2020 Annual Reports & 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/) NIGERIAN ELECTRICITY REGULATORY COMMISSION NERC * * * Electricity on Demand 20 Anr Repo Accc 20 annual sports &ounts 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/) NIGERIAN ELECTRICIT Y REGULATORY COMMISSION ERC * * * 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 regulatory and corporate activities audited financial statement of the Commission and the analyses of the state of the Nigerian electricity supply industry (covering operational, technical and commercial performance as well as consumer affairs). The Commission being accountable to the public 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 stakeholders of the Nigerian Electricity Supply Industry, 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 Tel: +234 (09) 4621400,+234(09)4621410 Central Business District P.M.B 136, Garki Abuja Email: [info@nerc.gov.ng](mailto:info@nerc.gov.ng) * * * The Nigerian Electricity Regulatory Commission was established by the Electric Power See 2004, with the principal objects outl or Reform (EPSR) Act ned 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. * * * 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. Visi "Electricity Mo "Keeping th on n demand" to: e lights on" * * * 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 env loyalty, trust, collaboration stakeholder engagement; ronment of and 4. Good Governance: making decisions in a fair, transparent and consistent manner, in compliance with the laws of Nigeria and our regulation. * * * CHAIRMAN'S FORWARD This annual report presents the activities of the Nigerian Electricity Regulatory Commission and performance of the electricity industry for the year ended 31st December 2020 thus providing valuable information to industry participants, investors, electricity customers and the general public. The Commission's 3-year Strategic Plan covering the years 2017-2020 was developed in alignment with the power sector reform agenda of the Federal Government of Nigeria ("FGN") and therefore formed the basis of the Commission's activities in 2020. Broadly, the plan has the broad objectives of improving quality of service, increasing access to electricity, reinforcing corporate governance and resolving the liquidity challenge in the industry. The power sector has recorded many strides in the year 2020 despite the several challenges in the industry. The collection efficiency of the electricity distribution companies ("DisCos") has continued to be low consequently creating a significant liquidity challenge in the electricity market. Other key challenges of the industry include infrastructural deficits at the distribution and the transmission segment of the value chain consequently constraining the optimal deployment of available generation capacity to the national grid. With the resolution of a litigation instituted in 2015 against the Commission constraining tariff reviews, the Commission undertook the first review of end-user tariffs based on the Multi-Year Tariff Order ("MYTO") methodology. The tariff order issued further ushered in a revised rate design and the transition to the Service-Based Tariff ("SBT"). We are pleased to note that the initiative improved market revenues by about 20 billion per month thereby improving the financial liquidity of the market and reducing the reliance of the NESI on fiscal support. The SBT regime was designed to not only align rates paid by consumers with quality of service but also to provide an opportunity for segmented investments in load clusters with a view to migrating customers to higher quality of service.In addition, the introduction of the SBT framework improved contractual accountability in the NESI based on the executed Service Level Agreements ("SLA") between the DisCos and the TCN,hence incentivising improved operational performance from all parties. In addressing the liquidity challenge of the industry, the Commission in collaboration with the Central Bank of Nigeria ("CBN") launched two credit facilities (Operating Expenditure - "OpEx" and Capital Expenditure- "CapEx") and the National Mass Metering Project ("NMMP") in 2020. The OpEx facility was to part-finance the DisCos market obligation to NBET and MO arising from under collection under the SBT regime and in line with the approved ramp-up program of the Commission. The CapEx facility was utilised to finance critical infrastructural requirements of the DisCos in line with the DisCos' approved Performance Improvement Plans ("PIPs"). The NMMP on the other hand was launched to rapidly increase meter deployment to end users and thereby close the metering gap in the NESI thereby securing revenue collection for the DisCos and by extension the entire industry. The break of the COVID-19 pandemic presented the Commission with the challenge of service continuity in the industry. In this regard, we are delighted with the outcome of the NESI Situation Room created to monitor and coordinate the provision and continuity of service. We are happy with the positive feedback received from customers during those difficult times and lessons learnt would be applied to emerging challenges in customer care. The Commission has sustained the tempo of its customer engagement through a number of initiatives including but not limited to town hall meetings, radio programs and the social media with a focus on customer services, consumer protection, stakeholder engagements, consumer enlightenment and education. The progress achieved in the industry in the year 2020 notwithstanding, several challenges remain to be resolved. In this regard, the Commission remains steadfast in its commitment to providing the needed regulatory oversight and much-needed interventions that the industry requires to consolidate and successfully transition to a financially sustainable electricity market structure. Sanusi Garba On behalf of the Commission, I wish to express our profound gratitude to the Management and staff of the Nigerian Electricity Regulatory Commission for their support, hard work and dedication which contributed to a large extent our achievements in the year 2020. In conclusion, we wish to acknowledge the trust reposed on us in this call to serve the nation as we commit to doing this with utmost sincerity of purpose and in the interest of public good. Chairman/CEO Nigerian Electricity Regulatory Commission * * * TABLE OF CONTENTS CHAIRMAN'S FORWARD..... ERROR! BOOKMARK NOT DEFINED. PART 1: LEADERSHIP OF THE COMMISSION..... 