** **Number of fatalities (employees & third parties) 115 109-6** ## In line with its mandate to ensure licensees’ commitment to safe energy delivery, ## the Commission commenced investigations into all the health and safety ## accidents in 2022. Upon the completion of investigation, the Commission will ## commence enforcement action against the relevant licensees with a view of ## creating deterrence against unsafe operations in the NESI. ## In line with its 2021-2023 strategic goals, the Commission is taking initiatives at ## implementing various safety programmes aimed at minimising accidents in the ## NESI. Some of such initiatives include the standardisation of protective schemes, ## public enlightenment on health and safety, engagement of government ## agencies on Right of Way (RoW) violation, and a review of an operational ## procedure for distribution system operators on fault clearing. ## Nigerian Electricity Regulatory Commission * * * # APPENDIX: KEY STATISTICS * * * # A. Electricity Generation B. Grid Performance # C. Commercial Performance D. Licence, Permit and Certification # E. Consumer Enlightenment, Metering and Customer Complaints * * * A. Electricity Generation Table A.1: Daily available capacity, available units and synchronised units, 2019-2022 | Period | Installed Available Capacity(MW) | | | | Number of AvailablePlant Units | | | | Number of synchronised plantUnits | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | | January | 4,783 | 5,103 | 5,663 | 5,597 | 63 | 58 | 65 | 58 | 63 | 57 | 56 | 53 | | February | 4,863 | 5,513 | 5,755 | 6,553 | 63 | 58 | 68 | 63 | 63 | 56 | 64 | 55 | | March | 4,491 | 5,601 | 5,275 | 6,158 | 59 | 60 | 65 | 62 | 59 | 55 | 62 | 57 | | April | 5,099 | 5,023 | 6,315 | 6,094 | 67 | 54 | 73 | 61 | 60 | 51 | 63 | 53 | | May | 4,608 | 5,002 | 6,421 | 5,949 | 60 | 64 | 73 | 62 | 57 | 52 | 66 | 53 | | June | 3,845 | 4,505 | 6,341 | 6,162 | 54 | 59 | 73 | 63 | 53 | 57 | 61 | 53 | | July | 4,092 | 4,858 | 6,301 | 6,617 | 56 | 60 | 74 | 67 | 55 | 56 | 61 | 54 | | August | 4,575 | 5,593 | 6,673 | 6,862 | 60 | 63 | 77 | 68 | 58 | 60 | 64 | 55 | | September | 4,456 | 5,453 | 6,048 | 6,647 | 58 | 58 | 71 | 64 | 58 | 56 | 61 | 49 | | October | 4,233 | 5,764 | 6,710 | 6,697 | 58 | 54 | 77 | 66 | 58 | 52 | 65 | 48 | | November | 4,537 | 5,432 | 5,893 | 6,486 | 63 | 63 | 68 | 68 | 63 | 60 | 66 | 51 | | December | 4,740 | 5,200 | 5,888 | 5,532 | 65 | 62 | 68 | 56 | 64 | 61 | 67 | 49 | | Average | 4,527 | 5,254 | 6,107 | 6,280 | 60 | 60 | 71 | 63 | 59 | 55 | 63 | 52 | Table A.2: Daily transmission capacity, energy generated and energy sent out, 2019- 2022 | | Transmission Capacity(MW) | | | | Energy Generated(MW) | | | | | Energy Sent Out(MW) | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | | | January | 8,100 | 7,300 | 4,800 | 4,800 | 4,265 | 4,495 | 3,817 | 4,003 | 4,187 | 4,424 | 3,732 | 3,952 | | | | February | 8,100 | 7,300 | 4,800 | 4,800 | 4,317 | 4,561 | 4,114 | 4,209 | 4,225 | 4,482 | 4,008 | 4,148 | | | | March | 8,100 | 7,300 | 4,800 | 4,800 | 3,728 | 4,410 | 3,912 | 4,228 | 3,680 | 4,328 | 3,858 | 4,167 | | | | April | 8,100 | 7,300 | 4,800 | 4,879 | 3,813 | 4,308 | 4,099 | 4,068 | 3,765 | 4,229 | 4,031 | 4,008 | | | | May | 8,100 | 7,300 | 4,800 | 4,848 | 3,630 | 4,149 | 4,168 | 3,831 | 3,579 | 4,075 | 4,100 | 3,774 | | | | June | 8,100 | 7,300 | 4,800 | 4,818 | 3,224 | 3,774 | 3,726 | 3,711 | 3,178 | 3,705 | 3,660 | 3,648 | | | | July | 8,100 | 7,300 | 4,800 | 4,917 | 3,634 | 3,940 | 3,821 | 3,737 | 3,593 | 3,866 | 3,757 | 3,676 | | | | August | 8,100 | 7,300 | 4,800 | 4,886 | 3,939 | 4,003 | 4,045 | 3,584 | 3,883 | 3,934 | 3,981 | 3,526 | | | | September | 8,100 | 7,300 | 4,800 | 4,856 | 4,047 | 3,867 | 3,863 | 3,524 | 3,940 | 3,801 | 3,806 | 3,474 | | | | October | 8,100 | 7,300 | 4,800 | 4,825 | 3,976 | 4,138 | 4,155 | 3,463 | 3,937 | 4,078 | 4,088 | 3,411 | | | | November | 8,100 | 7,300 | 4,800 | 4,828 | 4,304 | 4,336 | 4,424 | 3,804 | 4,264 | 4,275 | 4,358 | 3,751 | | | | December | 8,100 | 7,300 | 4,800 | 4,713 | 4,448 | 4,409 | 4,504 | 3,744 | 4,395 | 4,339 | 4,432 | 3,688 | | | | Average | 8,100 | 7,300 | 4,800 | 4,831 | 3,944 | 4,199 | 4,054 | 3,826 | 3,886 | 4,128 | 3,984 | 3,768 | | | * * * Table A.3: Plants’ average load factor, 2019-2022 | | Load Factor(%) | | | | | --- | --- | --- | --- | --- | | GenCos | 2022 | 2021 | 2020 | 2019 | | AES Barge IPP | 0 | 0 | 0 | 0 | | Afam IV-V | 78.90 | 75.69 | 62.84 | 44.13 | | Afam VI IPP | 97.72 | 92.91 | 68.79 | 38.13 | | Alaoji NIPP | 80.10 | 51.29 | 40.06 | 37.26 | | ASCO IPP | 0 | 0 | 0 | 0 | | Azura Edo IPP | 93.23 | 88.90 | 79.74 | 57.47 | | Dadin Kowa | 97.93 | 0 | 0 | 0 | | Delta | 87.69 | 82.27 | 67.77 | 68.60 | | Egbin | 91.48 | 81.59 | 65.36 | 56.06 | | Gbarain NIPP | 0 | 0 | 42.91 | 44.54 | | Geregu | 76.05 | 76.14 | 64.04 | 57.5 | | Geregu NIPP | 64.74 | 64.91 | 64.84 | 63.74 | | Ibom Power IPP | 52.37 | 80.69 | 55.02 | 62.20 | | Ihovbor NIPP | 50.55 | 50.60 | 36.79 | 66.36 | | Jebba | 84.96 | 85.08 | 78.73 | 75.04 | | Kainji | 94.93 | 95.05 | 83.60 | 81.60 | | Odukpani NIPP | 72.89 | 72.88 | 61.62 | 47.49 | | Okpai IPP | 78.24 | 78.52 | 59.02 | 58.06 | | Olorunsogo | 75.46 | 75.45 | 61.87 | 57.90 | | Olorunsogo NIPP | 66.08 | 65.11 | 60.54 | 66.43 | | Omoku IPP | 87.31 | 87.26 | 55.60 | 71.39 | | Omotosho | 84.09 | 84.07 | 65.69 | 67.61 | | Omotosho NIPP | 52.69 | 52.76 | 60.50 | 69.05 | | Paras Energy IPP | 79.14 | 79.20 | 73.87 | 83.51 | | Rivers IPP | 71.49 | 71.72 | 72.92 | 67.77 | | Sapele | 52.37 | 51.87 | 55.98 | 38.12 | | Sapele NIPP | 77.43 | 77.37 | 33.71 | 72.23 | | Shiroro | 74.54 | 74.54 | 67.59 | 59.62 | | Trans-Amadi IPP | 79.08 | 79.12 | 65.98 | 65.91 | | Average | 85.94 | 79.92 | 61.74 | 60.26 | * * * Table A.4: Annual electricity output and share by fuel type, 2019-2022 | | | Total Electricity Output(GWh) | | | | Fuel Share of Electricity Output(%) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | Fuel Type | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | Q1 | Thermal | 6,497.92 | 7,515.43 | 6,327.40 | 7,449.26 | 73.44 | 77.53 | 73.45 | 82.28 | | Hydro | 2,350.12 | 2,174.89 | 2,286.59 | 1,604.64 | 26.56 | 22.47 | 26.55 | 17.72 | | | Q2 | Aggregate | 8,848.04 | 9,690.32 | 8,614.00 | 9,053.89 | 100 | 100 | 100 | 100 | | Thermal | 6,324.19 | 7,295.96 | 7,121.44 | 7,128.99 | 81.44 | 81.91 | 81.53 | 84.35 | | | Q3 | Hydro | 1,442.48 | 1,609.71 | 1,613.49 | 1,322.43 | 18.56 | 18.09 | 18.47 | 15.65 | | Aggregate | 7,766.66 | 8,905.67 | 8,734.93 | 8,451.43 | 100 | 100 | 100 | 100 | | | Thermal | 6,027.94 | 6,737.64 | 6,318.88 | 6,608.10 | 70.58 | 77.42 | 76.45 | 82.76 | | | Q4 | Hydro | 2,512.51 | 1,956.13 | 1,946.54 | 1,376.59 | 29.42 | 22.58 | 23.55 | 17.24 | | Aggregate | 8,850.45 | 8,693.77 | 8,265.42 | 7,984.68 | 100 | 100 | 100 | 100 | | | Thermal | 6,438.98 | 6,830.77 | 7,248.67 | 6,239.04 | 70.90 | 72.06 | 75.29 | 77.01 | | | Hydro | 2,926.67 | 2,649.44 | 2,379.53 | 1,862.15 | 31.10 | 27.94 | 24.71 | 22.99 | | | Annual | Aggregate | 9,365.65 | 9,480.21 | 9,628.20 | 8,101.19 | 100 | 100 | 100 | 100 | | Thermal | 25,613.29 | 28,379.80 | 27,016.40 | 27,425.38 | 73.30 | 77.17 | 76.69 | 81.64 | | | Hydro | 9,328.98 | 8,390.16 | 8,213.82 | 6,165.81 | 26.70 | 22.83 | 23.31 | 18.36 | | | Aggregate | 34,942.27 | 36,769.97 | 35,230.22 | 33,591.20 | 100 | 100 | 100 | 100 | | * * * Table A.5: Plant share of total electricity output, 2019-2022 | GenCos | Electricity Output by Plant (GWh) | | | | Electricity Output by Plant(%) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | | AES Barge IPP | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | | Afam IV-V | 432.31 | 587.38 | 0.00 | 288.63 | 1.24 | 1.59 | 1.29 | 0.86 | | Afam VI IPP | 853.46 | 2,411.35 | 83.41 | 1,460.62 | 2.44 | 6.53 | 6.36 | 4.35 | | Alaoji NIPP | 578.62 | 508.29 | 130.43 | 208.90 | 1.66 | 1.37 | 1.53 | 0.62 | | ASCO IPP | 0 | 0.00 | 185.75 | 0 | 0 | 0 | 0 | 0 | | Azura Edo IPP | 3,454.41 | 3,254.17 | 250.10 | 2,269.72 | 9.89 | 8.84 | 8.27 | 6.76 | | Dadin Kowa | 233.81 | 112.14 | 0 | 0 | 0.67 | 0 | 0 | 0 | | Delta | 3,341.28 | 2,770.46 | 306.09 | 2,756.92 | 9.56 | 7.53 | 7.56 | 8.21 | | Egbin | 3,799.76 | 5,529.23 | 326.47 | 3,795.47 | 10.87 | 15.29 | 13.54 | 11.3 | | Egbin ST6 | 0 | 85.37 | 0 | 0 | 0 | 0 | 0 | 0 | | Gbarain NIPP | 0 | 0 | 453.12 | 265.12 | 0 | 0 | 0.24 | 0.79 | | Geregu | 1,618.57 | 2,460.19 | 481.93 | 1,905.80 | 4.63 | 6.70 | 5.76 | 5.67 | | Geregu NIPP | 733.81 | 679.03 | 492.86 | 1,209.92 | 2.10 | 1.85 | 2.31 | 3.60 | | Ibom Power IPP | 308.65 | 110.73 | 539.31 | 490.62 | 0.88 | 0.30 | 0.93 | 1.46 | | Ihovbor NIPP | 529.07 | 148.56 | 628.27 | 699.62 | 1.51 | 0.40 | 0.53 | 2.08 | | Jebba | 2,858.69 | 3,073.83 | 652.29 | 2,865.32 | 8.18 | 8.37 | 7.68 | 8.53 | | Kainji | 3,201.66 | 2,830.66 | 814.57 | 2,971.92 | 9.16 | 7.70 | 8.31 | 8.85 | | Odukpani NIPP | 1,924.90 | 2,537.68 | 834.17 | 1,951.38 | 5.51 | 6.90 | 6.99 | 5.81 | | Okpai IPP | 2,066.14 | 2,347.39 | 1,054.82 | 1,357.83 | 5.91 | 6.40 | 4.46 | 4.04 | | Olorunsogo | 952.53 | 1,080.27 | 1,128.71 | 1,392.73 | 2.73 | 2.94 | 3.20 | 4.15 | | Olorunsogo NIPP | 348.71 | 64.85 | 1,571.30 | 215.16 | 1.00 | 0.17 | 0.37 | 0.64 | * * * Key Statistics B. Grid Performance Table B.1: Average monthly transmission loss factor, 2020-2022 | | Energy Injected into Grid(GWh) | | | Energy Delivered to DisCos&Exported(GWh) | | | Transmission Losses Factor(%) | | | MYTO Allowance(%) | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Month | 2022 | 2021 | 2020 | 2022 | 2021 | 2020 | 2022 | 2021 | 2020 | 2022 | | January | 3,136 | 3,295 | 2,813 | 2,812 | 3,043 | 2,603 | 8.15% | 7.64% | 7.48% | 7.50% | | February | 2,860 | 3,007 | 2,826 | 2,554 | 2,781 | 2,593 | 8.54% | 7.51% | 8.23% | 7.50% | | March | 2,754 | 3,220 | 2,863 | 2,487 | 2,982 | 2,665 | 7.38% | 7.37% | 6.91% | 7.50% | | April | 2,717 | 3,004 | 2,900 | 2,446 | 2,816 | 2,730 | 8.44% | 7.49% | 5.87% | 7.50% | | May | 2,662 | 3,033 | 3,062 | 2,081 | 2,809 | 2,820 | 8.43% | 7.41% | 7.93% | 7.50% | | June | 2,291 | 2,664 | 2,640 | 2,465 | 2,464 | 2,441 | 8.20% | 7.49% | 7.55% | 7.50% | | July | 2,677 | 2,834 | 2,810 | 2,593 | 2,654 | 2,601 | 8.08% | 6.34% | 7.45% | 7.50% | | August | 2,870 | 2,890 | 2,967 | 2,637 | 2,705 | 2,741 | 7.78% | 6.43% | 7.60% | 7.50% | | September | 2,847 | 2,714 | 2,743 | 2,701 | 2,522 | 2,535 | 7.50% | 7.07% | 7.56% | 7.50% | | October | 2,917 | 3,030 | 3,067 | 2,851 | 2,785 | 2,843 | 7.42% | 8.07% | 7.30% | 7.50% | | November | 3,059 | 3,091 | 3,118 | 3,012 | 2,828 | 2,903 | 6.81% | 8.50% | 6.90% | 7.50% | | December | 3,263 | 3,243 | 3,295 | 2,755 | 2,983 | 3,053 | 7.71% | 8.03% | 7.34% | 7.50% | | Average | 2,838 | 3,005 | 2,925 | 2,616 | 2,781 | 2,711 | 7.87% | 7.45% | 7.34% | 7.50% | | Total | 34,054 | 36,065 | 35,104 | 31,393 | 33,373 | 32,527 | 7.87% | 7.45% | 7.34% | 7.50% | Table B.2: Number of system collapses, 2011-2022 | 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 B.3: Average daily system frequency, 2019-2022 | Period | Nominal Standard | Upper bound Frequency | | | | Lower bound Frequency | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | | | January | 50 | 50.68 | 50.49 | 50.82 | 50.65 | 49.13 | 49.17 | 49.67 | 49.50 | | February | 50 | 50.60 | 50.59 | 50.7 | 50.46 | 49.05 | 49.38 | 49.75 | 49.77 | | March | 50 | 50.78 | 50.62 | 50.65 | 50.46 | 49.07 | 49.29 | 49.48 | 49.60 | | April | 50 | 51.12 | 50.72 | 50.77 | 50.43 | 49.08 | 49.12 | 49.63 | 49.71 | | May | 50 | 50.47 | 50.64 | 50.67 | 50.62 | 49.13 | 49.13 | 49.70 | 49.72 | | June | 50 | 50.73 | 50.70 | 50.86 | 50.51 | 49.09 | 49.07 | 49.73 | 49.77 | | July | 50 | 50.63 | 50.69 | 50.78 | 50.51 | 48.71 | 49.95 | 49.83 | 49.73 | | August | 50 | 51.14 | 50.81 | 50.74 | 50.61 | 48.65 | 49.35 | 49.84 | 49.78 | | September | 50 | 50.81 | 51.00 | 50.81 | 50.74 | 48.76 | 49.24 | 49.86 | 50.22 | | October | 50 | 50.66 | 50.96 | 50.88 | 50.93 | 49.08 | 49.43 | 49.70 | 49.89 | | November | 50 | 50.44 | 50.72 | 50.58 | 50.88 | 49.07 | 49.32 | 49.34 | 49.72 | | December | 50 | 50.56 | 50.59 | 50.44 | 50.81 | 49.09 | 49.20 | 49.40 | 49.52 | | Average | 50 | 50.72 | 50.71 | 50.73 | 50.63 | 48.99 | 49.30 | 49.66 | 49.74 | Notes of the table: 1. Upper Limit (50.25Hz), Lower Limit (49.75), Higher Bound (51.25Hz), and Lower Bound (48.57Hz) Table B.4: Average daily system voltage, 2019-2022 | | Nominal Standard(kV) | Upper bound Voltage(kV) | | | | Lower bound Voltage(kV) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Period | 2022 | 2021 | 2020 | 2019 | 2022 | 2021 | 2020 | 2019 | | | January | 330.00 | 352.90 | 349.81 | 355.48 | 348.26 | 297.74 | 298.48 | 298.19 | 295.00 | | February | 330.00 | 352.76 | 348.96 | 351.52 | 349.36 | 297.36 | 299.21 | 299.00 | 298.39 | | March | 330.00 | 351.18 | 350.87 | 352.65 | 350.23 | 297.00 | 296.07 | 299.03 | 294.03 | | April | 330.00 | 358.00 | 349.13 | 356.80 | 360.83 | 299.00 | 297.17 | 290.97 | 299.40 | | May | 330.00 | 357.00 | 351.75 | 355.29 | 355.71 | 300.00 | 294.78 | 290.87 | 298.23 | | June | 330.00 | 358.00 | 353.47 | 355.90 | 356.13 | 300.00 | 299.97 | 297.50 | 299.03 | | July | 330.00 | 335.42 | 353.35 | 355.00 | 354.13 | 299.53 | 300.16 | 296.93 | 299.48 | | August | 330.00 | 358.24 | 352.23 | 354.47 | 356.29 | 299.10 | 298.74 | 297.67 | 299.39 | | September | 330.00 | 353.21 | 352.90 | 354.83 | 355.03 | 299.83 | 297.74 | 300.97 | 299.20 | | October | 330.00 | 351.03 | 352.90 | 353.74 | 357.73 | 299.45 | 297.74 | 296.16 | 299.61 | | November | 330.00 | 352.96 | 352.76 | 352.37 | 356.10 | 299.93 | 397.36 | 294.87 | 299.47 | | December | 330.00 | 352.21 | 351.18 | 349.55 | 351.47 | 298.73 | 297.00 | 298.61 | 300.58 | | Average | 330.00 | 352.74 | 351.61 | 353.97 | 354.27 | 298.97 | 297.87 | 296.73 | 298.48 | 1. Upper Voltage (346.50kV), and Lower Voltage (313.50kV) * * * C. Commercial Performance Table C.1: DisCos’ energy received, billed and billing efficiency 2020-2022 | | Total Energy Received(GWh) | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 Quarters | | | | Annual | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2022 | 2021 | 2020 | | | DisCos | 965 | 847 | 983 | 1,111 | 3,906 | 4,050 | 3,876 | | Abuja | 718 | 609 | 684 | 688 | 2,698 | 2,683 | 2,579 | | Benin | 764 | 688 | 762 | 911 | 3,125 | 3,591 | 3,558 | | Eko | 746 | 601 | 623 | 642 | 2,612 | 2,841 | 2,426 | | Enugu | 899 | 777 | 868 | 906 | 3,450 | 4,092 | 4,035 | | Ibadan | 1,039 | 898 | 1,031 | 1,113 | 4,082 | 4,548 | 4,581 | | Ikeja | 378 | 350 | 400 | 438 | 1,566 | 1,403 | 1,378 | | Jos | 572 | 497 | 499 | 542 | 2,110 | 2,324 | 2,295 | | Kaduna | 500 | 408 | 476 | 539 | 1,923 | 1,951 | 1,875 | | Port Harcourt | 490 | 461 | 525 | 548 | 2,024 | 2,109 | 2,027 | | Yola | 230 | 208 | 195 | 223 | 856 | 902 | 1,189 | | Total | 7,301 | 6,344 | 7,045 | 7,662 | 28,352 | 30,494 | 29,819 | | Average | 664 | 577 | 640 | 697 | 2,577 | 2,772 | 2,711 | | | Total Energy Billed(GWh) | | | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2022 | 2021 | 2020 | | | 643 | 594 | 690 | 750 | 2,677 | 2,682 | 2,364 | | | Abuja | 597 | 508 | 569 | 600 | 2,274 | 2,246 | 2,165 | | Benin | 666 | 616 | 693 | 811 | 2,786 | 3,141 | 3,129 | | Eko | 516 | 441 | 444 | 451 | 1,852 | 2,035 | 1,748 | | Enugu | 516 | 441 | 444 | 451 | 1,852 | 2,035 | 1,748 | | Ibadan | 662 | 593 | 631 | 681 | 2,567 | 2,920 | 2,857 | | Ikeja | 910 | 796 | 914 | 992 | 3,613 | 4,081 | 4,167 | | Jos | 287 | 259 | 283 | 352 | 1,181 | 976 | 779 | | Kaduna | 464 | 382 | 245 | 258 | 1,349 | 1,767 | 1,413 | | Kano | 372 | 291 | 321 | 362 | 1,346 | 1,454 | 1,434 | | Port Harcourt | 401 | 364 | 425 | 450 | 1,639 | 1,625 | 1,564 | | Yola | 131 | 116 | 110 | 128 | 486 | 420 | 543 | * * * Table C.2: Revenue performance by DisCos, 2020-2022 | DisCos | Total Billing(新1 Billion) | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 Quarters | | | | Annual | | | | | /Q1 | /Q2 | /Q3 | /Q4 | 2022 | 2021 | 2020 | | | Abuja | 36.49 | 33.82 | 39.27 | 44.64 | 154.22 | 140.63 | 92.97 | | Benin | 31.00 | 27.17 | 30.76 | 33.16 | 122.07 | 105.77 | 85.97 | | Eko | 34.52 | 32.63 | 37.69 | 46.48 | 151.31 | 145.61 | 107.67 | | Enugu | 27.45 | 23.56 | 24.40 | 25.93 | 101.34 | 98.00 | 74.64 | | Ibadan | 34.80 | 32.01 | 34.08 | 36.44 | 137.33 | 139.71 | 101.16 | | Ikeja | 44.53 | 39.53 | 46.55 | 51.81 | 182.42 | 184.22 | 133.33 | | Jos | 16.94 | 15.55 | 17.25 | 23.83 | 73.57 | 49.32 | 30.61 | | Kaduna | 24.15 | 19.50 | 13.40 | 14.94 | 71.98 | 89.77 | 57.14 | | Kano | 19.02 | 15.81 | 17.97 | 21.00 | 73.79 | 69.17 | 52.57 | | Port Harcourt | 21.03 | 19.65 | 23.59 | 26.07 | 90.34 | 76.23 | 61.79 | | Yola | 5.78 | 6.45 | 6.71 | 7.99 | 26.93 | 18.47 | 18.32 | | Total | 295.70 | 265.68 | 291.66 | 332.28 | 1,185.31 | 1,116.92 | 816.16 | | Average | 26.88 | 24.15 | 26.51 | 30.21 | 107.76 | 101.54 | 74.20 | Total Revenue Collected (₦’ Billion) /Q3 /Q4 2022 | | /Q1 | /Q2 | /Q3 | /Q4 | 2022 | 2021 | 2020 | | --- | --- | --- | --- | --- | --- | --- | --- | | Abuja | 30.42 | 28.99 | 32.00 | 36.40 | 127.80 | 117.61 | 82.61 | | Benin | 16.10 | 16.22 | 17.25 | 20.33 | 69.90 | 58.16 | 45.66 | | Eko | 28.79 | 27.74 | 32.28 | 38.97 | 127.79 | 120.89 | 84.65 | | Enugu | 18.18 | 16.74 | 16.96 | 19.05 | 70.93 | 69.83 | 47.83 | | Ibadan | 21.84 | 21.24 | 23.57 | 29.02 | 95.67 | 91.37 | 61.80 | | Ikeja | 40.62 | 36.87 | 43.40 | 47.42 | 168.31 | 157.40 | 105.23 | | Jos | 7.15 | 7.64 | 7.62 | 8.60 | 31.01 | 24.80 | 17.44 | | Kaduna | 7.49 | 6.57 | 6.31 | 7.88 | 28.25 | 30.64 | 21.53 | | Kano | 11.79 | 10.20 | 12.48 | 14.44 | 48.91 | 47.39 | 33.84 | | Port Harcourt | 13.57 | 13.01 | 15.12 | 17.07 | 58.77 | 47.72 | 31.39 | | Yola | 3.24 | 3.07 | 3.69 | 4.47 | 14.46 | 9.54 | 10.74 | | Total | 199.19 | 188.29 | 210.68 | 243.65 | 841.81 | 775.34 | 542.73 | | Average | 18.11 | 17.12 | 19.15 | 22.15 | 76.53 | 70.49 | 49.34 | | | /Q1 | /Q2 | /Q3 | /Q4 | 2022 | 2021 | 2020 | | --- | --- | --- | --- | --- | --- | --- | --- | | Abuja | 83.36 | 85.72 | 81.47 | 81.55 | 82.87 | 83.63 | 88.86 | | Benin | 51.94 | 59.70 | 56.09 | 61.33 | 57.26 | 54.98 | 53.11 | | Eko | 83.42 | 85.02 | 85.64 | 83.85 | 84.45 | 83.02 | 78.62 | | Enugu | 66.23 | 71.03 | 69.51 | 73.46 | 69.99 | 71.25 | 64.08 | | Ibadan | 62.77 | 66.35 | 69.16 | 79.64 | 69.67 | 65.39 | 61.09 | | Ikeja | 91.23 | 93.27 | 93.23 | 91.52 | 92.27 | 85.44 | 78.92 | | Jos | 42.20 | 49.10 | 44.20 | 36.10 | 42.15 | 50.29 | 56.99 | | Kaduna | 30.99 | 33.72 | 47.10 | 52.76 | 39.25 | 34.14 | 37.69 | | Kano | 61.98 | 64.54 | 69.45 | 68.76 | 66.28 | 68.51 | 64.37 | | Port Harcourt | 64.53 | 66.24 | 64.09 | 65.47 | 65.06 | 62.59 | 50.81 | | Yola | 56.00 | 47.57 | 55.01 | 55.91 | 53.71 | 51.63 | 58.61 | | Total | 67.36 | 70.87 | 72.23 | 73.33 | 71.02 | 69.42 | 66.50 | | Average | 63.15 | 65.66 | 66.81 | 68.21 | 65.72 | 64.63 | 63.01 | * * * Table C.3: Energy off-take performance, 2022 | DisCos | Jan-Jun 2022 | | | Jul-Dec 2022 | | | | --- | --- | --- | --- | --- | --- | --- | | Offtake(MWh/h) | MYTO share(MWh/h) | Variance(%) | Offtake(MWh/h) | PCC(MWh/h) | Variance(%) | | | Abuja | 417.30 | 415.34 | 0.43 | 474.18 | 424.22 | 11.78 | | Benin | 305.37 | 325.05 | -6.05 | 310.51 | 328.02 | -5.34 | | Eko | 334.35 | 397.28 | -15.84 | 378.85 | 337.94 | 12.11 | | Enugu | 310.07 | 325.05 | -4.61 | 286.46 | 320.67 | -10.67 | | Ibadan | 385.90 | 469.51 | -17.81 | 401.72 | 400.43 | 0.32 | | Ikeja | 445.98 | 541.74 | -17.68 | 485.63 | 481.78 | 0.80 | | Jos | 167.51 | 198.64 | -15.67 | 189.85 | 244.01 | -22.20 | | Kaduna | 246.09 | 288.93 | -14.83 | 235.73 | 228.74 | 3.06 | | Kano | 209.00 | 288.93 | -27.66 | 229.81 | 235.66 | -2.48 | | Port Harcourt | 218.95 | 234.76 | -6.73 | 242.90 | 249.51 | -2.65 | | Yola | 100.75 | 126.41 | -20.30 | 94.69 | 128.93 | -26.56 | | All DisCos | 3,141.09 | 3,611.63 | -13.03 | 3,330.33 | 3,379.91 | -1.47 | Table C.4: ATC&C losses performance, 2018-2022 | | 2022 | | 2021 | | 2020 | | 2019 | | 2018 | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 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 | 19.27 | 43.20 | 22.80 | 44.62 | 22.33 | 45.8 | 24 | 41.07 | 22.33 | 40.15 | | Benin | 17.37 | 51.73 | 21.71 | 53.96 | 23.91 | 55.41 | 31 | 50.52 | 23.91 | 53.24 | | Eko | 14.18 | 24.71 | 14.70 | 27.38 | 11.23 | 30.85 | 14 | 26.22 | 11.23 | 30.56 | | Enugu | 11.31 | 50.38 | 19.96 | 48.97 | 20.56 | 53.83 | 29 | 30.94 | 20.56 | 51.68 | | Ibadan | 15.47 | 48.16 | 18.55 | 53.33 | 19.67 | 56.74 | 25 | 47.74 | 19.67 | 49.96 | | Ikeja | 11.37 | 18.33 | 12.52 | 23.34 | 10.81 | 28.21 | 15 | 23.91 | 10.81 | 21.82 | | Jos | 27.27 | 68.22 | 35.98 | 65.02 | 39.12 | 67.79 | 44 | 60.4 | 39.12 | 69.61 | | Kaduna | 10.65 | 74.90 | 17.18 | 74.05 | 20.12 | 76.80 | 32 | 66.81 | 12.47 | 69.82 | | Kano | 15.85 | 53.61 | 18.65 | 48.94 | 22.06 | 50.78 | 29 | 43.72 | 22.06 | 51.47 | | Port Harcourt | 21.45 | 47.30 | 25.85 | 51.76 | 29.70 | 60.80 | 37 | 61.62 | 29.70 | 63.66 | | Yola | 64.12 | 69.50 | 29.44 | 75.96 | 23.71 | 73.24 | 28 | 65.08 | 23.71 | 68.42 | | All DisCos: MYTO Level | 20.75 | | 21.58 | | 22.11 | | 26 | | 20 | | | ATC&C Losses | - | 45.46 | | 46.85 | | 50.57 | | 43.85 | | 47.85 | | ATC Losses | - | 23.21 | | 23.43 | | 25.67 | | 17.23 | | 19.81 | | C Losses | - | 28.98 | | 30.58 | | 33.50 | | 32.16 | | 34.97 | Notes of the table: 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 * * * Key Statistics Table C.5: NBET and MO invoice to DisCos, 2018-2022 | | Jan22 | Feb22 | Mar22 | Apr22 | May22 | Jun22 | Jul22 | Aug22 | Sep22 | Oct22 | Nov22 | Dec22 | 2022 | 2021 | 2020 | 2019 | 2018 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | NBET Invoice | Amount in (¥'Billion) | | | | | | | | | | | | | | | | | | 8.85 | 8.24 | 8.06 | 8.27 | 7.85 | 7.09 | 9.29 | 9.40 | 9.87 | 10.46 | 11.03 | 11.21 | 109.61 | 101.33 | 89.91 | 87.88 | 76.66 | | | Abuja | 8.69 | 6.13 | 6.26 | 5.70 | 5.93 | 5.65 | 6.04 | 6.25 | 6.47 | 5.38 | 6.81 | 6.59 | 74.89 | 72.87 | 64.93 | 54.28 | 53.34 | | Benin | 8.02 | 7.12 | 6.60 | 6.80 | 7.25 | 6.26 | 6.64 | 7.85 | 6.75 | 6.41 | 6.92 | 7.75 | 84.43 | 93.01 | 84.12 | 77.99 | 68.08 | | Eko | 6.77 | 6.42 | 6.33 | 5.80 | 5.80 | 5.53 | 6.31 | 6.41 | 6.06 | 5.98 | 6.50 | 7.09 | 75.01 | 75.05 | 62.88 | 52.94 | 47.69 | | Enugu | 9.41 | 8.27 | 7.97 | 8.08 | 8.02 | 7.17 | 8.36 | 8.23 | 8.25 | 8.23 | 8.98 | 9.50 | 100.45 | 108.07 | 97.72 | 83.21 | 72.91 | | Ibadan | 10.81 | 9.62 | 9.19 | 9.18 | 9.45 | 8.24 | 9.10 | 9.78 | 10.32 | 9.67 | 10.72 | 11.83 | 117.90 | 122.51 | 107.19 | 89.52 | 74.41 | | Ikeja | 10.81 | 9.62 | 9.19 | 9.18 | 9.45 | 8.24 | 9.10 | 9.78 | 10.32 | 9.67 | 10.72 | 11.83 | 117.90 | 122.51 | 107.19 | 89.52 | 74.41 | | Jos | 3.79 | 3.54 | 3.63 | 3.53 | 3.51 | 3.24 | 3.64 | 3.72 | 3.88 | 4.15 | 4.27 | 4.66 | 45.56 | 41.33 | 37.44 | 29.46 | 26.36 | | Kaduna | 5.70 | 5.22 | 5.15 | 5.24 | 4.95 | 4.50 | 4.44 | 4.80 | 4.83 | 5.09 | 5.12 | 5.38 | 60.44 | 63.97 | 58.34 | 45.69 | 44.65 | | Kano | 5.47 | 5.00 | 4.55 | 4.77 | 4.40 | 4.04 | 5.39 | 4.72 | 4.56 | 5.06 | 5.21 | 5.41 | 57.59 | 58.66 | 52.43 | 41.27 | 41.65 | Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. * * * Table C.6: Remittances to NBET and MO by DisCos, 2018-2022 | | Jan22 | Feb22 | Mar22 | Apr22 | May22 | Jun22 | Jul22 | Aug22 | Sep22 | Oct22 | Nov22 | Dec22 | 2022 | 2021 | 2020 | 2019 | 2018 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Remittances to NBET | Amount in(N'Billion) | | | | | | | | | | | | | | | | | | Abuja | 6.18 | 6.98 | 6.00 | 6.51 | 5.74 | 6.52 | 9.04 | 7.76 | 7.90 | 6.91 | 6.94 | 6.60 | 83.07 | 64.90 | 34.23 | 34.98 | 26.03 | | Benin | 1.96 | 3.27 | 2.57 | 2.93 | 2.44 | 2.80 | 4.81 | 4.37 | 5.38 | 5.49 | 5.45 | 5.14 | 46.64 | 33.09 | 19.70 | 14.10 | 16.15 | | Eko | 6.75 | 6.38 | 5.43 | 6.08 | 6.46 | 5.20 | 6.64 | 7.74 | 5.63 | 5.29 | 5.01 | 5.75 | 72.37 | 64.12 | 35.60 | 31.92 | 26.30 | | Enugu | 3.52 | 3.55 | 2.65 | 3.10 | 2.47 | 2.93 | 5.97 | 5.68 | 5.01 | 5.38 | 5.52 | 5.29 | 51.08 | 42.26 | 19.74 | 12.45 | 16.53 | | Ibadan | 4.45 | 3.58 | 3.12 | 4.44 | 3.06 | 3.70 | 6.92 | 6.07 | 6.89 | 7.83 | 6.86 | 7.27 | 64.18 | 53.36 | 30.31 | 22.74 | 23.95 | | Ikeja | 10.09 | 8.04 | 7.37 | 9.18 | 4.70 | 6.89 | 9.10 | 9.75 | 9.99 | 9.34 | 8.77 | 9.72 | 102.95 | 93.37 | 47.99 | 34.37 | 31.15 | | Jos | 1.10 | 1.11 | 1.07 | 1.39 | 0.71 | 1.23 | 2.68 | 2.38 | 2.52 | 2.41 | 2.32 | 2.16 | 21.05 | 13.13 | 4.66 | 2.12 | 2.38 | | Kaduna | 0.69 | 0.48 | 0.20 | 0.68 | 0.20 | 0.38 | 1.74 | 1.90 | 0.84 | 1.17 | 1.11 | 0.72 | 10.11 | 14.28 | 12.42 | 6.92 | 6.20 | | Kano | 2.44 | 2.37 | 1.53 | 2.57 | 1.58 | 1.83 | 2.79 | 1.46 | 3.12 | 2.56 | 2.30 | 3.15 | 27.72 | 31.72 | 13.02 | 10.20 | 6.66 | | Port Harcourt | 1.35 | 4.09 | 1.84 | 2.43 | 2.98 | 2.00 | 3.14 | 3.12 | 2.28 | 3.04 | 3.08 | 2.60 | 31.96 | 24.62 | 8.93 | 8.55 | 7.61 | | Yola | 0.34 | 0.23 | - | 0.24 | 0.21 | - | 0.20 | 0.20 | 0.21 | 0.22 | 0.23 | 0.22 | 2.31 | 2.96 | 2.76 | 2.99 | 2.44 | Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. * * * Table C.7: Annual shortfalls to NBET and MO by DisCos, 2018-2022 | | Jan22 | Feb22 | Mar22 | Apr22 | May22 | Jun22 | Jul22 | Aug22 | Sep22 | Oct22 | Nov22 | Dec22 | 2022 | 2021 | 2020 | 2019 | 2018 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Shortfalls toNBET | Amount in(N'Billion) | | | | | | | | | | | | | | | | | | Abuja | -2.66 | -1.26 | -2.06 | -1.77 | -2.11 | -5.72 | -2.48 | -1.64 | -1.98 | -3.55 | -4.09 | -4.61 | -26.54 | -36.43 | -55.68 | -52.89 | -50.6 | | Benin | -4.71 | -2.26 | -3.69 | -2.77 | -3.49 | -2.85 | -1.23 | -1.88 | -1.09 | -8.90 | -1.36 | -1.44 | -28.26 | -39.77 | -45.22 | -40.18 | -37.20 | | Eko | -1.27 | -7.90 | -1.17 | -7.12 | -7.94 | -1.06 | -0.02 | -1.03 | -1.12 | -1.12 | -1.91 | -2.00 | -12.06 | -28.89 | -48.52 | -46.07 | -41.78 | | Enugo | -3.25 | -2.87 | -3.69 | -2.70 | -3.32 | -2.60 | -3.44 | -0.73 | -1.04 | -6.00 | -9.81 | -1.80 | -23.93 | -32.79 | -43.14 | -40.49 | -31.16 | | Ibadan | -4.96 | -4.68 | -4.85 | -3.65 | -4.96 | -3.47 | -1.44 | -0.22 | -1.35 | -4.01 | -2.13 | -2.23 | -36.27 | -54.72 | -67.41 | -60.47 | -48.95 | | Ikejia | -0.71 | -1.58 | -1.81 | -0.03 | -4.76 | -1.35 | 0.00 | -3.23 | -3.27 | -3.27 | -1.94 | -2.11 | -14.95 | -29.13 | -59.20 | -55.14 | -43.26 | | Jos | -2.69 | -2.43 | -2.56 | -2.14 | -2.79 | -2.01 | -9.59 | -1.38 | -1.36 | -1.73 | -1.95 | -2.50 | -24.51 | -28.20 | -32.78 | -27.34 | -23.99 | | Kaduna | -5.01 | -4.74 | -4.95 | -4.55 | -4.74 | -4.12 | -2.70 | -2.94 | -3.98 | -3.92 | -4.01 | -4.66 | -50.33 | -49.69 | -45.92 | -38.77 | -38.45 | | Kano | -3.03 | -2.63 | -3.02 | -2.20 | -2.82 | -2.21 | -1.61 | -3.26 | -1.44 | -2.49 | -2.91 | -2.26 | -29.87 | -26.94 | -39.41 | -31.07 | -34.98 | | Port Harcourt | -3.17 | -4.60 | -2.62 | -1.77 | -1.18 | -2.06 | -2.00 | -1.86 | -2.79 | -1.92 | -2.21 | -3.27 | -25.32 | -29.66 | -39.46 | -37.22 | -33.48 | Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operators respectively. Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operators respectively. * * * Table C.8: Market invoice, remittance and shortfall by DisCos, 2018-2022 \| \| Invoice (万亿) \| \| \| \| \| Remittances (万亿) \| \| \| \| \| \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \| DisCos \| 2022 \| 2021 \| 2020 \| 2019 \| 2018 \| 2022 \| 2021 \| 2020 \| 2019 \| 2018 \| \| Abuja \| 118.96 \| 126.93 \| 109.57 \| 102.99 \| 90.62 \| 100.53 \| 92.68 \| 50.91 \| 46.07 \| 30.53 \| \| Benin \| 78.00 \| 93.08 \| 78.44 \| 63.61 \| 63.06 \| 57.01 \| 48.32 \| 33.34 \| 21.19 \| 21.23 \| \| Eko \| 89.64 \| 116.44 \| 102.14 \| 91.37 \| 80.49 \| 87.55 \| 87.05 \| 53.58 \| 43.94 \| 35.09 \| \| Enugu \| 82.33 \| 95.47 \| 75.96 \| 62.03 \| 56.39 \| 61.10 \| 58.32 \| 32.81 \| 19.21 \| 19.18 \| \| Ibadan \| 101.76 \| 137.1 \| 118.53 \| 97.50 \| 86.24 \| 82.72 \| 74.61 \| 50.58 \| 33.98 \| 28.28 \| \| Ikeja \| 123.19 \| 154.67 \| 128.80 \| 104.82 \| 87.92 \| 122.90 \| 116.88 \| 69.60 \| 47.72 \| 39.22 \| \| Jos \| 38.53 \| 53.65 \| 44.84 \| 34.52 \| 31.18 \| 27.33 \| 22.34 \| 11.70 \| 5.70 \| 3.13 \| \| Kaduna \| 60.65 \| 79.82 \| 70.20 \| 53.58 \| 52.91 \| 13.39 \| 19.3 \| 21.64 \| 12.62 \| 7.69 \| \| Kano \| 58.61 \| 71.5 \| 62.52 \| 48.38 \| 49.13 \| 34.18 \| 40.22 \| 22.21 \| 15.12 \| 7.96 \| \| Port Harcourt \| 57.76 \| 67.57 \| 58.53 \| 53.63 \| 48.59 \| 39.18 \| 34.92 \| 18.39 \| 14.28 \| 9.36 \| \| Yola \| 6.81 \| 31.59 \| 33.20 \| 31.07 \| 24.47 \| 6.37 \| 4.4 \| 5.59 \| 6.88 \| 5.03 \| \| Total \| 816.25 \| 1,027.83 \| 882.73 \| 743.50 \| 670.98 \| 632.25 \| 599.04 \| 370.34 \| 266.71 \| 206.68 \| \| Average \| 74.20 \| 93.44 \| 80.25 \| 67.59 \| 61.00 \| 57.48 \| 54.46 \| 33.67 \| 24.25 \| 18.79 \| | DisCos | Shortfalls(#’Billion) | | | | | Remittance Performance(%) | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2022 | 2021 | 2020 | 2019 | 2018 | 2022 | 2021 | 2020 | 2019 | 2018 | | | Abuja | 18.43 | -34.25 | 58.66 | 56.92 | 60.10 | 84.51 | 73.02 | 46.46 | 44.73 | 33.67 | | Benin | 21.00 | -44.75 | 45.10 | 42.42 | 41.83 | 73.08 | 51.91 | 42.51 | 33.31 | 33.67 | | Eko | 2.09 | -29.39 | 48.56 | 47.43 | 45.40 | 97.67 | 74.76 | 52.46 | 48.09 | 43.59 | | Enugu | 21.23 | -37.15 | 43.15 | 42.82 | 37.21 | 74.21 | 61.09 | 43.20 | 30.96 | 34.01 | | Ibadan | 19.04 | -62.51 | 67.96 | 63.52 | 57.96 | 81.29 | 54.42 | 42.67 | 34.85 | 32.79 | | Ikeja | 0.29 | -37.78 | 59.21 | 57.10 | 48.70 | 99.76 | 75.57 | 54.03 | 45.52 | 44.61 | | Jos | 11.20 | -31.31 | 33.14 | 28.82 | 28.05 | 70.93 | 41.64 | 26.09 | 16.50 | 10.04 | | Kaduna | 47.27 | -60.53 | 48.57 | 40.96 | 45.22 | 22.07 | 24.18 | 30.82 | 23.56 | 14.53 | | Kano | 24.43 | -31.29 | 40.31 | 33.25 | 41.17 | 58.32 | 56.25 | 35.52 | 31.26 | 16.19 | | Port Harcourt | 18.57 | -32.66 | 40.14 | 39.35 | 39.23 | 67.84 | 51.68 | 31.42 | 26.63 | 19.26 | | Yola | 0.44 | -27.18 | 27.61 | 24.19 | 19.43 | 93.51 | 13.93 | 16.83 | 22.14 | 20.56 | | Total | 184.00 | -428.79 | 512.39 | 476.79 | 464.30 | 77.46 | 58.28 | 41.95 | 35.87 | 30.80 | | Average | 16.73 | -38.98 | 46.58 | 43.34 | 42.21 | 74.84 | 58.28 | 38.36 | 32.51 | 27.54 | Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. Notes of the table: 1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. 2. 2022 market data is based on MRO. 3. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively. 4. 2022 market data is based on MRO. * * * Table C.9: Collection and remittance performances by DisCos, 2019-2022 | | Collection Efficiency(%) | | | | Percentage Point Change in Collection Efficiency(pp) | | | Remittance Performance(%) | | | | Percentage point Change in Remittance Performance(pp) | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2022 | 2021 | 2020 | 2019 | 2022-21 | 2021-20 | 2020-19 | 2022 | 2021 | 2020 | 2019 | 2022-21 | 2021-20 | 2020-19 | | Abuja | 82.87 | 83.63 | 88.86 | 75.64 | -0.76 | -5.23 | 13.23 | 84.51 | 73.02 | 46.46 | 44.73 | 11.49 | 26.56 | 1.73 | | Benin | 57.26 | 54.98 | 53.11 | 56.99 | 2.28 | 1.88 | -3.88 | 73.08 | 51.92 | 42.51 | 33.31 | 21.16 | 9.41 | 9.20 | | Eko | 84.45 | 83.02 | 78.62 | 83.33 | 1.44 | 4.39 | -4.71 | 97.67 | 74.76 | 52.46 | 48.09 | 22.91 | 22.3 | 4.37 | | Enugu | 69.99 | 71.25 | 64.08 | 72.63 | -1.26 | 7.17 | -5.11 | 74.21 | 61.09 | 43.20 | 30.96 | 13.12 | 17.89 | 12.24 | | Ibadan | 69.67 | 65.39 | 61.09 | 62.93 | 4.27 | 4.30 | -1.84 | 81.29 | 54.41 | 42.67 | 34.85 | 26.88 | 11.74 | 7.82 | | Ikeja | 92.27 | 85.44 | 78.92 | 86.33 | 6.82 | 6.52 | -7.41 | 99.76 | 75.57 | 54.03 | 45.52 | 24.19 | 21.54 | 8.51 | | Jos | 45.15 | 50.29 | 56.99 | 55.21 | -8.13 | -6.70 | 1.78 | 70.93 | 41.64 | 26.09 | 16.50 | 29.29 | 15.55 | 9.59 | | Kaduna | 39.25 | 34.14 | 37.69 | 40.80 | 5.11 | -3.55 | -3.11 | 22.07 | 24.18 | 30.82 | 23.56 | -2.11 | -6.64 | 7.26 | | Kano | 66.28 | 68.51 | 64.37 | 68.51 | -2.23 | 4.14 | -4.14 | 58.32 | 56.24 | 35.52 | 31.26 | 2.08 | 20.72 | 4.26 | | PH | 65.06 | 62.59 | 50.81 | 51.27 | 2.46 | 11.79 | -0.47 | 67.84 | 51.68 | 31.42 | 26.63 | 16.16 | 20.26 | 4.79 | | Yola | 53.70 | 51.63 | 58.61 | 51.29 | 2.07 | -6.97 | 7.39 | 93.51 | 13.93 | 16.83 | 22.14 | 79.58 | -2.9 | -5.31 | | Total | 71.02 | 69.42 | 66.50 | 67.84 | 1.60 | 2.92 | -1.34 | 77.46 | 58.28 | 41.95 | 35.87 | 19.18 | 16.33 | 6.08 | * * * D. Licence, Permit and Certification Table D.1: Licences issued and renewed by the Commission in 2022 | S/N | Applicants | Capacity(MW) | LicenceType | Location | FuelType | | --- | --- | --- | --- | --- | --- | | A. | New Issue | | | | | | 1 | Daybreak Power Solutions Nigeria Limited | 1.50 | Off-Grid Generation | NBC Idu, Abuja | Solar | | 2 | Daybreak Power Solutions Nigeria Limited | 1.60 | Off-Grid Generation | NBC Asejire, Oyo | Solar | | 3 | Daybreak Power Solutions Nigeria Limited | 3.50 | Off-grid generation | NBC Challawa, Kano | Solar | | 4 | CKS Power Nigeria Limited | 5.00 | Embedded generation | Yabo, Sokoto | Gas | | 5 | Globeleq Power Solutions Limited | 5.50 | Off-Grid Generation | NBC Port Harcourt | Gas | | 6 | Daybreak Power Solutions Limited | 1.74 | Off-grid generation | Kudenda, Kaduna | Solar | | 7 | Daybreak Power Solutions Limited | 6.00 | Off-Grid Generation | 7UP Ikeja, Lagos | Solar | | 8 | Daybreak Power Solutions Limited | 2.00 | Off-Grid Generation | 1A Lateef Jakande Road, Ikeja, Lagos | Solar | | 9 | Daybreak Power Solutions Limited | 2.00 | Off-Grid Generation | 1B Lateef Jakande Road, Ikeja | Solar | | 10 | Genco Sunrise Limited | 1.50 | Embedded generation | Sunrise Hills Estate, Asokoro | Diesel | | 11 | Electro Sunrise Limited | NA | Independent distribution | Sunrise Hills Estate, Asokoro | NA | | 12 | Commercio Electricity Exchange Limited | NA | Trading Licence | Lagos | NA | | 13 | Calabar Generation Company Limited | 561.00 | On-Grid Generation/Amendment | Odukpani, Calabar | Gas | | 14 | Cross Boundary Energy Nigeria Limited | 4.00 | Off-Grid Generation | Ama Brewery | Gas | | 15 | Haske Solar Company Limited | 10.00 | Embedded Generation | Challawa, Kumbotso | Solar | | 16 | Daybreak Power Solutions Limited | 1.60 | Off-Grid Generation | NBC Benin (A), Edo | Solar | | 17 | Daybreak Power Solutions Limited | 2.00 | Off-Grid Generation | NBC Benin (B), Edo | Solar | | 18 | Daybreak Power Solutions Limited | 2.10 | Off-Grid Generation | NBC Owerri, Imo | Solar | | 19 | Daybreak Power Solutions Limited | 1.75 | Off-Grid Generation | NBC Port Harcourt | Solar | | 20 | Daybreak Power Solutions Limited | 3.50 | Off-Grid Generation | NBC Badagry | Solar | | 21 | Victoria Island Power Limited | 30.00 | Embedded Generation | Victory Island, Lagos | Gas | | 22 | Ecof Nigeria Limited | NA | Trading Licence | Kaduna | NA | | 23 | Ibom Utility Company Limited | NA | IEDN\* | Ikot Abasi, Akwa Ibom | NA | | 24 | MEPP Limited | 50.00 | On-grid | Baga road,Maiduguri,Borno | solar | | 25 | Quest Oil&Engineering Services Ltd | 6.50 | Off-grid | Nigerian BottlingCompany,Idu,FCT | Solar | | B. | Renewal | | | | | | 26 | Olorunshogo Power GenerationCompany Limited | 750.00 | Renewal of on-grid generation | Olorunshogo,Ogun | Gas | | 27 | Ogorode Power GenerationCompany Limited | 450.00 | Renewal of on-grid generation | Sapele,Delta | Gas | | 28 | Alaoji Generation Company Limited | 1070.00 | Renewal of On-GridGeneration | Alaoji,Abia | Gas | | 29 | Tower Power Utility Limited | 20.00 | off-grid generation | Ota,Ogun | Gas | | C. | Licence Transferred | | | | | | 30 | Wapsila Nigeria Limited | 310.00 | Bilateral saleagreement withLord's MintTechnologies Ltd | Ota,Ogun | Gas | | 31 | Transfer of Licence issued toStandard Metallurgical CompanyLimited to Taopex Energy ServicesCompany Limited | 90.00 | on-grid generation | Sagamu,Ogun | Gas | Notes of the table: IEDN is an acronym for an Independent Electricity Distribution Network Table D.2: Captive power generation Permits granted by the Commission in 2022 S/N Applicants Location | S/N | Applicants | Location | Capacity(MW) | | --- | --- | --- | --- | | A. | Permit Issued | | | | 1 | Speciality Pulp and Paper Company Limited | Ijebu Ode, Ogun | 3.50 | | 2 | African Natural Resources & Mines Ltd | Gujeni, Abuja | 50.00 | | 3 | Nigerian Breweries Plc | Aba Malting Plant | 7.97 | | 4 | Nigerian Breweries Plc | Ibadan Breweries | 7.97 | | 5 | Nigerian Breweries Plc | Aba Malting Plant | 7.20 | | 6 | Nigerian Breweries Plc | Ama Bwereries | 10.59 | | 7 | Nigerian Breweries Plc | Aba Bwereries | 5.60 | | 8 | Nigerian Breweries Plc | Awo Omama Breweries | 4.40 | | 9 | Nigerian Breweries Plc | Ijebu-Ode, Ogun | 5.80 | | 10 | Greenville Oil& Gas Limited(renewal) | Emuoha,Rivers | 80.00 | | 11 | Duport Midstream Company Limited | Egbokor,Edo | 2.00 | | 12 | Julius Berger Nigeria Plc | Utako,FCT | 3.00 | | 13 | Julius Berger Nigeria Plc | Idu,FCT | 3.00 | | 14 | Mobil Producing Nigeria Unlimited | East Area Project Ibeno,Akwa Ibom | 15.00 | | 15 | The Shell Petroleum Development Co.Nig.Ltd | Ogbotobo AG-Booster-Station | 3.98 | | 16 | The Shell Petroleum Development Co.Nig.Ltd | Tunu CPF | 15.86 | Nigerian Electricity Regulatory Commission * * * Key Statistics | S/N | Applicants | Location | Capacity(MW) | | --- | --- | --- | --- | | 17 | The Shell Petroleum Development Co. Nig. Ltd | Opukushi AG Booster StatioBenisede AG | 4.28 | | 18 | The Shell Petroleum Development Co. Nig. Ltd | Booster Station | 4.29 | | 19 | The Shell Petroleum Development Co. Nig. Ltd | Sea Eagle FPSO | 50.00 | | 20 | The Shell Petroleum Development Co. Nig. Ltd | Kolo Creek Oil & NAG Manifold | 6.00 | | 21 | The Shell Petroleum Development Co. Nig. Ltd | Okoloma | 2.00 | | 22 | Niger Mills Limited | Murtala Muhammad Highway, Calabar | 8.80 | | 23 | Mikano International Limited | Akinwande Street, Off Badagry Express Way | 22.90 | | 24 | African Natural Resources & Mines Limited | Liverpool Road, Apapa, Lagos | 50.00 | | 25 | Premier Polypack Limited | Plot 1 Block A Gbagada Industrial Estate Lagos | 3.43 | | 26 | Wacot Rice Limited | Km 10 Argungu Sokoto Expressway Kebbi | 3.40 | | 27 | Cadbury Nigeria Plc | Lateef Jakande, Agidingbi, Ikeja, Lagos | 5.80 | | 28 | Niger Mills Company Limited | Murtala Mohammed Highway, Calabar | 8.80 | | 29 | Chi Limited | Ajao, Estate, Lagos | 23.59 | | 30 | Nigerian Breweries Plc | Aba, Abia | 7.97 | | 31 | Nigerian Breweries Plc | New Ife Road, Ibadan | 7.20 | | 32 | Nigerian Breweries Plc | Mile Corner Ama-Eke, Ngwo Enugu | 5.60 | | 33 | Nigerian Breweries Plc | Ama, Abua | 10.80 | | 34 | Nigerian Breweries Plc | Awo-Omama | 4.40 | | 35 | Nigerian Breweries Plc | Ijebu Ode, Ogun | 5.80 | CPG is an acronym for Captive Power Generation | S/N | Name | Location | Capacity(Kw) | | --- | --- | --- | --- | | | A. Approved Registration | | | | 1 | Husk Power Energy Systems Nigeria Limited | Gidan Buba,Lafia,Nassarawa | 100 | | 2 | Husk Power Energy Systems Nigeria Limited | Kiguna,Lafia,Nassarawa | 100 | | 3 | Husk Power Energy Systems Nigeria Limited | Igbabo,Doma,Nassarawa | 122 | | 4 | A4&T Power Solutions Limited | Laoso,Ondo West,Ondo | 97 | | 5 | Havenhill Synergy Limited | Kigbe,Kwali,FCT | 20 | | 6 | Rivet Engineering Limited | Bolorunduro,Ekiti South-West,Ekiti State | 50 | | 7 | Rivet Engineering Limited | Aba Ekan,Ise/Orun,Ekiti | 40 | | 8 | Rivet Engineering Limited | Oriokuta,Ekiti West,Ekiti | 40 | | 9 | Rivet Engineering Limited | Omuaran,Ekiti South-Wes,Ekiti | 40 | | 10 | Rivet Engineering Limited | Ilupeju Edetedo,Ekiti West,Ekiti | 100 | | 11 | News Engineering Nigeria Limited | Inname,Binji,Sokoto, | 40 | | 12 | Steven International Company Limited | Alapa,Ilado,Ibarapa East,Oyo | 100 | | 13 | Leading Diagonal Engineering Limited | Maluri,Turmi-Maluri,Fika,Yobe | 100 | | 14 | Power Gen Nigeria Assets Limited | Jikangi,Lavun,Niger | 86 | | 15 | Power Gen Nigeria Assets Limited | Kpanje,Lavun,Niger | 86 | | 16 | Power Gen Nigeria Assets Limited | Sa’achi,Lavun,Niger | 106 | | 17 | Power Gen Nigeria Assets Limited | Lagun,Lavun,Niger | 10 | * * * | S/N | Name | Location | Capacity (Kw) | | --- | --- | --- | --- | | 18 | Power Gen Nigeria Assets Limited | Sosa, Lavun, Niger | 106 | | 19 | Power Gen Nigeria Assets Limited | Ebangi, Lavun, Niger | 106 | | 20 | Power Gen Nigeria Assets Limited | Gbade, Lavun, Niger | 186 | | 21 | Power Gen Nigeria Assets Limited | Dukugi, Lavun, Niger | 256 | | 22 | Power Gen Nigeria Assets Limited | Danchitagi, Lavun, Niger | 330 | | 23 | Power Gen Nigeria Assets Limited | Toto, Toto, Nasarawa | 362 | | 24 | ABSI Building System International Limited | Abuke Oluwo, Owode, Ogun | 80 | | 25 | Decrown West Africa Company Limited | Sule Camp, Ovia Southwest, Edo | 100 | | 26 | Husk Power Energy Systems Nigeria | Acura, Lafia, Nassarawa | 100 | | 27 | Darway Coast Nigeria Limited | Odiopiti, Ahoada West, Rivers | 71 | | 28 | Darway Coast Nigeria Limited | Ekowe, Southern Ijaw, Bayelsa | 99 | | 29 | Darway Coast Nigeria Limited | Odeke, Ibaji, Kogi | 88 | | 30 | Darway Coast Nigeria Limited | Amala 2, Ngor Okpala, Imo | 99 | | 31 | Darway Coast Nigeria Limited | Okumbiri, Sagbama, Bayelsa | 71 | | 32 | Darway Coast Nigeria Limited | Umudora, Anambra West, Anambra | 99 | | 33 | Darway Coast Nigeria Limited | Emirikpoko, Abua/Odual, Rivers | 78 | | 34 | Darway Coast Nigeria Limited | Oroma-Ettii, Anambra West, Anambra | 99 | | 35 | Darway Coast Nigeria Limited | Umuwaaibu, Okigwe, Imo | 71 | | 36 | Darway Coast Nigeria Limited | Emago-Kugbo, Abua/Odual, Rivers | 99 | | 37 | Darway Coast Nigeria Limited | Amatolo, Sagbama, Bayelsa | 71 | | 38 | Darway Coast Nigeria Limited | Aked dei, Sagbama, Bayelsa | 99 | | 39 | Privida Power Limited | Sati-ikov, Ushongo Benue | 50 | | 40 | Privida Power Limited | Nyanikhume, Kwande, Benue | 50 | | 41 | Privida Power Limited | Ugbedomagwu, Igalamela Odolu, Kogi | 45 | | 42 | Privida Power Limited | Odamagu-Odo, Omala, Kogi | 8 | | 43 | Privida Power Limited | Ugbamaka, Ofu, Kogi | 45 | | 44 | Privida Power Limited | Kpnache Ozongulo, Bassa, Kogi | 55 | | 45 | Privida Power Limited | Ikem Ogugu, Olamaboro, Kogi | 60 | | 46 | Privida Power Limited | Igoti-lboko, Ofu, Kogi | 71 | | 47 | Privida Power Limited | Emonoji, Omala, Kogi | 15 | | 48 | Privida Power Limited | Emakpe, Igalamela Odolu, Kogi | 15 | | 49 | Privida Power Limited | Emagaba II, Olamaboro, Kogi | 71 | | 50 | Privida Power Limited | Ekelekwu, Igalamela Odolu, Kogi | 15 | | 51 | A4 & T Power Solutions | Orisunbare, Ondo East, Ondo State | 15 | | 52 | Husk power Limited | Rukubi, Doma, Nasarawa | 100 | | 53 | Triple E System Limited | Onirogbo, Odigbo, Ondo | 5 | | 54 | Ay Global Integrated Resource | Binjun Muza Bunji Sokota | 60 | | 55 | Maskh Limited Bauchi | Magarta Hos Gatour | 50 | | 56 | Maskh Limited Bauchi | Hakatafi Ganjuwa Bauchi | 30 | | 57 | Maskh Limited | Hakatafi, Ganjuwa, Bauchi | 30 | | 58 | Maskh Limited | Dunari, Itas Gadau, Bauchi | 30 | | 59 | Maskh Limited | Shagari Ganjuwa Bauchi | 30 | | 60 | Maskh Nigeria Limited | Mela dige, Itas Gadau, Bauchi | 50 | | 61 | A4 & T Power Solutions | Ilugha, Ondo West, Ondo | 96 | * * * S/N Name 64 Solad Tnt Power Solutions Limited 65 ACOB Lighting Tech Limited 66 ACOB Lighting Tech Limited 67 ACOB Lighting Tech Limited 68 ACOB Lighting Tech Limited 69 ECOF Kaduna Limited 70 Havenhill Synergy Limited B. Approved Permits 71 Ventura Logistic Services Limited 72 Zanoplus Energy Limited 73 Blue Camel Energy Limited 74 Husk Power Energy Systems Nigeria Limited 75 Privida Power Limited 76 Privida Power Limited 77 Privida Power Limited 78 Privida Power Limited 79 Privida Power Limited 80 Privida Power Limited 81 Privida Power Limited 82 Privida Power Limited 83 Renewvia Solar Nigeria Limited 84 Renewvia Solar Nigeria Limited 85 Renewvia Solar Nigeria Limited 86 Renewvia Solar Nigeria Limited 87 Renewvia Solar Nigeria Limited 88 Engie Energy Access 89 Husk Power Limited 90 Husk Power Limited 91 Husk Power Limited 92 Husk Power Energy System Nig. Limited 93 Nayo Tropical Tech Limited 94 Nayo Tropical Tech Limited 95 Nayo Tropical Tech Limited 96 Nayo Tropical Tech Limited 97 Nayo Tropical Tech Limited Location Capacity (Kw) Ikenne Market, Ikenne, Ogun 58 Otu Costain Odigbo Ogun 70 Bolorunduro Odigbo Ogun 40 Mile 13 Ajebamijoko Odigbo Ogun 55 Adaja Odigbo Ogun 40 Chikaji Giwari Igabi Kaduna 42 Olokoto, Orile-north, Oyo 16 Mebiowa Okposi, Ohaozara LGA, Ebonyi State 98 Ifite-Ogwari, Aguata LGA, Anambra State 199 Kasuwan Magani, Kajuru, Kaduna 100 Husk Power Energy Systems Nigeria Limited Gidan Buba, Lafia, Nassarawa 110 Ugah,1, Lafia Nasarawa 220 Ugah,2, Lafia Nasarawa 240 Ochi- Adegbe, ofu Kogi 205 Alla Ejima, ofo, Kogi 230 Bagaji- Ofo Omola, Kogi 225 Azara, awe, Nasarawa 250 Otukpo, Apa, Benue 155 Adupi fzmimko, olamaboro, Kogi 170 Ekong – Anaku, Akampa, Cross River 60 Opu, Ikom, Cross River 14 Bendeghe Afi, Ikom, Cross River 18 Emereoke Eastern Obolo Akwa Ibom 28 Balep Ikom Cross River 9 Gbangba, Gbako, Niger 90 Kiguna, Lafia, Nassarawa 100 Sabon Gida, Lafia, Nassarawa 100 Akura, Lafia, Nassarawa 100 Husk Power Energy System Nig. Limited Yelwa Ediya Doma Nassarawa 100 Soba Mashegu Niger100 100 Sahon Rami Mashegu Niger 228 Sabon Rijiya Mashegu Niger 198 Bokani Mokwa Niger 150 Shafini Magama Niger 60 97 Nayo Tropical Tech Limited Shafini Magama Niger 60 98 Nayo Tropical Tech Limited Adogo Mallam Mashegu Niger 180 99 Wavelength-Commur pwr Networks Limited Imula Danre Ondo 132 100 Darway Coast Nig. Ltd Lokpowkwu 1, Uwunneochi Abia 449 101 Darway Coast Nig. Ltd Lokpowkwu 2, Uwunneochi Abia 449 102 Darway Coast Nig. Ltd Fule-Uma Ahoada West Rivers 449 103 Darway Coast Nig. Ltd Orwu-Ogita Teche Rivers 269 104 Darway Coast Nig. Ltd Umuoye Eteche Rivers 221 105 Darway Coast Nig. Ltd Akpokui lopai Niger 159 106 Husk Power Energy Systems Nigeria Ijajun Doma, Nasarawa 100 Limited Limited * * * Key Statistics | S/N | Name | Location | Capacity(Kw) | | --- | --- | --- | --- | | 107 | Husk Power Energy Systems Nigeria Limited | Fadama Bauna North,Lafia Nasarawa | 100 | | 108 | Powergen Nig Asset Limited | Araromi Olatapo Otiglo,Ondo | 224 | | 109 | Prado Power Limited | Maijaki Lapai,Niger | 45 | | 110 | Prado Power Limited | Lafia Kpada Lapai Niger | 50 | | 111 | Ceesolar Energy Limited | Abaribara Abayong Biase,Cross River | 22 | | 112 | Ventura Logistics Services Limited | Odege Okposi Ohaozora | 99 | | 113 | NXT Grid Nigeria Limited | Matari Soba Kaduna | 117 | | 114 | Darway Coast Nigeria Limited | Agbokim Etung Cross River | 130 | | 115 | Darway Coast Nigeria Limited | Abia Etung Cross River | 71 | | 116 | Darway Coast Nigeria Limited | Bendeghe Etung Cross River | 140 | | 117 | Darway Coast Nigeria Limited | Etomi Etung LGA Cross River | 115 | | 118 | Enaro Energy Mini Grid Limited | Ishoka phase 1,Mercy Land and Mercy phase 1 Estate,Ajobo Ipaja LGA,Lagos | 999 | Table D.4: Meter service providers certified by the Commission in 2022 | S/N | Applicant | Application Type | | --- | --- | --- | | 1 | Bajis Limited | Installer | | 2 | Nextsol Nigeria Limited | Installer | | 3 | Tis&P Dynamic Solutions Limited | Installer | | 4 | Jofebo Global Resources Limited | Installer | | 5 | Tinutten Nigeria Limited | Installer | | 6 | Watts&Grid Limited | Installer | | 7 | Global Hydro Cool Water Limited | Installer | | 8 | Information Management Technology Limited | Installer | | 9 | Felcon Multi Services Ltd | Installer | | 10 | Pro Engineering Innoveture Ltd | Installer | | 11 | Tee jay-Ade-Afolabi Electrical Enterprises | Installer | | 12 | Crestzone Resource Ltd | Installer | | 13 | Princaasi Integrated Services | Installer | | 14 | Specline Integrated Services Ltd | Installer | | 15 | Estervo System Company Limited | Installer | | 16 | Teejay Ade Afolabi Electrical Enterprises | Installer | | 17 | Panida Resources Ltd | Installer | | 18 | Damijosh Energy Limited | Installer | | 19 | HACOM Energy Limited | Installer | | 20 | Elvic Professional Services Ltd | Installer | | 21 | Estervo System Company Ltd | Installer | | 22 | Universal Integrated Power & Utility Services Ltd | Installer | | 23 | ASBA Synergy Concept Limited | Manufacturer | | 24 | Sandex Global Resources Limited | Manufacturer | | 25 | Payafrik International Limited | Manufacturer | | 26 | Chintec Electro Nig. Ltd | Manufacturer | | 27 | News Engineering Nig Ltd | Manufacturer | | 28 | Marks and Adams | Manufacturer | | 29 | Anietronic Limited | Manufacturer | * * * Key Statistics | 30 | Kobeissi Electrical & Mechanical Engineering Ltd | Manufacturer | | --- | --- | --- | | 31 | Morgan Energy Limited | Manufacturer | | 32 | Nigerian Energy Support Program | Importer | | 33 | Conlog Meter Solutions Nigeria Limited | Importer | | 34 | Sparkmeter West Africa Limited | Importer | | 35 | Q-Tech Nigeria Limited | Importer | | 36 | Utility Performance Limited | Vendor | | | MAP | DisCo | | 37 | Erasko Energy Ltd | Ikeja | | 38 | Mojec Meter Asset Management Company Ltd | Yola | | 39 | Volvo& Vision Business Ltd. | Yola | | 40 | Crest Hill Engineering Ltd | Yola | * * * E. Consumer Enlightenment, Metering and Complaints Table E.1: Customers registered, metered and unmetered, 2018-2022 Registered Customers (RC) by DisCos 2022/Q2 2022/Q3 | | Registered Customers(RC)byDisCos | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2022/Q1As at31March | | 2022/Q2As at30June | | 2022/Q3As at31September | | 2022/Q4As at31December | | | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | | | Abuja | 1,126,682 | 8.98 | 1,163,553 | 9.20 | 1,250,563 | 9.78 | 1,290,977 | 10.62 | | Benin | 1,652,722 | 13.18 | 1,665,886 | 13.18 | 1,680,279 | 13.14 | 1,186,922 | 9.77 | | Eko | 646,023 | 5.15 | 654,184 | 5.17 | 660,087 | 5.16 | 689,237 | 5.67 | | Enugu | 1,665,264 | 13.28 | 1,666,840 | 13.18 | 1,691,865 | 13.23 | 1,391,562 | 11.45 | | Ibadan | 2,121,325 | 16.91 | 2,141,404 | 16.94 | 2,176,067 | 17.01 | 2,220,266 | 18.27 | | Ikeja | 1,298,323 | 10.35 | 1,298,323 | 10.27 | 1,298,323 | 10.15 | 1,298,323 | 10.68 | | Jos | 692,474 | 5.52 | 696,211 | 5.51 | 699,455 | 5.47 | 705,249 | 5.80 | | Kaduna | 809,003 | 6.45 | 818,890 | 6.48 | 837,389 | 6.55 | 844,996 | 6.95 | | Kano | 884,710 | 7.05 | 884,799 | 7.00 | 838,091 | 6.55 | 849,311 | 6.99 | | Port Harcourt | 1,177,641 | 9.39 | 1,178,868 | 9.32 | 1,179,194 | 9.22 | 1,179,194 | 9.70 | | Yola | 468,414 | 3.63 | 474,672 | 3.75 | 480,584 | 3.76 | 496,069 | 4.08 | | Total | 12,542,581 | 100.00 | 12,643,630 | 100.00 | 12,791,897 | 100.00 | 12,152,106 | 100.00 | Metered Customers by DisCos 2022/Q2 2022/Q3 | DisCos | 2022/Q1As at 31 March | | 2022/Q2As at 30 June | | 2022/Q3As at 31 September | | 2022/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | | | Abuja | 675,098 | 14.24 | 710,870 | 14.51 | 726,553 | 14.47 | 757,458 | 14.75 | | Benin | 627,764 | 13.24 | 631,898 | 12.90 | 634,457 | 12.63 | 607,902 | 11.84 | | Eko | 353,232 | 7.45 | 360,152 | 7.35 | 372,113 | 7.41 | 391,398 | 7.62 | | Enugu | 551,703 | 11.64 | 559,810 | 11.43 | 571,700 | 11.38 | 537,408 | 10.47 | | Ibadan | 800,888 | 16.90 | 828,061 | 16.90 | 858,822 | 17.10 | 905,824 | 17.64 | | Ikeja | 645,862 | 13.63 | 686,705 | 14.02 | 713,508 | 14.21 | 763,680 | 14.87 | | Jos | 212,449 | 4.48 | 219,243 | 4.48 | 222,868 | 4.44 | 226,611 | 4.41 | | Kaduna | 179,482 | 3.79 | 192,848 | 3.94 | 196,599 | 3.91 | 197,442 | 3.85 | | Kano | 194,628 | 4.11 | 199,234 | 4.07 | 210,537 | 4.19 | 205,280 | 4.00 | | Port Harcourt | 414,951 | 8.75 | 425,784 | 8.69 | 435,670 | 8.68 | 445,174 | 8.67 | | Yola | 84,057 | 1.77 | 84,116 | 1.72 | 88 | 0.00 | 96,694 | 1.88 | | Total | 4,740,114 | 100.00 | 4,898,721 | 100.00 | 5,021,862 | 100.00 | 5,134,871 | 100.00 | Unmetered Customers by DisCos 2022/Q2 2022/Q3 | DisCos | 2022/Q1As at 31 March | | 2022/Q2As at 30 June | | 2022/Q3As at 31 September | | 2022/Q4As at December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | | | Abuja | 5.79 | 452,683 | 5.84 | 524,010 | 6.74 | 533,519 | 7.60 | | | Benin | 1,024,958 | 13.14 | 1,033,988 | 13.35 | 1,045,822 | 13.46 | 579,020 | 8.25 | | Eko | 292,791 | 3.75 | 294,032 | 3.80 | 287,974 | 3.71 | 297,839 | 4.24 | | Enugu | 1,113,561 | 14.27 | 1,107,030 | 14.29 | 1,120,165 | 14.42 | 854,154 | 12.17 | | Ibadan | 1,320,437 | 16.92 | 1,313,343 | 16.96 | 1,317,245 | 16.95 | 1,314,442 | 18.73 | | Ikeja | 652,461 | 8.36 | 611,618 | 7.90 | 584,815 | 7.53 | 534,643 | 7.62 | | Jos | 480,025 | 6.15 | 476,968 | 6.16 | 476,587 | 6.13 | 478,638 | 6.82 | | Kaduna | 629,521 | 8.07 | 626,042 | 8.08 | 640,790 | 8.25 | 647,554 | 9.23 | | Kano | 690,082 | 8.84 | 685,565 | 8.85 | 627,554 | 8.08 | 644,031 | 9.18 | | Port Harcourt | 762,690 | 9.77 | 753,084 | 9.72 | 743,524 | 9.57 | 734,020 | 10.46 | | Yola | 384,357 | 4.93 | 390,556 | 5.04 | 480,496 | 6.18 | 399,375 | 5.69 | | Total | 7,802,467 | 100.00 | 7,744,909 | 100.00 | 7,770,035 | 100.00 | 7,017,235 | 100.00 | * * * Table E.1 Cont’d: Customers registered, metered and unmetered, 2018-2022 | Registered Customers(RC)byDisCos | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2021/Q1As at31March | | 2021/Q2As at30June | | 2021/Q3As at31September | | 2021/Q4As at31December | | | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | | | Abuja | 1,533,401 | 14.23 | 1,550,062 | 14.02 | 1,575,421 | 12.32 | 1,581,212 | 12.29 | | Benin | 1,088,812 | 10.10 | 1,119,118 | 10.12 | 1,626,697 | 12.72 | 1,645,337 | 12.79 | | Eko | 572,328 | 5.31 | 608,252 | 5.50 | 611,941 | 4.79 | 614,370 | 4.77 | | Enugu | 1,250,159 | 11.60 | 1,284,548 | 11.62 | 1,660,084 | 12.98 | 1,663,429 | 12.93 | | Ibadan | 1,983,521 | 18.41 | 2,017,113 | 18.24 | 2,051,727 | 16.05 | 2,084,476 | 16.20 | | Ikeja | 1,143,431 | 10.61 | 1,183,171 | 10.70 | 1,298,323 | 10.16 | 1,298,323 | 10.09 | | Jos | 658,657 | 6.11 | 671,821 | 6.07 | 671,180 | 5.25 | 681,002 | 5.29 | | Kaduna | 736,213 | 6.83 | 743,506 | 6.72 | 780,793 | 6.11 | 791,430 | 6.15 | | Kano | 668,723 | 6.21 | 668,707 | 6.05 | 766,590 | 6.00 | 766,590 | 5.96 | | Port Harcourt | 705,038 | 6.54 | 766,755 | 6.93 | 1,288,197 | 10.08 | 1,288,197 | 10.01 | | Yola | 436,509 | 4.05 | 445,886 | 4.03 | 453,732 | 3.55 | 453,732 | 3.50 | | Total | 10,776,792 | 100.00 | 11,058,939 | 100.00 | 12,784,685 | 100.00 | 12,868,098 | 100.00 | Metered Customers by DisCos 2021/Q2 2021/Q3 | DisCos | 2021/Q1As at 31 March | | 2021/Q2As at 30 June | | 2021/Q3As at 31 September | | 2021/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | | | Abuja | 764,126 | 17.66 | 663,374 | 15.06 | 701,489 | 14.70 | 701,781 | 14.96 | | Benin | 574,918 | 13.29 | 601,977 | 13.67 | 597,819 | 12.53 | 622,429 | 13.27 | | Eko | 296,854 | 6.86 | 321,335 | 7.30 | 350,844 | 7.35 | 347,116 | 7.40 | | Enugu | 479,799 | 11.09 | 499,724 | 11.35 | 385,852 | 8.08 | 545,035 | 11.62 | | Ibadan | 672,783 | 15.55 | 761,094 | 17.28 | 723,718 | 15.16 | 782,105 | 16.67 | | Ikeja | 679,764 | 15.71 | 620,144 | 14.08 | 761,518 | 15.96 | 633,562 | 13.51 | | Jos | 130,770 | 3.02 | 160,204 | 3.64 | 253,310 | 5.31 | 212,265 | 4.52 | | Kaduna | 155,425 | 3.59 | 158,921 | 3.61 | 300,544 | 6.30 | 166,814 | 3.56 | | Kano | 131,113 | 3.03 | 147,866 | 3.36 | 231,427 | 4.85 | 190,834 | 4.07 | | Port Harcourt | 365,980 | 8.46 | 384,611 | 8.73 | 393,658 | 8.25 | 404,439 | 8.62 | | Yola | 75,089 | 1.74 | 84,763 | 1.92 | 72,727 | 1.52 | 84,774 | 1.81 | | Total | 4,326,621 | 100.00 | 4,404,013 | 100.00 | 4,772,906 | 100.00 | 4,691,154 | 100.00 | Unmetered Customers by DisCos 2021/Q3 2021/Q3 | DisCos | 2021/Q1As at 31 March | | 2021/Q3As at 30 June | | 2021/Q3As at 31 September | | 2021/Q4As of 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | | | 769,275 | 11.93 | 886,688 | 13.32 | 873,932 | 10.91 | 879,431 | 10.76 | | | Abuja | 769,275 | 11.93 | 886,688 | 13.32 | 873,932 | 10.91 | 879,431 | 10.76 | | Benin | 513,894 | 7.97 | 517,141 | 7.77 | 1,028,878 | 12.84 | 1,022,908 | 12.51 | | Eko | 275,474 | 4.27 | 286,917 | 4.31 | 261,097 | 3.26 | 267,254 | 3.27 | | Enugu | 770,360 | 11.94 | 784,824 | 11.79 | 1,274,232 | 15.90 | 1,118,394 | 13.68 | | Ibadan | 1,310,738 | 20.32 | 1,256,019 | 18.87 | 1,328,009 | 16.58 | 1,302,371 | 15.93 | | Ikeja | 463,667 | 7.19 | 563,027 | 8.46 | 536,805 | 6.70 | 664,761 | 8.13 | | Jos | 527,887 | 8.18 | 511,617 | 7.69 | 417,870 | 5.22 | 468,737 | 5.73 | | Kaduna | 580,788 | 9.00 | 584,585 | 8.78 | 480,249 | 5.99 | 624,616 | 7.64 | | Kano | 537,610 | 8.33 | 520,841 | 7.83 | 535,163 | 6.68 | 575,756 | 7.04 | | Port Harcourt | 339,058 | 5.26 | 382,144 | 5.74 | 894,539 | 11.17 | 883,758 | 10.81 | | Yola | 361,420 | 5.60 | 361,123 | 5.43 | 381,005 | 4.76 | 368,958 | 4.51 | | Total | 6,450,171 | 100.00 | 6,654,926 | 100.00 | 8,011,779 | 100.00 | 8,176,944 | 100.00 | * * * Table E.1 Cont’d: Customers registered, metered and unmetered, 2018-2022 | Registered Customers(RC)by DisCos | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2020/Q1As at 31 March | | 2020/Q2As at 30 June | | 2020/Q3As at 31 September | | 2020/Q4As at 31 December | | | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | | | Abuja | 1,271,563 | 12.14 | 1,277,921 | 12.15 | 1,468,404 | 12.40 | 1,468,404 | 12.40 | | Benin | 1,022,458 | 9.76 | 1,027,570 | 9.77 | 1,180,650 | 9.97 | 1,180,650 | 9.97 | | Eko | 518,192 | 4.95 | 520,783 | 4.95 | 541,560 | 4.57 | 541,560 | 4.57 | | Enugu | 1,100,292 | 10.50 | 1,105,793 | 10.52 | 1,183,093 | 9.99 | 1,183,093 | 9.99 | | Ibadan | 2,139,741 | 20.42 | 2,150,440 | 20.45 | 2,907,214 | 24.55 | 2,907,214 | 24.55 | | Ikeja | 1,145,622 | 10.93 | 1,145,622 | 10.89 | 1,145,622 | 9.67 | 1,145,622 | 9.67 | | Jos | 537,726 | 5.13 | 540,415 | 5.14 | 598,430 | 5.05 | 598,430 | 5.05 | | Kaduna | 675,059 | 6.44 | 678,434 | 6.45 | 721,436 | 6.09 | 721,436 | 6.09 | | Kano | 699,618 | 6.68 | 699,618 | 6.65 | 699,618 | 5.91 | 699,618 | 5.91 | | Port Harcourt | 985,782 | 9.41 | 985,782 | 9.37 | 985,782 | 8.32 | 985,782 | 8.32 | | Yola | 381,803 | 3.64 | 383,712 | 3.65 | 410,010 | 3.46 | 410,010 | 3.46 | | Total | 10,477,856 | 100.00 | 10,516,090 | 100.00 | 11,841,819 | 100.00 | 11,841,819 | 100.00 | Metered Customers by DisCos 2020/Q2 2020/Q3 | DisCos | 2020/Q1As at 31 March | | 2020/Q2As at 30 June | | 2020/Q3As at 31 September | | 2020/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | | | 670,485 | 52.73 | 671,822 | 52.57 | 707,534 | 48.18 | 707,534 | 48.18 | | | Benin | 554,443 | 54.23 | 555,174 | 54.03 | 571,600 | 48.41 | 571,600 | 48.41 | | Eko | 262,752 | 50.71 | 263,503 | 50.60 | 286,847 | 52.97 | 286,847 | 52.97 | | Enugu | 493,509 | 44.85 | 493,509 | 44.63 | 505,136 | 42.70 | 505,136 | 42.70 | | Ibadan | 794,136 | 37.11 | 794,136 | 36.93 | 807,573 | 27.78 | 807,573 | 27.78 | | Ikeja | 520,859 | 45.47 | 520,859 | 45.47 | 562,837 | 49.13 | 562,837 | 49.13 | | Jos | 170,989 | 31.80 | 170,989 | 31.64 | 172,627 | 28.85 | 172,627 | 28.85 | | Kaduna | 159,322 | 23.60 | 159,322 | 23.48 | 232,405 | 32.21 | 232,405 | 32.21 | | Kano | 147,682 | 21.11 | 147,682 | 21.11 | 352,493 | 50.38 | 352,493 | 50.38 | | Port Harcourt | 379,729 | 38.52 | 379,729 | 38.52 | 387,025 | 39.26 | 387,025 | 39.26 | | Yola | 78,034 | 20.44 | 78,034 | 20.34 | 80,114 | 19.54 | 80,114 | 19.54 | | Total | 4,231,940 | 40.39 | 4,234,759 | 40.27 | 4,666,191 | 39.40 | 4,666,191 | 39.40 | Unmetered Customers by DisCos 2020/Q2 2020/Q3 | DisCos | 2020/Q1As at 31 March | | 2020/Q2As at 30 June | | 2020/Q3As at 31 September | | 2020/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | | | Abuja | 601,078 | 47.27 | 606,099 | 47.43 | 760,870 | 51.82 | 760,870 | 51.82 | | Benin | 468,015 | 45.77 | 472,396 | 45.97 | 609,050 | 51.59 | 609,050 | 51.59 | | Eko | 255,440 | 49.29 | 257,280 | 49.40 | 254,713 | 47.03 | 254,713 | 47.03 | | Enugu | 606,783 | 55.15 | 612,284 | 55.37 | 677,957 | 57.30 | 677,957 | 57.30 | | Ibadan | 1,345,605 | 62.89 | 1,356,304 | 63.07 | 2,099,641 | 72.22 | 2,099,641 | 72.22 | | Ikeja | 624,763 | 54.53 | 624,763 | 54.53 | 582,785 | 50.87 | 582,785 | 50.87 | | Jos | 366,737 | 68.20 | 369,426 | 68.36 | 425,803 | 71.15 | 425,803 | 71.15 | | Kaduna | 515,737 | 76.40 | 519,112 | 76.52 | 489,031 | 67.79 | 489,031 | 67.79 | | Kano | 551,936 | 78.89 | 551,936 | 78.89 | 347,125 | 49.62 | 347,125 | 49.62 | | Port Harcourt | 606,053 | 61.48 | 606,053 | 61.48 | 598,757 | 60.74 | 598,757 | 60.74 | | Yola | 303,769 | 79.56 | 305,678 | 79.66 | 329,896 | 80.46 | 329,896 | 80.46 | | Total | 6,245,916 | 59.61 | 6,281,331 | 59.73 | 7,175,628 | 60.60 | 7,175,628 | 60.60 | * * * Table E.1 Cont’d: Customers registered, metered and unmetered, 2018-2022 | Registered Customers(RC)by DisCos | | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2019/Q1As at 31 March | | 2019/Q2As at 30 June | | 2019/Q3As at 31 September | | 2019/Q4As at 31 December | | | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | | | Abuja | 1,080,637 | 12.22 | 1,097,279 | 12.35 | 1,164,748 | 12.04 | 1,228,288 | 11.84 | | Benin | 970,000 | 10.97 | 970,000 | 10.92 | 1,001,821 | 10.36 | 1,022,458 | 9.86 | | Eko | 493,639 | 5.58 | 493,639 | 5.56 | 504,225 | 5.21 | 518,192 | 4.99 | | Enugu | 985,112 | 11.14 | 985,112 | 11.09 | 1,075,626 | 11.12 | 1,100,292 | 10.61 | | Ibadan | 1,779,751 | 20.13 | 1,779,751 | 20.04 | 2,090,781 | 21.61 | 2,139,741 | 20.62 | | Ikeja | 972,589 | 11.00 | 972,589 | 10.95 | 996,769 | 10.30 | 1,145,622 | 11.04 | | Jos | 486,198 | 5.50 | 510,198 | 5.74 | 512,108 | 5.29 | 537,726 | 5.18 | | Kaduna | 673,848 | 7.62 | 673,848 | 7.59 | 673,848 | 6.97 | 673,848 | 6.50 | | Kano | 529,114 | 5.98 | 529,114 | 5.96 | 516,947 | 5.34 | 689,304 | 6.64 | | Port Harcourt | 523,693 | 5.92 | 523,693 | 5.90 | 761,105 | 7.87 | 937,305 | 9.03 | | Yola | 346,220 | 3.92 | 346,220 | 3.90 | 376,751 | 3.89 | 381,803 | 3.68 | | Total | 8,840,801 | 100.00 | 8,881,443 | 100.00 | 9,674,729 | 100.00 | 10,374,579 | 100.00 | Metered Customers by DisCos 2019/Q2 2019/Q3 | DisCos | Metered Customers by DisCos | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2019/Q1As at 31 March | | 2019/Q2As at 30 June | | 2019/Q3As at 31 September | | 2019/Q4As at 31 December | | | | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | | | Abuja | 568,180 | 52.58 | 574,743 | 52.38 | 631,387 | 54.21 | 641,738 | 52.25 | | Benin | 548,261 | 56.52 | 548,261 | 56.52 | 549,211 | 54.82 | 553,394 | 54.12 | | Eko | 239,559 | 48.53 | 239,559 | 48.53 | 240,663 | 47.73 | 255,880 | 49.38 | | Enugu | 429,623 | 43.61 | 438,471 | 44.51 | 450,632 | 41.89 | 476,955 | 43.35 | | Ibadan | 687,652 | 38.64 | 687,652 | 38.64 | 689,123 | 32.96 | 783,878 | 36.63 | | Ikeja | 447,299 | 45.99 | 449,639 | 46.23 | 458,494 | 46.00 | 488,917 | 42.68 | | Jos | 170,409 | 35.05 | 170,492 | 33.42 | 170,492 | 33.29 | 170,522 | 31.71 | | Kaduna | 149,588 | 22.20 | 149,588 | 22.20 | 149,968 | 22.26 | 157,576 | 23.38 | | Kano | 126,539 | 23.92 | 126,539 | 23.92 | 126,539 | 24.48 | 147,104 | 21.34 | | Port Harcourt | 355,205 | 67.83 | 355,205 | 67.83 | 357,408 | 46.96 | 374,793 | 39.99 | | Yola | 71,580 | 20.67 | 71,580 | 20.67 | 71,580 | 19.00 | 78,034 | 20.44 | | Total | 3,793,895 | 42.91 | 3,811,729 | 42.92 | 3,895,497 | 40.26 | 4,128,791 | 39.80 | Unmetered Customers by DisCos 2019/Q2 2019/Q3 | DisCos | 2019/Q1As at 31 March | | 2019/Q2As at 30 June | | 2019/Q3As at 31 September | | 2019/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | | | Abuja | 512,457 | 47.42 | 522,536 | 47.62 | 533,361 | 45.79 | 586,550 | 47.75 | | Benin | 421,739 | 43.48 | 421,739 | 43.48 | 452,610 | 45.18 | 469,064 | 45.88 | | Eko | 254,080 | 51.47 | 254,080 | 51.47 | 263,562 | 52.27 | 262,312 | 50.62 | | Enugu | 555,489 | 56.39 | 546,641 | 55.49 | 624,994 | 58.11 | 623,337 | 56.65 | | Ibadan | 1,092,099 | 61.36 | 1,092,099 | 61.36 | 1,401,658 | 67.04 | 1,355,863 | 63.37 | | Ikeja | 525,290 | 54.01 | 522,950 | 53.77 | 538,275 | 54.00 | 656,705 | 57.32 | | Jos | 315,789 | 64.95 | 339,706 | 66.58 | 341,616 | 66.71 | 367,204 | 68.29 | | Kaduna | 524,260 | 77.80 | 524,260 | 77.80 | 523,880 | 77.74 | 516,272 | 76.62 | | Kano | 402,575 | 76.08 | 402,575 | 76.08 | 390,408 | 75.52 | 542,200 | 78.66 | | Port Harcourt | 168,488 | 32.17 | 168,488 | 32.17 | 403,697 | 53.04 | 562,512 | 60.01 | | Yola | 274,640 | 79.33 | 274,640 | 79.33 | 305,171 | 81.00 | 303,769 | 79.56 | | Total | 5,046,906 | 57.09 | 5,069,714 | 57.08 | 5,779,232 | 59.74 | 6,245,788 | 60.20 | * * * Table E.1 Cont’d: Customers registered, metered and unmetered, 2018-2022 Registered Customers (RC) by DisCos 2018/Q2 2018/Q3 | | Registered Customers(RC)by DisCos | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | | 2018/Q1As at 31 March | | 2018/Q2As at 30 June | | 2018/Q3As at 31 September | | 2018/Q4As at 31 December | | | DisCos | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | RegisteredCustomers | %Share | | Abuja | 1,129,521 | 13.88 | 967,667 | 12.14 | 973,926 | 11.72 | 983,496 | 11.40 | | Benin | 856,292 | 10.53 | 856,292 | 10.74 | 888,143 | 10.69 | 920,190 | 10.66 | | Eko | 470,766 | 5.79 | 470,766 | 5.90 | 496,442 | 5.97 | 494,888 | 5.73 | | Enugu | 884,992 | 10.88 | 884,992 | 11.10 | 938,311 | 11.29 | 982,155 | 11.38 | | Ibadan | 1,613,635 | 19.83 | 1,613,635 | 20.24 | 1,693,346 | 20.38 | 1,779,751 | 20.62 | | Ikeja | 910,338 | 11.19 | 910,338 | 11.42 | 910,465 | 10.96 | 998,673 | 11.57 | | Jos | 486,198 | 5.98 | 486,198 | 6.10 | 486,580 | 5.86 | 520,585 | 6.03 | | Kaduna | 484,310 | 5.95 | 484,310 | 6.07 | 543,654 | 6.54 | 589,810 | 6.83 | | Kano | 508,640 | 6.25 | 508,640 | 6.38 | 508,943 | 6.12 | 495,522 | 5.74 | | Port Harcourt | 453,818 | 5.58 | 453,818 | 5.69 | 524,255 | 6.31 | 506,488 | 5.87 | | Yola | 337,220 | 4.14 | 337,220 | 4.23 | 346,342 | 4.17 | 358,982 | 4.16 | | Total | 8,135,730 | 100.00 | 7,973,876 | 100.00 | 8,310,408 | 100.00 | 8,630,540 | 100.00 | Metered Customers by DisCos 2018/Q2 2018/Q3 | DisCos | 2018/Q1As at 31 March | | 2018/Q2As at 30 June | | 2018/Q3As at 31 September | | 2018/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | MeteredCustomers | As%of RC | | | Abuja | 430,098 | 38.08 | 526,120 | 54.37 | 527,900 | 54.20 | 482,508\* | 49.06 | | Benin | 544,828 | 63.63 | 548,261 | 64.03 | 548,261 | 61.73 | 549,789 | 59.75 | | Eko | 215,987 | 45.88 | 235,038 | 49.93 | 222,344\* | 44.79 | 240,699 | 48.64 | | Enugu | 409,748 | 46.30 | 312,385\* | 35.30 | 429,623 | 45.79 | 387,758\* | 39.48 | | Ibadan | 665,609 | 41.25 | 687,652 | 42.62 | 669,105\* | 39.51 | 644,322\* | 36.20 | | Ikeja | 311,332 | 34.20 | 447,299 | 49.14 | 447,299 | 49.13 | 466,746 | 46.74 | | Jos | 170,409 | 35.05 | 170,409 | 35.05 | 170,409 | 35.02 | 160,670\* | 30.86 | | Kaduna | 136,037 | 28.09 | 136,037 | 28.09 | 136,037 | 25.02 | 139,895 | 23.72 | | Kano | 126,539 | 24.88 | 101,732\* | 20.00 | 126,539 | 24.86 | 135,491 | 27.34 | | Port Harcourt | 352,533 | 77.68 | 310,616\* | 68.45 | 355,205 | 67.75 | 304,737\* | 60.17 | | Yola | 70,883 | 21.02 | 71,580 | 21.23 | 71,580 | 20.67 | 70,782\* | 19.72 | | Total | 3,434,003 | 42.21 | 3,547,129 | 44.48 | 3,704,302 | 44.57 | 3,583,397\* | 41.52 | Unmetered Customers by DisCos 2018/Q2 2018/Q3 | DisCos | 2018/Q1As at 31 March | | 2018/Q2As at 30 June | | 2018/Q3As at 31 September | | 2018/Q4As at 31 December | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | UnmeteredCustomers | As%of RC | | | Abuja | 699,423 | 61.92 | 1,361,248 | 45.63 | 446,026 | 45.80 | 500,988 | 50.94 | | Benin | 311,464 | 36.37 | 308,031 | 35.97 | 339,882 | 38.27 | 370,401 | 40.25 | | Eko | 254,779 | 54.12 | 235,728 | 50.07 | 274,098 | 55.21 | 254,189 | 51.36 | | Enugu | 475,244 | 53.70 | 572,607 | 64.70 | 508,688 | 54.21 | 594,397 | 60.52 | | Ibadan | 948,026 | 58.75 | 925,983 | 57.38 | 1,024,241 | 60.49 | 1,135,429 | 63.80 | | Ikeja | 599,006 | 65.80 | 463,039 | 50.86 | 463,166 | 50.87 | 531,927 | 53.26 | | Jos | 315,789 | 64.95 | 315,789 | 64.95 | 316,171 | 64.98 | 359,915 | 69.14 | | Kaduna | 348,273 | 71.91 | 348,273 | 71.91 | 407,617 | 74.98 | 449,915 | 76.28 | | Kano | 382,101 | 75.12 | 406,908 | 80.00 | 382,404 | 75.14 | 360,031 | 72.66 | | Port Harcourt | 101,285 | 22.32 | 143,202 | 31.55 | 169,050 | 32.25 | 201,751 | 39.83 | | Yola | 266,337 | 78.98 | 265,640 | 78.77 | 274,762 | 79.33 | 288,200 | 80.28 | | Total | 4,701,727 | 57.79 | 5,346,448 | 55.52 | 4,606,106 | 55.43 | 5,047,143 | 58.48 | Notes of the table: 1. % Share is the ratio of the registered customers by a DisCo to the registered customers by all DisCos 2. % Share is the ratio of the registered customers by a DisCo to the registered customers by all DisCos * * * Key Statistics Table E.2: Summary of customers metering status, 2020-2022 | DisCos | Registered Customers As at December 2022 | Registered Customers As at December 2021 | Registered Customers As at December 2020 | Metered Customers As at December 2022 | Metered Customers As at December 2021 | Metered Customers As at December 2020 | Metered Customers Pre-Privatization Policy | DisCos Metering per Annum | Metering Pledge Gaps in 2022 | Metering Pledge Gaps in 2021 | Metering Pledge Gaps in 2020 | Total Metering Gap as at December 2022 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Abuja | 1,290,977 | 1,581,212 | 1,468,404 | 701,781 | 701,781 | 707,534 | 392,488 | 150,000 | 94,323 | 155,753 | 84,204 | 533,519 | | Benin | 1,186,922 | 1,645,337 | 1,180,650 | 622,429 | 622,429 | 571,600 | 425,308 | 264,000 | 278,527 | 213,171 | 245,794 | 579,020 | | Eko | 689,237 | 614,370 | 541,560 | 347,116 | 347,116 | 286,847 | 189,542 | 204,000 | 159,718 | 143,731 | 173,033 | 297,839 | | Enugu | 1,391,562 | 1,663,429 | 1,183,093 | 545,035 | 545,035 | 505,136 | 218,718 | 48,000 | 55,627 | 8,101 | 19,819 | 854,154 | | Ibadan | 2,220,266 | 2,084,476 | 2,907,214 | 782,105 | 782,105 | 807,573 | 413,297 | 217,611 | 93,892 | 243,079 | 193,916 | 1,314,442 | | Ikeja | 1,298,323 | 1,298,323 | 1,145,622 | 633,562 | 633,562 | 562,837 | 391,724 | 120,000 | (10,118) | 49,275 | 46,080 | 534,643 | | Jos | 705,249 | 681,002 | 598,430 | 212,265 | 212,265 | 172,627 | 168,046 | 100,000 | 85,654 | 60,362 | 97,895 | 478,638 | | Kaduna | 844,996 | 791,430 | 721,436 | 166,814 | 166,814 | 232,405 | 175,275 | 187,200 | 156,572 | 252,791 | 112,371 | 647,554 | | Kano | 849,311 | 766,590 | 699,618 | 190,834 | 190,834 | 352,493 | 146,329 | 100,000 | 85,554 | 261,659 | (105,389) | 644,031 | | Port Harcourt | 1,179,194 | 1,288,197 | 985,782 | 404,439 | 404,439 | 387,025 | 199,501 | 252,000 | 211,265 | 234,586 | 239,768 | 734,020 | | Yola | 496,069 | 453,732 | 410,010 | 84,774 | 84,774 | 80,114 | 61,599 | 51,600 | 39,680 | 46,940 | 49,520 | 399,375 | Notes of the table: 1. BPE is the Bureau of Public