1 PART 2: EXECUTIVE SUMMARY..... 15 PART 3: CORPORATE ACTIVITIES OF THE COMMISSION..... 34 3.1. The Commission..... 36 3.1.1. Background to the Creation of the Commission..... 36 3.1.2. Principal Objects of the Commission..... 37 3.1.3. Mission, Vision and Motto of the Commission..... 38 3.1.4. Value of the Commission..... 38 3.2. Strategic Plan and Performance Monitoring System..... 42 3.3. Staff Composition..... 51 3.4. Capacity Development..... 55 3.5. Promotion, Awards and Retirement..... 56 3.6. Reporting Obligations..... 56 3.6.1. Quarterly Reports..... 56 3.6.2. * * * 5.1.1. Regulations ..... 89 5.1.2. Orders ..... 89 5.1.3. Guidelines ..... 95 5.2. Licensing and Permits ..... 95 5.3. Certification of Meter Assets/Service Providers ..... 97 5.4. Applications under Evaluation ..... 97 5.5. Public Consultation and Workshop ..... 101 5.6. Compliance Monitoring and Enforcement ..... 102 5.7. Litigation and Alternative Dispute Resolution ..... 103 5.7.1. Litigation ..... 103 5.7.2. Alternative Dispute Resolution ..... 105 PART 6: CONSUMER AFFAIRS ..... 106 6.1 Consumer Education and Enlightenment ..... 108 6.2 Metering of End-use Customers ..... 108 6.3 Customers Complaints ..... 112 6.4 Forum Offices ..... 114 * * * C. Commercial Performance.....151 D. Licence, Permit and Certification.....159 E. Consumer Enlightenment, Metering and Complaints.....163 * * * LIST OF TABLES Table 2.1: Distributions of NERC's Staff by Cadre and Gender .....19 Table 2.2: System Collapse in 2018-2020 .....21 Table 3.1: Summary of Progress Reports on NERC's Strategic Plan 2017-20..44 Table 3.2: Distribution of NERC's Staff by Divisions .....51 Table 3.3: Training, Workshop and Conferences Attended in 2020 .....56 Table 4.1: Total and Partial System Collapses in 2020.....72 Table 4.2: Annual Energy Received and Billed by DisCos .....75 Table 4.3: Annual Revenue Performance of DisCos for 2019 and 2018.....77 Table 4.4: ATC&C Losses for DisCos from 2016 to 2020.....79 Table 4.5: Annual Remittance Performance to NBET and MO by DisCos .....8 * * * Table C.5: Annual Invoice from NBET & MO by DisCos, 2016-2020 .....154 Table C.6: Annual Remittances to NBET and MO by DisCos, 2016-2020 ....155 Table C.7: Annual Shortfalls to NBET & MO by DisCos, 2016-2020 .....156 Table C.8: Total Market Invoice, Remittance & Shortfall by DisCos, 2016-20.157 Table D.1: Generation Licences Issued and Renewed in 2020 .....159 Table D.2: Grant of Permit for Captive Power Generation Issued in 2020.....160 Table D.3: Mini-Grid Registrations and Permits Approved in 2020 .....160 Table D.4: Certification of Meter Assets Providers as at 2020 .....161 Table D.5: Certification of Meter Service Prov * * * LIST OF FIGURES Figure 2.1: DisCos Billing, Collection & Remittance Performance, 2020 .....22 Figure 2.2: Remittances to MO and NBET by DisCos, 2020 .....23 Figure 2.3: Expected and Actual Remittance by DisCos in 2020 .....23 Figure 2.4: Metering Status in NESI as at 31 December 2020.....31 Figure 2.5: Category of Complaints Received by DisCos in 2020.....31 Figure 2.6: Complaints Received by Forum Office during 2017-20.....32 Figure 3.2: Organisational Structure of NERC as at Dec. 2020.....40 Figure 3.2: Distribution of NERC's Staff by Gender.....52 Figure 3.3: Distribution of NERC's Staff by Cadre & Gender.....53 Figure 3.4: Staff Distribution by Age as $ 31^{\\mathrm{st * * * LIST OF ABBREVIATIONS ADR Alternative Dispute Resolution AEDC Abuja Electricity Distribution Co. ANAN Association of National Accounts ATC&C Average Technical, Commercial BCR Business Continuity Regulations BEDC Benin Electricity Distribution Co. BPE Bureau of Public Enterprises CA Consumer Affairs CAPEX Capital Expenditure CAPMI Credited Advance Payment for Implementation CEET Compagnie Energie Electrique CPC Consumer Protection Council DisCos Distribution Companies DSOs Distribution System Operators ECN Electricity Corporation of Nigeria EEDC Enugu Electricity Distribution Co. EKEDC Eko Electricity Distribution Com- EPM Engineering Performance and M EPSR Electric Power Sector Reform FCT Federal Capital Territory FMS Financial and Management Servi GenCos Generation Companies GWh Gigawatt's hour IBEDC Ibadan Electricity Distribution Co. ICAN Institute of Chartered Accountant IEDN Independent Electricity Distributio IKEDC Ikeja Electricity Distribution Co. IPP Independent Power Plant JEDC Jos Electricity Distribution Comp KDEDC Kaduna Electricity Distribution Co. Company Plc Clients of Nigeria & Collection Losses Company Plc Metering U Togo a Company Plc any Plc monitoring services Company Plc Clients of Nigeria on Network company Plc any Plc company Plc company Plc Nigeria * * * MWh Megawatt's hour MYTO Multi Year Tariff Order NACCIMA Nigerian Association of Chambal Industry, Mines and Agriculture NAEE Nigerian Association for Energy NBA Nigerian Bar Association NBET Nigerian Bulk Electricity Trading NDA Niger Dams Authority NEPA National Electric Power Authority NEPP Nigerian Electric Power Policy NERC Nigerian Electricity Regulatory C NESCO Nigerian Electricity Supply Com NESI Nigerian Electricity Supply Indus NICE Notices of Intention to Comment NIGELEC Nigerien Electricity Society NIM Nigerian Institute of Management NIPP National Integrated Power Project NSE Nigerian Society of Engineers PHCN Power Holding Company of Nig PHEDC Port Harcourt Electricity Distribut PRS Planning Research and Strategy REC Regulation on Eligible Customer SBEE Société Béninoise d'Energie Elec TCN Transmission Company of Nigeria TLF Transmission Loss Factor YEDC Yola Electricity Distribution Com ers of Commerce Economics plc y Commission Company Limited entry e Enforcement nt ct eria ion Company Plc trique a Plc company Plc * * * PART 1: LEADERSHIP OF THE COMMISSION * * * 1.1 Board of Commissioners 1.2 General Managers of the Divisions 1.3 Secretary of the Commission 1.4 Members of the Management Staff 1.5 Forum Offices Secretaries * * * 1.1 Board of Commissioners Engr. Sanusi Garba Chairman/CEO (December 2020 to date) Vice-Chairman/Commissioner, Market Competition & Rates (January 2017-November 2020) Sanusi Garba obtained his Bachelor of Engin ("ABU") where he graduated as the Best Find later obtained a Master of Science degree in of Birmingham, UK. ering degree from Ahmadu Bello University Year Student in Electrical Engineering. He Industrial Management from the University His professional career started at the design and standards department of the then National Electric Power Authority ("NEPA") headquarters, Lagos where he was posted for the National Youth Service. Prior to his nomination for the position of Chairman/CEO, Engr Sanusi Garba had served as the Vice Chairman/Commissioner, Market Competition & Rates of the Nigerian Electricity Regulatory Commission, Chief Executive of Katsina Steel Rolling Co. Ltd, and Director (Power) in the Federal Ministry of Power ("FMoP") with responsibility for Generation, Transmission and Distribution aspects of the electricity industry. He has also served as Executive Director (Generation) at the Niger Delta Power Holding Co. Ltd during which he provided technical and commercial leadership for the efficient operation of seven (7) NIPP thermal power plants. Engr Garba has served on many Federal Government Committees including the Presidential Committee on Power Sector Reform (2007/8) and the Presidential Task Force on Power (2009/10). * * * Prof. James A. M Chairman/CEO (May 2018-Nov Momoh ember 2020) James Momoh, a Professor of Electrical Engineering of University, USA was inaugurated as Chairman/CEO of Commission (NERC) on May 3,2018. d Computer Science with Howard the Nigerian Electricity Regulatory A native of Igarra, Edo State, James Momoh graduated with a BSc in Engineering and was top of his class. In 1976 he got the Federal Government of Nigeria's Full Scholarship Award to study for his Masters in Electrical Engineering at Carnegie Mellon University, Pittsburgh, and went on to obtain his PhD at Howard University. As part of the testimonies of his outstanding scholarly imprint, he has published nine textbooks on the modern power system and over 300 published journal articles. His research and academic work span numerous aspects of power systems, communication, and computer engineering. Besides his exemplary academic career, Momoh has distinguished himself as an administrator and manager of resources. He was the Site Director of Power Systems Engineering Research Centre (PSERC) and Programme Director of the National Science Foundation (NSF) where he developed a national initiative for designing Electric Power Network Efficiency and Security (EPNES) between NSF and the Office of Naval Research (ONR) which funded over 40 universities in the US across different disciplines. He attended many professional and developmental courses in Artificial Intelligence, Regulations, Advance Power Systems, Renewable Energy and Policy Studies at MIT, IBM, and Harvard University. He is a recipient of over 30 fellowships, honours and awards such as Fellow of the Nigerian Society of Engineers (NSE); Fellow of the Institute of Electrical and Electronics Engineers (IEEE), Fellow of the Nigeria Academy of Engineering (FAEng) and Fellow of the Academy of Science (FAS), and membership into the 2020 class of NAE with numerous awards and membership of professional associations and societies. * * * Oseni O. Musiliu, PhD Vice-Chairman/Commissioner, Market Competition & Rates (December 2020 to date) Commissioner, Planning Research & Strategy (January 2017-November 2020) Dr Oseni was, until his appointment as the Vice-Chairman/Commissioner, Market Competition & Rates, the Commissioner, Planning, Research & Strategy of the Nigerian Electricity Regulatory Commission. Prior to his nomination as a Commissioner at NERC, he was a Research Associate in Economics and Finance of the Built Environment at the University College London and was previously a researcher at the Energy Policy Research Group, University of Cambridge, UK. Musiliu's research interests cut across Energy and Behavioural Economics, and he was involved in several consulting projects for the energy industry and the World Bank. He was also a lecturer at Al-Hikmah University Ilorin, Nigeria, between 2008 and 2011. He is particularly interested in energy issues relating to access, willingness to pay, affordability, pricing, the security of supply, quality of service, and demand-side management. His research has been published in several peer-reviewed journals, including the Energy Journal, Energy Economics, Energy Policy, Renewable and Sustainable Energy Reviews, and the Journal of Energy and Development. Musiliu holds a PhD in Business/Energy Economics from the University of Cambridge, a Master of Science (distinction) in Energy Economics and Policy from the University of Surrey, UK, and a Bachelor of Science (first class) in Economics from the University of Ibadan, Nigeria. He is currently an honorary research associate at both the Cambridge Energy Policy Research Group (EPRG) and the UCL Faculty of Built Environment. He is a member of the American Economic Association (AEA) and the International Association for Energy Economics (IAEE). * * * Prof. Frank N. Okafor Commissioner, Engineering Performance & Monitoring (January 2017 to date) Professor Okafor was born in Ogidi, Anambra State. He attended the famous Boys Secondary School, Ogidi (1973-1977), where he passed WAEC in Grade 1 Distinction. He later proceeded to the University of Lagos where he earned three degrees: a B.Sc. (Hons.), Electrical