Enterprise 2. BPE is the Bureau of Public Enterprise * * * Key Statistics Table E.3: Customer complaints received and resolved by DisCos in 2022 | DisCos | 2022/Q1 | | | | 2022/Q2 | | | | 2022/Q3 | | | | 2022/Q4 | | | | 2022 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | | | | Abuja | 27,251 | 26,948 | 303 | 25,471 | 24,908 | 705 | 31,004 | 30,325 | 679 | 30,662 | 30,107 | 555 | 114,388 | 112,324 | 2,064 | 114,388 | 112,324 | 2,064 | | | | Benin | 9,546 | 9,163 | 383 | 8,252 | 7,612 | 635 | 8,212 | 7,168 | 1,044 | 4,606 | 4,225 | 381 | 30,616 | 28,168 | 2,448 | 30,616 | 28,168 | 2,448 | | | | Eko | 37,938 | 37,412 | 526 | 36,502 | 35,995 | 763 | 38,638 | 35,881 | 2,757 | 43,997 | 40,733 | 3,264 | 148,165 | 136,075 | 12,090 | 148,165 | 136,075 | 12,090 | | | | Enugu | 29,028 | 23,466 | 5,562 | 20,815 | 15,742 | 2,708 | 20,312 | 16,430 | 3,882 | 24,601 | 22,729 | 1,872 | 103,666 | 92,313 | 11,353 | 103,666 | 92,313 | 11,353 | | | | Ibadan | 15,102 | 14,179 | 923 | 37,186 | 29,752 | 1,118 | 32,094 | 24,040 | 8,054 | 40,178 | 36,068 | 4,110 | 124,560 | 104,039 | 20,521 | 124,560 | 104,039 | 20,521 | | | | Ikeja | 36,802 | 33,542 | 3,260 | 40,790 | 37,579 | 3,414 | 32,044 | 28,868 | 3,176 | 29,282 | 19,536 | 9,746 | 138,918 | 119,525 | 19,393 | 138,918 | 119,525 | 19,393 | | | | Jos | 18,878 | 18,475 | 403 | 11,708 | 11,524 | 457 | 11,671 | 11,581 | 90 | 14,815 | 13,950 | 865 | 57,072 | 55,530 | 1,542 | 57,072 | 55,530 | 1,542 | | | | Kaduna | 8,369 | 7,425 | 944 | 8,410 | 7,862 | 819 | 8,144 | 7,744 | 400 | 7,258 | 6,845 | 413 | 32,175 | 29,876 | 2,299 | 32,175 | 29,876 | 2,299 | | | * * * Table E.3 Cont’d: Customer complaints received and resolved by DisCos in 2021 | DisCos | 2021/Q1 | | | 2021/Q2 | | | 2021/Q3 | | | 2021/Q4 | | | 2021 | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | | 27,224 | 26,643 | 581 | 37,624 | 36,919 | 705 | 35,958 | 35,041 | 917 | 31,051 | 29,967 | 1,084 | 131,857 | 128,570 | 3,287 | | | Abuja | 18,192 | 16,985 | 1,207 | 14,795 | 14,160 | 635 | 12,920 | 12,397 | 523 | 11,383 | 10,832 | 551 | 57,290 | 54,374 | 2,916 | | Benin | 55,200 | 54,438 | 762 | 54,658 | 53,895 | 763 | 50,712 | 50,092 | 620 | 37,033 | 35,757 | 1,276 | 197,603 | 194,182 | 3,421 | | Eko | 28,072 | 26,529 | 1,543 | 29,233 | 26,525 | 2,708 | 20,585 | 19,341 | 1,244 | 24,089 | 22,046 | 2,043 | 101,979 | 94,441 | 7,538 | | Enugu | 28,072 | 26,529 | 1,543 | 29,233 | 26,525 | 2,708 | 20,585 | 19,341 | 1,244 | 24,089 | 22,046 | 2,043 | 101,979 | 94,441 | 7,538 | | Ibadan | 9,984 | 8,573 | 1,411 | 8,581 | 7,463 | 1,118 | 8,876 | 8,050 | 826 | 9,898 | 9,017 | 881 | 37,339 | 33,103 | 4,236 | | Ikeja | 37,950 | 34,533 | 3,417 | 38,473 | 35,059 | 3,414 | 37,964 | 35,096 | 2,868 | 35,191 | 32,375 | 2,816 | 149,578 | 137,063 | 12,515 | | Jos | 10,676 | 10,030 | 646 | 12,825 | 12,368 | 457 | 13,193 | 12,734 | 459 | 13,427 | 13,178 | 249 | 50,121 | 48,310 | 1,811 | | Kaduna | 8,905 | 7,795 | 1,110 | 8,058 | 7,239 | 819 | 8,865 | 8,051 | 814 | 11,036 | 10,603 | 433 | 36,864 | 33,688 | 3,176 | | Kano | 12,253 | 12,150 | 103 | 10,592 | 10,139 | 453 | 19,363 | 18,970 | 393 | 16,473 | 16,122 | 351 | 58,681 | 57,381 | 1,300 | E k o /k e i o P H,{ * * * Key Statistics Table E.3 Cont’d: Customer complaints received and resolved by DisCos in 2020 | | 2020/Q1 | | | | 2020/Q2 | | | | 2020/Q3 | | | | 2020/Q4 | | | | 2020 | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | Customers' Complaints | | | | Customers' Complaints | | | | Customers' Complaints | | | | Customers' Complaints | | | | Customers' Complaints | | | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | | | Abuja | 27,519 | 26,860 | 659 | 20,109 | 19,761 | 348 | 23,531 | 23,035 | 496 | 41,841 | 39,806 | 2,035 | 113,000 | 109,462 | 3,538 | | | | | | | | | Benin | 11,604 | 9,966 | 1,638 | 9,282 | 7,751 | 1,531 | 14,929 | 12,665 | 2,264 | 15,140 | 12,907 | 2,233 | 50,955 | 43,289 | 7,666 | | | | | | | | | Eko | 25,560 | 22,198 | 3,362 | 25,441 | 22,148 | 3,293 | 26,032 | 23,300 | 2,732 | 27,177 | 25,244 | 1,933 | 104,210 | 92,890 | 11,320 | | | | | | | | | Enugu | 57,835 | 55,690 | 2,145 | 63,230 | 61,460 | 1,770 | 54,223 | 53,446 | 777 | 52,966 | 52,056 | 910 | 228,254 | 222,652 | 5,602 | | | | | | | | | Ibadan | 9,021 | 6,927 | 2,094 | 7,818 | 6,324 | 1,494 | 9,717 | 7,526 | 2,191 | 7,708 | 6,435 | 1,273 | 34,264 | 27,212 | 7,052 | | | | | | | | | Ikeja | 39,415 | 35,930 | 3,485 | 37,830 | 34,471 | 3,359 | 39,831 | 36,248 | 3,583 | 35,741 | 32,100 | 3,641 | 152,817 | 138,749 | 14,068 | | | | | | | | | Jos | 5,270 | 4,816 | 454 | 4,460 | 4,222 | 238 | 5,936 | 5,717 | 219 | 11,530 | 10,635 | 895 | 27,196 | 25,390 | 1,806 | | | | | | | | | Kaduna | 8,078 | 7,655 | 423 | 7,529 | 7,003 | 526 | 8,329 | 7,803 | 526 | 6,422 | 5,493 | 929 | 30,358 | 27,954 | 2,404 | | | | | | | | * * * Key Statistics Table E.3 Cont’d: Customer complaints received and resolved by DisCos in 2019 | DisCos | 2019/Q1 | | | 2019/Q2 | | | 2019/Q3 | | | 2019 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | | | 14,168 | 11,444 | 2,724 | 11,959 | 9,682 | 2,277 | 16,354 | 12,165 | 4,189 | 19,631 | 17,106 | 2,525 | 62,112 | | | Abuja | 15,404 | 11,970 | 3,434 | 13,673 | 11,598 | 2,075 | 10,517 | 9,754 | 766 | 10,665 | 9,322 | 1,343 | 50,259 | | Benin | 26,442 | 26,333 | 109 | 17,722 | 15,821 | 1,901 | 16,223 | 13,977 | 2,193 | 17,713 | 14,797 | 2,916 | 78,100 | | Eko | 26,442 | 26,333 | 109 | 17,722 | 15,821 | 1,901 | 16,223 | 13,977 | 2,193 | 17,713 | 14,797 | 2,916 | 78,100 | | Enugu | 21,317 | 18,832 | 2,485 | 30,104 | 28,989 | 1,115 | 56,249 | 45,879 | 10,370 | 47,209 | 45,672 | 1,537 | 154,879 | | Ibadan | 9,893 | 6,564 | 3,329 | 9,067 | 6,948 | 2,119 | 8,657 | 6,006 | 2,651 | 7,772 | 5,757 | 2,098 | 35,389 | | Ikeja | 30,171 | 26,475 | 3,696 | 29,778 | 25,462 | 4,316 | 27,853 | 24,138 | 3,715 | 35,256 | 31,804 | 3,405 | 123,058 | | Jos | 5,464 | 5,150 | 314 | 5,378 | 4,841 | 537 | 4,624 | 4,294 | 330 | 5,852 | 5,337 | 515 | 21,318 | | Kaduna | 11,862 | 9,630 | 2,232 | 9,486 | 7,790 | 1,696 | 9,364 | 9,008 | 356 | 9,662 | 9,340 | 322 | 40,374 | | Kano | 5,965 | 5,681 | 284 | 6,065 | 5,667 | 398 | 4,988 | 4,684 | 304 | 6,481 | 6,242 | 239 | 23,499 | | P/H | 9,135 | 8,082 | 1,053 | 10,415 | 8,941 | 1,474 | 15,688 | 14,116 | 1,572 | 15,603 | 13,535 | 2,068 | 50,841 | | Yola | 2,117 | 2,098 | 19 | 2,312 | 2,286 | 26 | 2,316 | 2,305 | 14 | 1,963 | 1,930 | 33 | 8,708 | * * * Key Statistics Table E.3 Cont’d: Customer complaints received and resolved by DisCos in 2018 | DisCos | 2018/Q1 | | | 2018/Q2 | | | 2018/Q3 | | | 2018/Q4 | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | Customers' Complaints | | | | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | | | | | Abuja | 11,525 | 10,468 | 1,057 | 12,486 | 11,319 | 1,167 | 16,371 | 14,552 | 1,819 | 14,036 | 12,999 | 1,037 | 54,418 | 49,338 | 5,080 | | Benin | 30,680 | 7,857 | 22,823 | 42,948 | 11,533 | 31,415 | 33,682 | 15,942 | 17,740 | 12,437 | 7,226 | 5,211 | 119,747 | 42,558 | 77,189 | | Eko | 11,084 | 8,431 | 2,653 | 11,063 | 9,118 | 1,945 | 3,881 | 3,837 | 44 | 30,531 | 30,436 | 95 | 56,559 | 51,822 | 4,737 | | Enugu | 9,191 | 6,689 | 2,502 | 23,610 | 6,685 | 16,925 | 15,548 | 11,613 | 3,935 | 22,608 | 20,352 | 2,256 | 70,957 | 45,339 | 25,618 | | Ibadan | 11,619 | 10,089 | 1,530 | 9,236 | 7,840 | 1,396 | 8,222 | 7,370 | 852 | 7,154 | 6,139 | 1,015 | 36,231 | 31,438 | 4,793 | | Ikeja | 12,288 | 9,654 | 2,634 | 26,537 | 22,117 | 4,420 | 27,485 | 24,270 | 3,215 | 24,943 | 21,199 | 3,744 | 91,253 | 77,240 | 14,013 | | Jos | 1,617 | 1,492 | 125 | 3,519 | 3,245 | 274 | 3,680 | 3,315 | 365 | 5,401 | 4,923 | 478 | 14,217 | 12,975 | 1,242 | | Kaduna | 10,315 | 8,507 | 1,808 | 10,001 | 8,823 | 1,178 | 7,838 | 5,891 | 1,947 | 8,615 | 6,576 | 2,039 | 36,769 | 29,797 | 6,972 | | Kano | 4,662 | 4,514 | 148 | 5,326 | 5,168 | 158 | 5,507 | 4,731 | 776 | 4,802 | 4,080 | 722 | 20,297 | 18,493 | 1,804 | | P/H | 4,143 | 3,412 | 731 | 5,519 | 4,950 | 569 | 4,116 | 3,414 | 702 | 3,405 | 2,225 | 1,180 | 17,183 | 14,001 | 3,182 | | Yola | 1,747 | 1,733 | 14 | 2,982 | 2,899 | 83 | 2,461 | 2,408 | 53 | 2,461 | 2,408 | 53 | 9,651 | 9,448 | 203 | * * * Table E.4: DisCos’ Complaints resolution rate, 2018-2022 | | 2022(%) | | | | | 2021(%) | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | DisCos | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | Abuja | 98.89 | 97.79 | 97.81 | 98.19 | 98.20 | 97.87 | 98.13 | 97.45 | 96.51 | 96.87 | | Benin | 95.99 | 92.24 | 87.29 | 91.73 | 92.00 | 93.37 | 95.71 | 95.95 | 95.16 | 84.96 | | Eko | 98.61 | 98.61 | 92.86 | 92.58 | 91.84 | 94.5 | 98.6 | 98.78 | 96.55 | 89.14 | | Enugu | 80.84 | 71.67 | 80.89 | 92.39 | 89.05 | 98.62 | 90.74 | 93.96 | 91.52 | 97.55 | | Ibadan | 93.89 | 80.01 | 74.90 | 89.77 | 83.53 | 85.87 | 86.97 | 90.69 | 91.10 | 79.42 | | Ikeja | 91.14 | 92.13 | 90.09 | 66.72 | 86.04 | 91.00 | 91.13 | 92.45 | 92.00 | 90.79 | | Jos | 97.87 | 98.43 | 99.23 | 94.16 | 97.3 | 93.95 | 96.44 | 96.52 | 98.15 | 93.36 | | Kaduna | 88.72 | 93.48 | 95.09 | 94.31 | 92.85 | 87.54 | 89.84 | 90.82 | 96.08 | 92.08 | | Kano | 99.48 | 99.17 | 98.94 | 99.31 | 99.22 | 99.16 | 95.72 | 97.97 | 97.87 | 97.86 | | Port Harcourt | 98.9 | 98.31 | 98.83 | 97.66 | 98.41 | 99.79 | 99.12 | 98.67 | 98.55 | 95.32 | | Yola | 98.29 | 99.02 | 99.64 | 98.00 | 98.8 | 97.49 | 99.12 | 97.80 | 96.29 | 98.79 | | Average | 94.78 | 92.81 | 92.32 | 92.26 | 93.39 | 94.47 | 94.68 | 95.55 | 95.43 | 92.38 | | All DisCos | 94.6 | 92.38 | 91.58 | 91.3 | 92.49 | 95.41 | 95.32 | 96.28 | 95.39 | 93.25 | | | 2020(%) | | | | | 2019(%) | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | | Abuja | 97.61 | 98.27 | 97.89 | 95.14 | 96.87 | 80.77 | 80.96 | 74.39 | 87.14 | 81.14 | | Benin | 85.88 | 83.51 | 84.83 | 85.25 | 84.96 | 77.71 | 84.82 | 92.75 | 87.41 | 84.85 | | Eko | 86.85 | 87.06 | 89.51 | 92.89 | 89.14 | 99.59 | 89.27 | 86.16 | 83.54 | 90.82 | * * * Key Statistics Table E.5: Category of customer complaints received by DisCos, 2017-2022 | Complaint Categories | 2022 | | | | | 2021 | | | | | 2020 | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | | Metering | 79,637 | 111,956 | 117,268 | 122,805 | 431,666 | 50,328 | 50,659 | 55,293 | 53,305 | 209,585 | 44,662 | 48,019 | 71,897 | 41,455 | 206,033 | | Interruption | 37,186 | 23,438 | 21,750 | 24,233 | 106,607 | 43,611 | 48,216 | 45,065 | 38,450 | 175,342 | 41,381 | 39,869 | 34,199 | 37,631 | 153,080 | | Voltage | 16,272 | 9,987 | 4,139 | 4,346 | 34,744 | 22,895 | 29,326 | 30,235 | 26,079 | 108,535 | 15,216 | 17,583 | 17,623 | 14,899 | 65,321 | | Load Shedding | 14,719 | 5,336 | 1,303 | 1,466 | 22,824 | 17,792 | 18,228 | 14,360 | 14,148 | 64,528 | 16,056 | 20,342 | 16,498 | 16,680 | 69,576 | | Billing | 41,644 | 32,930 | 49,924 | 61,022 | 185,520 | 38,920 | 42,769 | 48,542 | 39,398 | 169,629 | 45,746 | 45,895 | 40,489 | 46,399 | 178,529 | | Disconnection | 26,994 | 7,251 | 7,346 | 4,845 | 46,436 | 34,369 | 31,318 | 31,019 | 28,121 | 124,827 | 21,427 | 22,856 | 20,414 | 24,666 | 89,363 | | Connection Delay | 12,794 | 2,996 | 1,284 | 2,952 | 20,026 | 19,224 | 15,989 | 14,820 | 14,766 | 64,799 | 10,309 | 14,495 | 12,401 | 13,386 | 50,591 | | Others | 14,141 | 38,011 | 38,227 | 39,438 | 129,817 | 9,800 | 4,971 | 7,784 | 8,372 | 30,927 | 8,319 | 9,930 | 16,976 | 9,390 | 44,615 | | Total | 243,387 | 231,905 | 241,241 | 261,107 | 977,640 | 236,939 | 241,476 | 247,118 | 222,639 | 948,172 | 203,116 | 218,989 | 230,497 | 204,506 | 857,108 | | Complaint Categories | 2019 | | | | | 2018 | | | | | 2017 | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | * * * Table E.6: Appeals received and resolved by forum offices 2022 | S/N | Forum Offices | 2022/01 | | | | 2022/02 | | | | 2022/03 | | | | 2022/04 | | | | 2022 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | | 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 | Received | Resolved | Pending | Resolution Rate | | | | 1 | Abakaliki | 41 | 28 | 13 | 68% | 77 | 0 | 77 | 0% | 50 | 32 | 18 | 64% | 63 | 32 | 31 | 51% | 231 | 92 | 139 | 40% | | 2 | Abeokuta | NC | NC | NC | NC | 39 | 13 | 26 | 33% | 70 | 30 | 40 | 43% | 94 | 55 | 39 | 59% | 203 | 98 | 105 | 48% | | 3 | Abuja | 62 | 47 | 15 | 76% | 56 | 33 | 23 | 59% | 56 | 34 | 22 | 61% | 65 | 49 | 16 | 75% | 239 | 163 | 76 | 68% | | 4 | Asaba | 84 | 80 | 4 | 95% | 121 | 92 | 29 | 76% | 92 | 86 | 6 | 93% | 67 | 61 | 6 | 91% | 364 | 319 | 45 | 88% | | 5 | Awka | 77 | 67 | 10 | 87% | 62 | 35 | 27 | 56% | 81 | 50 | 31 | 62% | 92 | 77 | 15 | 84% | 312 | 229 | 83 | 73% | | 6 | Bauchi | 34 | 25 | 9 | 74% | 17 | 14 | 3 | 82% | 5 | 4 | 1 | 80% | 5 | 5 | 0 | 100% | 61 | 48 | 13 | 79% | | 7 | Benin | 67 | 45 | 22 | 67% | 59 | 43 | 16 | 73% | 50 | 28 | 22 | 56% | 54 | 54 | 0 | 100% | 230 | 170 | 60 | 74% | | 8 | B/Kebi | 4 | 0 | 4 | 0% | 4 | 0 | 4 | 0% | 6 | 0 | 6 | 0% | 10 | 2 | 8 | 20% | 24 | 2 | 22 | 8% | | 9 | Calabar | 48 | 31 | 17 | 65% | 58 | 28 | 30 | 48% | 61 | 14 | 47 | 23% | 73 | 40 | 33 | 55% | 240 | 113 | 127 | 47% | | 10 | Dutse | 2 | 1 | 1 | 50% | 14 | 0 | 14 | 0% | 17 | 0 | 17 | 0% | 15 | 1 | 14 | 7% | 48 | 2 | 46 | 4% | * * * Table E.6: Appeals received and resolved by forum offices 2021 | S/N | Forum Offices | 2021/Q1 | | | | 2021/Q2 | | | | 2021/Q3 | | | | 2021/Q4 | | | | 2021 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | | 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 | Received | Resolved | Pending | Resolution Rate | | | | 1 | Abakaliki | 22 | 17 | 5 | 77% | 19 | 7 | 12 | 37% | 15 | 6 | 40% | 40% | 53 | 42 | 7 | 79% | 109 | 72 | 37 | 66% | | 2 | Aujia | 45 | 22 | 23 | 49% | 87 | 53 | 34 | 61% | 76 | 51 | 67% | 67% | 64 | 52 | 10 | 81% | 272 | 178 | 94 | 65% | | 3 | Asaba | 78 | 75 | 3 | 96% | 103 | 100 | 3 | 97% | 66 | 66 | 100% | 100% | 76 | 52 | 2 | 68% | 323 | 293 | 30 | 91% | | 4 | Awka | 81 | 57 | 24 | 70% | 89 | 71 | 18 | 80% | 87 | 59 | 68% | 68% | 70 | 48 | 2 | 69% | 327 | 235 | 92 | 72% | | 5 | Bauchi | 5 | 0 | 5 | 0% | 6 | 0 | 6 | 0% | 1 | 0 | 0% | 0% | 2 | 0 | 8 | 0% | 14 | 0 | 14 | 0% | | 6 | Benin | 58 | 0 | 58 | 0% | 52 | 52 | 0 | 100% | 45 | 45 | 100% | 100% | 32 | 12 | 0 | 38% | 187 | 109 | 78 | 58% | | 7 | B/kabbi | 69 | 35 | 34 | 51% | 138 | 98 | 40 | 71% | 40 | 21 | 53% | 53% | 39 | 27 | 3 | 69% | 286 | 181 | 105 | 63% | | 8 | Colabar | 119 | 93 | 26 | 78% | 163 | 137 | 26 | 84% | 142 | 112 | 79% | 79% | 190 | 151 | 3 | 79% | 614 | 493 | 121 | 80% | | 9 | Dute | 109 | 80 | 29 | 73% | 100 | 68 | 32 | 68% | 85 | 42 | 49% | 49% | 84 | 74 | 2 | 88% | 378 | 264 | 114 | 70% | | 10 | Eko | 15 | 12 | 3 | 80% | 11 | 11 | 0 | 100% | 15 | 10 | 67% | 67% | 8 | 5 | 24 | 63% | 49 | 38 | 11 | 78% | | 11 | Enugu | 8 | 6 | 2 | 75% | 0 | 0 | 0 | 0% | 4 | 2 | 50% | 50% | 14 | 10 | 38 | 71% | 26 | 18 | 8 | 69% | * * * Table E.6 Cont’d: Appeals received and resolved by forum offices 2020 | S/N | Forum Offices | 2020/Q1 Customers' Complaints | | | | 2020/Q2 Customers' Complaints | | | | 2020/Q3 Customers' Complaints | | | | 2020/Q4 Customers' Complaints | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | | | | | | 1 | Abakaliki | 21 | 12 | 9 | 57% | 15 | 11 | 4 | 73% | 25 | 17 | 8 | 68% | 30 | 23 | 7 | 77% | 70 | 63 | 7 | 90% | | 2 | Abuja | 70 | 33 | 37 | 47% | 50 | 32 | 18 | 64% | 61 | 40 | 21 | 66% | 53 | 43 | 10 | 81% | 158 | 148 | 10 | 94% | | 3 | Asaba | 35 | 37 | 18 | 67% | 79 | 0 | 79 | 0% | 70 | 70 | 0 | 100% | 71 | 69 | 2 | 97% | 185 | 183 | 2 | 99% | | 4 | Awka | 45 | 24 | 21 | 53% | 32 | 10 | 22 | 31% | 55 | 37 | 18 | 67% | 49 | 22 | 27 | 45% | 138 | 111 | 27 | 80% | | 5 | Bauchi | 14 | 11 | 3 | 79% | 22 | 2 | 18 | 9% | 11 | 0 | 11 | 0% | 8 | 0 | 8 | 0% | 40 | 32 | 8 | 80% | | 6 | Benin | 47 | 25 | 22 | 53% | 107 | 107 | 0 | 100% | 71 | 71 | 0 | 100% | 61 | 61 | 0 | 100% | 436 | 436 | 0 | 100% | | 7 | B/kebi | 14 | 0 | 8 | 0% | 10 | 1 | 5 | 56% | 19 | 17 | 2 | 89% | 9 | 6 | 3 | 67% | 51 | 48 | 3 | 94% | | 8 | Calabar | 34 | 11 | 23 | 32% | 41 | 11 | 30 | 27% | 59 | 27 | 32 | 44% | 64 | 27 | 35 | 42% | 89 | 52 | 35 | 58% | | 9 | Duke | 1 | 1 | 0 | 100% | 4 | 4 | 0 | 100% | 2 | 0 | 2 | 0% | 5 | 1 | 2 | 20% | 95 | 11 | 5 | 26% | | 10 | Eko | 252 | 137 | 115 | 54% | 152 | 120 | 32 | 79% | 132 | 108 | 24 | 82% | 143 | 119 | 24 | 83% | 508 | 484 | 24 | 95% | | 11 | Enugu | 63 | 20 | 43 | 32% | 125 | 0 | 125 | 0% | 186 | 134 | 50 | 72% | 85 | 47 | 38 | 85% | 276 | 236 | 38 | 86% | * * * Table E.6 Cont’d: Appeals received and resolved by forum offices 2019 | S/N | Forum Offices | 2019/Q1 | | | | 2019/Q2 | | | | 2019/Q3 | | | | 2019/Q4 | | | | 2019 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | | 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 | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | Received | Resolved | Pending Resolution Rate | | | 1 | Abakaliki | 37 | 22 | 15 | 59% | 48 | 31 | 11 | 65% | 33 | 28 | 5 | 85% | 37 | 32 | 5 | 86% | 117 | 113 | 5 | 97% | | 2 | Abuja | 438 | 214 | 224 | 49% | 261 | 148 | 110 | 57% | 197 | 162 | 35 | 82% | 98 | 80 | 18 | 82% | 625 | 604 | 18 | 97% | | 3 | Asaba | 126 | 80 | 46 | 63% | 62 | 55 | 7 | 89% | 88 | 67 | 21 | 76% | 77 | 69 | 8 | 90% | 265 | 271 | 8 | 102% | | 4 | Awka | 86 | 41 | 45 | 48% | 84 | 33 | 51 | 39% | 92 | 54 | 38 | 59% | 35 | 16 | 19 | 46% | 203 | 144 | 19 | 71% | | 5 | Bauchi | 11 | 8 | 2 | 73% | 5 | 2 | 3 | 40% | 6 | 5 | 1 | 83% | 7 | 5 | 2 | 71% | 24 | 20 | 2 | 83% | | 6 | Benin | 52 | 16 | 36 | 31% | 84 | 59 | 25 | 70% | 97 | 84 | 12 | 87% | 30 | 18 | 12 | 60% | 173 | 177 | 12 | 102% | | 7 | Birinn Kebabi | 10 | 6 | 4 | 60% | 9 | 5 | 4 | 56% | 11 | 4 | 7 | 36% | 9 | 1 | 8 | 11% | 32 | 16 | 8 | 50% | | 8 | Calabar | 15 | 12 | 3 | 80% | 8 | 1 | 7 | 13% | 9 | 0 | 9 | 0% | 16 | 2 | 14 | 13% | 40 | 15 | 14 | 38% | | 9 | Dutse | 6 | 0 | 6 | 0% | 0 | 0 | 0 | 0% | 2 | 0 | 2 | 0% | 2 | 1 | 1 | 50% | 4 | 1 | 125% | | | 10 | Eko | 333 | 70 | 263 | 21% | 332 | 115 | 217 | 35% | 194 | 162 | 32 | 84% | 171 | 121 | 50 | 71% | 734 | 468 | 50 | 64% | * * * Table E.6 Cont’d: Appeals Received and Resolved by Forum Offices 2018 | S/N | Forum Offices | 2018/Q1 | | | | 2018/Q2 | | | | 2018/Q3 | | | | 2018/Q4 | | | | 2018 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints | | | | 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 | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | Received Resolved Pending Resolution Rate | | | | | | 1 | Abakaliki | 17 | 0 | 17 | 0% | 15 | 4 | 9 | 27% | 45 | 30 | 15 | 67% | 49 | 44 | 5 | 90% | 85 | 78 | 5 | 92% | | 2 | Abuja | 101 | 0 | 101 | 0% | 171 | 91 | 79 | 54% | 171 | 106 | 108 | 50% | 267 | 105 | 16 | 39% | 464 | 302 | 162 | 65% | | 3 | Asaba | 79 | 2 | 77 | 3% | 73 | 70 | 3 | 96% | 115 | 76 | 39 | 66% | 95 | 30 | 65 | 32% | 243 | 178 | 65 | 73% | | 4 | Awka | 56 | 0 | 56 | 0% | 73 | 33 | 40 | 45% | 51 | 26 | 25 | 51% | 63 | 46 | 17 | 73% | 122 | 105 | 17 | 86% | | 5 | Bauchi | - | - | - | - | - | - | - | - | - | - | - | - | 4 | 0 | 4 | 0% | 4 | 0 | 4 | 0% | | 6 | Benin | 64 | 0 | 64 | 0% | 37 | - | 37 | 0% | 50 | 26 | 24 | 52% | 48 | 31 | 17 | 65% | 74 | 57 | 17 | 77% | | 7 | Birnin Kebbi | 0 | 0 | 0 | - | 1 | 1 | - | 100% | 0 | 0 | 0 | 0% | 1 | 0 | 1 | 0% | 2 | 1 | 1 | 50% | | 8 | Calabar | 14 | 9 | 5 | 64% | 16 | 10 | 6 | 63% | 30 | 7 | 23 | 23% | 14 | 3 | 11 | 21% | 40 | 29 | 11 | 73% | | 9 | Eko | 191 | 95 | 96 | 50% | 329 | 76 | 253 | 23% | 173 | 4 | 169 | 2 | 543 | 174 | 361 | 32% | 718 | 349 | 361 | 49% | | 10 | Enugu | 170 | 0 | 170 | 0% | 111 | 97 | 14 | 87% | 86 | 38 | 48 | 44% | 73 | 37 | 17 | 61% | 208 | 172 | 36 | 83% | * * * Table E.7: List and Addresses of NERC Forum Offices as at December 2022 | 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 | 814682225 | [abujaforum@nerc.gov.ng](mailto:abujaforum@nerc.gov.ng) | | 4 | Asaba, Delta State | Denis Osadebe Way, Beside Mobil Filling Station, Asaba, Delta State | 9062277247 | [asaboferum@nerc.gov.ng](mailto:asaboferum@nerc.gov.ng) | | 5 | Awka, Anambra State | Plot 80, Aroma Junction Layout, Opp. CBN, Awka, Anambra State | 9037808594 | [awkaferum@nerc.gov.ng](mailto:awkaferum@nerc.gov.ng) | | 6 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bauchi, Bauchi State | 9062924607 | [bauchiforum@nerc.gov.ng](mailto:bauchiforum@nerc.gov.ng) | | 7 | Benin, Edo State | 34, Akpakpeva Street, Benin City, Edo State | 9037808592 | [beninforum@nerc.gov.ng](mailto:beninforum@nerc.gov.ng) | | 8 | B/Kebbi, Kebbi State Calabar, C/Rivers State | 8, Ahmadu Bello Way, J.B. Yakubu Road, Gusau, Zamfara State | 9062863161 | [birinkebbiforum@nerc.gov.ng](mailto:birinkebbiforum@nerc.gov.ng) | | 9 | Dutse, Jigawa State | Plot 109, MCC Road by Ibok Street, Calabar, Cross River State | 9062863159 | [calabarferum@nerc.gov.ng](mailto:calabarferum@nerc.gov.ng) | | 10 | Eko, Lagos State | Dutse G.R.A, Dutse, Jigawa State | 7031704827 | [jigawaferum@nerc.gov.ng](mailto:jigawaferum@nerc.gov.ng) | | 11 | Enugu, Enugu State | 61, Oduntami Street, Off Marina, Lagos Island, Lagos State | 8106870261 | [ekofurum@nerc.gov.ng](mailto:ekofurum@nerc.gov.ng) | | 12 | Gombe, Gombe State | John Anichukwu Close, Plot 7 Mkpkitik Pocket Layout, Enugu, Enugu State | 814682230 | [enuguforum@nerc.gov.ng](mailto:enuguforum@nerc.gov.ng) | | 13 | Gusau, Zamfara State | Government Layout GDP/2, Along Ministry of Education Road, Gombe State | 8140440079 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) | | 14 | Gusau, Zamfara State | 2 Canteen Daij, J.B. Yakubu Road, Gusau, Zamfara State | 9062863163 | [gusauferum@nerc.gov.ng](mailto:gusauferum@nerc.gov.ng) | | 15 | Ibadan, Oyo State | Jibowu Str, Opp. Magara Police Station, Iyaganku, G.R.A, Ibadan, Oyo State | 814682252 | [ibadaforum@nerc.gov.ng](mailto:ibadaforum@nerc.gov.ng) | | 16 | ikeja, Lagos State | 19b, Obafemi Awolowo Way, Alausa, Ikeja, Lagos State | 8106870298 | [ikejaferum@nerc.gov.ng](mailto:ikejaferum@nerc.gov.ng) | | 17 | Ilorin, Kwara State | 30, Stadium Road, Off Taiwo Road, Ilorin, Kwara State | 9062924603 | [ilorinforum@nerc.gov.ng](mailto:ilorinforum@nerc.gov.ng) | | 18 | Jos, Plateau State | 5a, Ray-field Road, Jos, Plateau State | 9037808597 | [josferum@nerc.gov.ng](mailto:josferum@nerc.gov.ng) | | 19 | Kaduna, Kaduna State | 22, Ahmadu Belle Way, Opposite NNDC Building, Kaduna, Kaduna State | 8106870299 | [kadunaferum@nerc.gov.ng](mailto:kadunaferum@nerc.gov.ng) | | 20 | Kano, Kano State | 2, Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 814682222 | [kanofurum@nerc.gov.ng](mailto:kanofurum@nerc.gov.ng) | | 21 | Katsina, Katsina State | 7, Abujia Crescent, Off Hassan Usman Katsina Road, Katsina, Katsina State | 7031704821 | [katsinaferum@nerc.gov.ng](mailto:katsinaferum@nerc.gov.ng) | | 22 | Lafia, Nasarawa State | Manyi Street, Off Jos Road, Bukan Sidi, Lafia, Nasarawa State | 9062924599 | [lafiaferum@nerc.gov.ng](mailto:lafiaferum@nerc.gov.ng) | | 23 | Lokija, Kogi State | Hassan Kastina Rd, Opp. State Civil Service Commission, Zone 8 Police HQ, Lokija, Kogi State. | 9062924601 | [lokojaforum@nerc.gov.ng](mailto:lokojaforum@nerc.gov.ng) | | 24 | Makurdii, Benue State | Hephizibah Plaza, Atom Kpera Road, Opp. Makurdii Int'l School, Benue State | 9062277249 | [makurdiforum@nerc.gov.ng](mailto:makurdiforum@nerc.gov.ng) | * * * * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION NERC NIGERIAN ELECTRICITY REGULATORY COMMISSION PLOT 1387 \| CADASTRAL ZONE A00 \| CENTRAL BUSINESS DISTRICT \| P.M.B. 136 \| GARKI \| ABUJA [www.nerc.gov.ng](http://www.nerc.gov.ng/)