Engineering (1984), M. Phil., Electrical and Electronics Engineering (1987) and a PhD in Electrical Power and Control Engineering (1993). He started his career at the University of Lagos ("Unilag") as Graduate Assistant between 1985-1988 during which he developed Computer Aided Control System Design Tools for Research and Training. At the peak of the Grid collapse in the 1990s, he developed a two-area control structure for the Nigerian Power System and deployed a robust non-linear controller for Automatic Generation Control (AGC) to improve grid stability. He was a German Research Foundation Post-Doctoral Fellow at the Technical University of Chemnitz (TUC), Germany, 2000-2001. While there, he designed the fully Controlled Doubly Fed Induction Generator (DFIG) for Wind Energy Conversion, best suited for low, very high wind speeds and emergencies. A foremost Power Software Development Company, DigiSilent GmbH, deployed the scheme as the first standard model for variable speed constant frequency (VSCF) generating Plants based on DFIG. In view of his works, he was appointed staff of Electrical Engineering Faculty at TUC for a brief period. Prof. Okafor was appointed Professor (visiting) at the Technical University Dresden (TUD), Germany (January 2003) with focus on High Voltage Test Techniques for power components. * * * Leadership Electronics Engineering, Unilag from 2008 and appointed Director-General of the Dispute Resolution Panel project in 2010, a position he held till January 2017 when he was appointed a Commissioner in the Nigerian Electricity Regulatory Commission (NERC). He has edited several books and conference proceedings and has over 60 publications in learned journals and conference proceedings. He is an accredited consultant in Evacuation Studies, Power Quality and Environmental Impact Assessment. Prof. Okafor's several awards include the German Research Foundation Fellowship (2000) and Best PhD Thesis Award in Engineering (2011) with his student from National Universities Commission (NUC). He is a registered Engineer, a Fellow of the Nigerian Society of Engineers (2003), a member of IEEE-USA, German Society of Electrical Engineers (VDE) and a fellow of the prestigious Nigerian Academy of Engineering (FAEng). Prof. Okafor is married to Dr Mrs Ogechi Okafor children. and the marriage is blessed with * * * Moses Arigu, PhD Commissioner, Planning Research & Strategy (December 2020 to date) Commissioner, Consumer Affairs (January 2017-November 2020) Dr Moses Arigu obtained his Bachelor of Science and Master of Science degrees from the University of Jos and PhD in Computing & Mathematics from Brunel University, UK with specialization in Heat Equations of Partial Differential Equations - Sequential and Parallel Algorithms. He has published many research papers in international Computer and Engineering journals (also refereed numerous research papers for journals). Some of the mathematical methods he developed have been named after him and are being applied by the National Aeronautics and Space Administration (NASA) and the High-Performance Computing Laboratories in the United States. Dr Arigu has acquired over 25 years of experience in Capital Markets, Technology & Operations, Electricity, Gas and Petroleum industries. He was Assistant Vice President (Credit Suisse and JP Morgan Chase) all in New York. Until his confirmation as a Commissioner at the Nigeria Electricity Regulatory Commission ("NERC"), Dr Arigu was Vice President, GCS Partners at the Royal Bank of Canada. * * * Nathan R. Shatti Commissioner, Finance & Management Services (January 2017 to date) Before his appointment, Mr Shatti was a Management Co an Accountant by training with over twenty-six (26) years Tax,Audit, Finance and Business Management. sultant based in Abuja. He is of experience in Accounting, He graduated with B.Sc. (Hons.) in Accounting from Ahmadu Bello University Zaria in 1990 following which he received professional training at Akintola Williams Deloitte (Chartered Accountants) and qualified as a Chartered Accountant in 1995. He joined Mobil Oil Nigeria plc (a subsidiary of Exxon Mobil) and had a career that spans over thirteen years working in Exxon Mobil subsidiaries in Nigeria, Europe and East Africa. He held various positions of responsibility in the Accounting, Financial Reporting Business Services, Controls, Planning and Finance departments of the company most of which were senior management positions and, in the process, gathered significant international experience in the Oil & Gas industry. He was a former Commissioner for Finance of Adamawa State where he ensured a wellfunctioning Public Financial Management System which promotes Fiscal Discipline, Optimal Allocation of Resources and delivered Value for Money through Efficient and Effective Use of Resources in the Implementation of Strategic Priorities of the State Government. Born in 1967, Mr Shatti is a Fellow of the Institute of Chartered Accountants of Nigeria (ICAN), a member of The Chartered Institute of Taxation of Nigeria (CITN), and an alumnus of INSEAD Business School, France and Lagos Business School (LBS). He is married with children. * * * Dafe C. Akpeneye Commissioner, Legal, Licensing & Compliance (January 2017 to date) Dafe C. Akpeneye is the Commissioner that leads the Legal, Licensing and Compliance Division at NERC. Dafe C. Akpeneye graduated from the Obafemi Awolowo University with a Bachelor of Laws Degree in 2001 and was admitted to the Nigerian Bar in 2003. He worked briefly with the firm of Jude Idigbe & Co. before proceeding to join Ibrahim, Yakubu & Co. in Lokoja for the National Youth Service Corps program. He joined the leading commercial law firm, Ajumogobia & Okeke, upon his return to Lagos in 2004 where he worked until he joined PricewaterhouseCoopers (PwC) global network of firms in December 2005. He led the regulatory services practice at PwC Nigeria and was also the general counsel of the firm in Anglophone West Africa until his resignation on 31 January 2017 to take on the role at NERC following his nomination as a Commissioner by President Buhari. He is a member of the Nigerian Bar Association, Chartered and the Chartered Institute of Arbitrators (UK). nstitute of Taxation of Nigeria * * * Mrs Aisha Mahmud Commissioner, Consumer Affairs (December 2020 to date) Aisha Mahmud obtained her first degree in 1997 from the prestigious Bayero University, Kano, with B.sc honours in Economics and a Master's degree in Business Administration (MBA) from the same University in the year 2000. Following her NYSC in 1998, she joined the private sector as an 'Officer-Commercial Banking' at the United Bank for Africa Plc (UBA) from September 1998 to May 2001 and then moved over to Karama Industrial Ventures where she served as Administrative Officer from June 2001 to May 2003. She transited to the public sector following her early stint in the private sector. From 2003 to 2006 she served as an Administrative Officer at the Federal Ministry of Internal Affairs. She has also worked with the Rural Electrification Agency as Assistant Manager in 2007 before moving to NERC later that year where she served as Manager - Market Analysis and Compliance from June 2007 to May 2010, Principal Manager-Tariff & Rates from July 2013 to May 2018,and Assistant General Manager-Head,Tariff & Rates from May 2018 till November 2020. Aisha Mahmud rose through the ranks in service, gaining experience and expertise in both public and the private sectors, with an array of personal development training cutting across Oil & Gas, Electricity Regulation and Strategy, International Financing Framework and Management, Process Re-engineering, Financial Analysis and Utility Infrastructure Management among others. She is a Utility Regulator with depth in knowledge and experience in the power sector. An expert in tariff and rates design, with immense familiarity with the Nigerian Electricit Supply Industry. Aisha Mahmud is a dedicated, relentless, and proactive achiever with impeccable track records of performance and commitment. * * * 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 acts for the Commissioner in his absence. The under-listed staffs are the General Managers of the Divisions as at 31 $ ^{st} $ December 2020. 31^{\\mathrm{~s\ }} 1. Dr Anthony Akah, $ m n i^{+} $ GM, Research, Planning Research & Strategy (PRS) 2. Mustapha Bukar, $ mni^{+} $ GM, Internal Audit, Chairman's Office (CO) 3. Olufunke Dinneh, $ mni^{+} $ GM, Consumer Affairs (CA) 4. Bassey N. Ayambem $ ^{\*} $ GM, Corporate Planning & Strategy, PRS 5. Dr Usman Abba-Arabi $ ^{\*} $ GM, Public Affairs, CO 6. Sharfuddeen Mahmud GM, Market Competition and Rate (MCR) 7. Abdulkadir Shettima GM, Finance & Management Services (FMS) 8. Abdul B. Mohammed GM, Engineering Performance & Monitoring (EPM) 9. Zubairu T.Ahmadu DGM, Legal Licencing & Compliance (LLC) 1.3. Secretary of the Commission The Secretary of the Commission provides administrative records minutes of the meeting of the Board of Comrn Commission as at 31 $ ^{st} $ December 2020 is ive support, and coordinates and missioners. The Secretary of the 10. Ada Ozoemena DGM, Secretariat, CO 1.4. Members of the Management Staff The General Managers of the Divisions, Se listed members of staff made up the Mana December 2020. Secretary of the Commission and the under-ement Staff of the Commission as at 31st 11. Chinedu Ukabiala DGM, Generation, EPM 12. Maryam Y. Abubakar DGM, Procurement, CO 13. James O. Ewah DGM, Inspectorate, LLC {3^{\\mathrm{r d}}} - Commenced three (3) months retirement leave from 23rd November 2020 - Following the commencement of the 3 months' retirement leave by Dr Anthony Akah, he assumed the position GM, Planning Research as Strategy from $23^{\\mathrm{rd}}$ November 2020 23^{\\mathrm{r d}} - Following the commencement of the 3 months' retirement leave by Olufunke Dinneh, he assumed the position GM, Consumer Affairs from $ 23^{\\mathrm{rd}} $ November 2020 23^{\\mathrm{r d}} * * * 15. Shittu Shaibu 16. Abba I. Terab 17. Chikwerem Obi 18. Tasiu G. Wudil 19. Razak Y. Afolayan 20. Dr Abdussalam Yusuf 21. Abdullah Adamu 22. Aisha Mahmud $ ^{1} $ 23. Arit Uya 24. Michael Faloseyi 25. Kanneng Gwon 26. Zubair B. Zubair 27. Iko Bolus 28. Ene Effiom 29. John D. Joseph 30. Jonathan Okoronkwo 31. Friday E. Sule 32. Abu Kadiri 33. Chuka Akunne 34. Mary Anahve 35. Rasheed Busari 36. Edem Effiom Effiong 37. Habib Kidaji DGM, Customer Service Standards, CA DGM, Tariff & Rates, MCR DGM, Research, PRS AGM, Networks, EPM AGM, Generation, EPM AGM, Research, PRS AGM, Information Communication & Technology, FMS AGM, Tariff & Rates, MCR AGM, Consumer Complaints, CA AGM, Public Affairs, CO AGM, Customer Service Standards, CA AGM, Consumer Enlightenment & Education, CA AGM, Internal Audit, CO AGM, Compliance & Enforcement, LLC AGM, Engineering & Standards, EPM AGM, Corporate Planning & Strategy, PRS AGM, Market Analysis, MCR AGM, Health Safety & Standards, EPM AGM, Human Resources Development, FMS AGM, Public Affairs, CO AGM, General Administration, FMS AGM, Engineering & Standards, EPM AGM, Human Resources Development, FMS The daily activities of the Commission's Forum Offices across Nigeria are coordinated by the under-listed members of staff as Forum Secretaries as at 31st December 2020. 38. Saidu Lawal AGM, Information Communication & Technology, FMS 1.5. Forum Office Secretaries 1. Ifeanyi P. Ezeocha Abakaliki Forum Office, Ebonyi State 2. Sampson Osi 3. Princess I. Okenwa $ ^{1} $ Upon her confirmation as a Commissioner of the Nigerian Electricity Regulatory Commission ("NERC"), she retired as a core staff of NERC in November 2020. * * * 7. Ashiru Abdu Na Abdu Benin Forum Office, Edo State 8. Peter Dickson Birnin Kebbi Forum Office, Kebbi State 9. Temitope Mudasiru Calabar Forum Office, Cross River State 10. Henrietta Ene 11. Bashir Shuaibu Enugu Forum Office, Enugu State 12. Ashiru Abdu Na Abd Gombe Forum Office, Gombe State Gusau Forum Office, Zamfara State 13. Olaiya O. Abe 14. Ibilola A. Olaniun Ibadan Forum Office, Oyo State 15. Kabir Musa Ikeja Forum Office, Lagos State Ilorin Forum Office, Kwara State 16. Ja'afar Ibrahim Jigawa Forum Office, Jigawa State 17. Samuel Andzenge Jos Forum Office, Plateau State 18. Sa'adatu Zaria Kaduna Forum Office, Kaduna State 19. Ja'afar Ibrahim Kano Forum Office, Kano State 20. Ja'afar Ibrahim 21. Abubakar Kurna, Esq Katsina Forum Office, Kastina State Lafia Forum Office, Nasarawa State 22. Ado Jamilu okoja Forum Office, Kogi State 23. Pamela Zakari 24. Afaoma Ubani Makurdi Forum Office, Benue State 25. Kabir Musa Osogbo Forum Office, Osun State 26. Ukongim P. Akubue Port-Harcourt Forum Office, River State 27. Ashiru Abdu Na Abdi 28. Chioma Okechukwu koto Forum Office, Sokoto State 30. Mutari Aliyu uahia Forum Office, Abia State Yola Forum Office, Adamawa State * * * NIGERIAN ELECTRICIT Y REGULATORY COMMISSION PART 2: EXECUTIVE SUMMARY * * * A Corporate Strategy and B State of the Industry C Regulatory Function D Consumer Affairs E Financial Reporting I Structure s * * * CORPORATE STRATEGY AND STRUCTURE: The Nigerian Electricity Regulatory Commission (NERC or the Commission): In 2020, the Commission continued the implementation of its 2017-2020 Strategic Plan focusing on its ten (10) critical goals targeted to addressing the challenges in the Nigerian Electricity Supply Industry ("NESI"). The plan developed in 2017 has overarching objectives of restoration of the sector to financial sustainability, providing adequate and reliable power supply, and improving customer care. The Commission continues to reposition itself to provide robust regulatory interventions as the sector consolidates the transition from a state-owned monopoly to an unbundled competitive electricity market structure. Several private investors were licensed during the year 2020 to operate alongside the successor companies of the unbundled Power Holding Company of Nigeria ("PHCN") with clear licensing terms and conditions aimed at improving the quality of electricity service to consumers. The Co has 7 L sub-div 25 unit Commission Divisions Dived into s Corporate Structure: The Commission maintained the same structure it operated in 2019. However, following the expiration of the tenure of the Chairman/CEO, Professor James Momoh in November 2020, and pursuant to Section 39 and 40(6), Mr President appointed Engr Garba Sanusi (Vice-Chairman and Commissioner, Market Competition & Rates), Dr Musiliu Oseni (Commissioner, Planning, Research & Strategy) and Mrs Aisha Mahmoud (AGM, Tariff & Rates) as the new Chairman/CEO, Vice-Chairman and Commissioner respectively. The Commission continues to maintain its seven (7) Division structure consisting of - the Office of the Chairman, Engineering Performance & Monitoring, Finance & Management Services, Consumer Affairs, Market Competition & Rates, Legal, Licensing & Compliance, and Planning, Research & Strategy. The seven (7) Divisions of the Commission are further sub-divided into a total of twenty-five (25) Units. The Divisions are each headed by a commissioner who is charged with the effective performance and management of the Division. In addition, a management staff not lower than the rank of Deputy General Manager (DGM) * * * coordinates the day-to-day activities to the Commissioner. of each Division and reports Performance Monitoring System: The Commission in 2020, reviewed the implementation of the final phase of its three (3) year strategic plan covering the period 2017-2020. The plan is geared towards the realisation of ten (10) critical goals with periodic reviews to ensure timely and appropriate interventions that may be required. There was an ongoing tracking of the timelines for the completion of the initiatives that were mapped out toward the implementation of the strategic goals. Performance assessments were carried out for all Divisions, Units and staff based on annual evaluation systems that have been standardized for performance monitoring. These assessments formed part of the basis for the 2020 staff promotions and rewards undertaken by the Commission. As at 31 December 2020 the Commission's members of staff consist of 7 Commissioners, 37 Management, 94 Non- Management, & 23 junior staff. Staff Composition: As at 31st December 2020, the count of the Commission's total manpower was 161 broken down as follows - seven (7) Commissioners, thirty-seven (37) Management staff ninety-four (94) non-management staff and twenty-three (23) junior staff spread across the 7 Divisions. The members of staff are a mix of experienced professionals from diverse disciplines ranging from engineering, economics, finance and accounting, social sciences, law, and other fields relevant to the needs of the Commission. The Commission's Management staff cadre (General Manager, Deputy General Manager and Assistant General Manager) and Senior Staff cadre (Principal Manager, Senior Manager, and Manager) account for 71.43% of the total workforce in support of the highly technical work content of the Commission, while the middle-level cadre staff (Assistant Manager and Analysts I-III) account for 13.64%. There is fair gender representation across the cadres as indicated in Table 2.1. Excluding the Junior Staff who are mainly drivers, 31.30% of the professional staff of the Commission are female. The Commission is committed to gender balance and shall continue to inspire female representation both within the Commission and in the industry at large. * * * Table 2.1: Distributions of NERC's Staff by Cadre and Gender | No | Position | Cadre | Total | Male | Female | Female Share | | --- | --- | --- | --- | --- | --- | --- | | 1 | General Manager | Mgt. Cadre | 8 | 7 | 1 | 0.14 | | 2 | Deputy General Manager | " | 8 | 6 | 2 | 0.33 | | 3 | Assistant General Manager | " | 21 | 17 | 4 | 0.24 | | 4 | Principal Manager | Senior Cadre | 27 | 17 | 10 | 0.59 | | 5 | Senior Manager | " | 19 | 11 | 8 | 0.73 | | 6 | Manager | " | 27 | 19 | 8 | 0.42 | | 7 | Assistant Manager | Middle Cadre | 17 | 13 | 4 | 0.31 | | 8 | Analyst I | " | 3 | 0 | 3 | ∞ | | 9 | Analyst II | " | 1 | 0 | 1 | ∞ | | 10 | Analyst III | " | 0 | 0 | 0 | - | | 11 | Junior Staff | Junior Cadre | 22 | 22 | 1 | 0.05 | | | Grand Total | | 154 | 115 | 40 | 0.38 | Note: The staff's distribution in this table excludes the Commissioners and six (6) Aides In 2020, the Commission sponsored s staff to atten face-to-face or/and virtual trainings on subjects that beneficial to statutory responsibili be in come and ual t are to its ties. Capacity Development, Promotion and Exit: The Commission places premium on staff capacity development, and on account of this, some members of staff were sponsored to attend regulatory, management and leadership courses in person in various institutions. However, with the outbreak of COVID-19, the Commission resorted to leveraging Information Communication Technology ("ICT") in conducting and attending virtual meetings, training, workshops and engaging with industry operators. The Commission fulfilled her reporting obligations in 2020 by submitting 4 quarterly reports to Mr President and National Assembly, and audit ed her financial statement for the year ended 31st December 2020 Reporting Obligation of the Commission: In compliance with section 55(3) of the EPSR Act 2004, the Commission has submitted the Q1-Q4 2020 reports of its activities to Mr President and the National Assembly. The reports analyse the state of the industry (covering both the technical, operational and commercial performances), regulatory functions, consumer affairs and the Commission's finances and staff development. * * * STATE THE INDUS OF STRY: In 2020, the total electric energy generated was 35,242,547MWh and the average capacity utilisation rate stood at 66.69%. Operational Performance: The Commission, in line with its mandates derived from the EPSRA, continued the function of regulating the technical and operational performance of the NESI. Available Capacity and Generation: During the year 2020, the available generation capacity of the twenty-six (26) active plants stood at 6,107MW while the average generation was 4,054MWh (5.97% higher than the generation level in 2019). The industry recorded the highest daily peak generation of 5,520MWh on 30th October 2020. The utilisation of the available generation capacity increased to 66.69% in 2020 from 61.30% recorded in 2019. The improved utilisation was due to a reduction in technical and operational constraints relating to inadequate gas supply, water management at the hydropower stations, limited transmission capacity, limitations on distribution networks and commercially induced load limitation by DisCos. Complete resolutions of the technical and operational challenges in the NESI remain a top priority of the Commission. As the Payment Assurance Facility for ensuring that GenCos honour their obligation to gas suppliers comes to an end, the Commission is finalising an Escrow Arrangement for the industry, that will provide payment security for GenCos and gas suppliers pending full activation of contract obligations. The Commission continued consultations with relevant stakeholders to develop lasting solutions to the gas impasse in the power industry. The Commission continued to execute a number of actionable items identified in its strategic plan 2017-2020 to completely resolve the technical, operational and commercial challenges in the NESI. Pursuant to this effort, the Commission has reviewed and approved the relevant and qualified projects of the Performance Improvement Plans ("PIPs") filed by the DisCos for implementation. The PIPs were prepared with the guidelines provided by the Commission, to cover the period 2020-2025 and have an overall objective of ensuring that utilities invest in projects critical to addressing the technical, operational and commercial constraints affecting their efficiency. * * * The total system collapse declined by 60% in 2020 National Grid Stability: A summary of the system stability performance of the national grid for 2018-2020 is contained in Table 2.2. The table shows relative improvement in the stability of the grid network as the number of total system collapses (i.e., total blackouts nationwide) declined significantly in 2020 relative to prior years. The industry recorded four (4) total system collapses in 2020 as compared to ten (10) recorded in 2019. There was no incident of partial system collapse (i.e., failure of a section of the grid) in 2020 as against one (1) partial collapse in 2019. Table 2.2: System Collapse in 2018-2020 | | 2020 Quarterly: | | | | Annually: | | | | --- | --- | --- | --- | --- | --- | --- | --- | | Category | /Q1 | /Q2 | Q3 | /Q4 | 2020 | 2019 | 2018 | | No.of Partial Collapse | 0 | 0 | 0 | 0 | 0 | 1 | 1 | | No.of Total Collapse | 1 | 2 | 0 | 1 | 4 | 10 | 12 | In 2020, DisCos' bir efficiency s at 74.3% collection efficiency w 66.50%. filing stood while was To sustain the improvement in grid stability, the Commission continues to monitor the implementation of its directive to DisCos & TCN to execute Service Level Agreements ("SLAs") that will ensure grid discipline. The Commission, in collaboration with the System Operator ("SO"), intensified its monitoring and supervision efforts to ensure strict compliance with the SO's directives to generators on frequency control mode and free governor in line with the provisions of the Grid Code. Commercial Performance: The financial viabili remains a major priority of the Commission. of the industry Billing and Collection efficiencies: During the year under review, the total billing to electricity consumers by the eleven (11) DisCos stood at N816.16 billion of which only N370.34 billion was collected leaving a total outstanding balance of N542.73 billion. As represented in Figure 2.1, these respectively denote 74.33% and 66.50% billing and collection efficiencies and respectively indicate 8.44 and 1.34 percentage points decline when compared with 2019. The level of collection efficiency indicates that as much as N3.35 out of every N10 worth of energy sold during the year 2020 remained uncollected from customers as and when due. * * * Figure 2.1: DisCos Billing, Collection & Remittance Performance, 2020 In 2020, average remittance performan MO and I for all Dis rose respe to 92.73% 31.39%. the face to NBET Cos actively and Market Remittance: The financial viability of the industry is further assessed with the market settlement rate: Remittance to NBET & MO: During the year 2020, a total invoice of N882.73 billion was issued to the eleven (11) DisCos for energy received from Nigerian Bulk Electricity Trading Plc ("NBET") and for service charge by the Market Operator ("MO"), out of which a sum of N370.34 billion was settled by DisCos, leaving a total deficit of N512.39 billion in the market. This payment represents 41.95% remittance performance, indicating 6.08 percentage points increase from the final settlement rate recorded in 2019 (35.87%). The individual DisCo's remittance performances to NBET and MO settlement during 2020 are represented in Figure 2.2. The individual performance indicates that Benin and Eko DisCos met the expected Minimum Remittance Obligations ("MROs") to MO and NBET, Ibadan met its MRT to NBET while Enugu and Ikeja met their MRTs to MO. The average remittance performances to MO and NBET increased respectively from 78.30% and 28.58% in 2019 to 92.73% and 31.39% in 2020. DisCos' remittance performance levels ranged from 48.39% (Yola) to 100.94% (Benin) for MO,and 10.10% (Yola) to 44.77% (Ikeja) for NBET. * * * Figure 2.2: Remittances to MO and NBET by DisCos, 2020 During year 2020, the DisCos actual remittance of 41.95% to I & MO was 3.88% point lesser than 45.83% expected M adjusted for shortfall al of NBET just RO tariff Noting that tariff shortfall (difference between cost-reflective tariff and allowed end-user tariffs payable by consumers) has partly contributed to liquidity challenges being experienced in the NESI, the settlement ratio and the MROs adjusted for tariff shortfall are represented in Figure 2.3. The figure shows that the remittance performance of DisCos within the timeframe provided for market settlement in the Market Rules is close to the expected market remittance adjusted for the prevailing tariff shortfall in 2020. DisCos' actual remittance of 41.95% was just 3.88 percentage points lower than their expected market remittance of 45.83%. Figure 2.3: Expected and Actual Remittance by DisCos in 2020 * * * The improvement in the DisCos' remittance performance is partly linked to the continuous enforcement of the MRO, and the OpEx loan facility offered by CBN-NESI Stabilization Strategy Limited to DisCos to part-finance the DisCos payment obligations to NBET and MO and their operations to support the transition to the Service-Based Tariff regime. The OpEx loan facility tasks DisCos to ramp up their collections to meet up their subsequent required remittance obligations to NBET and MO,and their OpEx requirement within the tenor of the facility. In 2020, the special customers made no payment while the int'I customer made a total payment of #10.45billion for the invoices issued to them by MO in 2020. Remittances by Special and International Customers: In 2020, the international customers consisting of Societe Beninoise d'Energie Electrique, Compagnie Energie Electrique du Togo, and Societe Nigerienne d'electricite received a total invoice of N16.31 billion from MO and made a total payment of N10.45 billion for the services received from MO.In contrast, no payment was made by the special customers (Ajaokuta Steel Co.Ltd and the host community) in respect of the N0.93 billion and N0.15 billion invoices received from NBET and MO respectively.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 threatening its sustainability. The liquidity challenge is due to a combination of non-implementation of cost-reflective tariffs, high ATC&C losses exacerbated by energy theft and consumers' apathy to payments under the prevailing practise of estimated billing. The outbreak of COVID-19 and its consequential impact in 2020 also compounded the liquidity challenge. DisCos must continue to improve on effort toward reducing ATC&C losses to levels commensurate with their contractual obligations in order to improve sector liquidity and ensure business continuity. Further to this, the non-settlement of energy bills by MDAs across the three tiers of government (i.e., Federal, State and Local Government), which is one of the major contributory factors to high ATC&C losses, and hence poor liquidity, will have to be addressed as part of the ongoing Federal Government's efforts towards ensuring the financial sustainability of the industry. * * * REGULATORY FUNCTIONS: During the year 2020,the Commission commenced the process for the review five (5) exiting Regulations. Regulations: No new regulations were issued during 2020. The Commission continued the monitoring of compliance with the provisions of extant regulations, orders and standards governing the industry. The Commission also initiated the review of the following regulations in the year 2020: b. Meter Reading, Billing, Cash Collections & Credit Management for Electricity Supplies Regulations, 2007. c. Customer Service Standards of Performance for Distribution Companies, 2007. d. Connection & Disconnection Services, 2007. Procedures for Electricity e. Meter Asset Provider Regulations, 2018. Orders: The Commission issued the underlisted orders in 2020: During the 2020, the Commission issued forty nine (49) Orders to t industry operators. year n he 1. NERC/196/2020 on Transitional accounting treatment of tariff-related liabilities in the financial records of market participants in NESI. This Order, among others: a) Provides a guideline for the transitional accounting treatment of tariff-related liabilities in the financial records of the participants; b) Ensures that no new tariff-related liabilities accrue in the financial records of DisCos; and c) Ensures that the balance sheet of DisCos is not adversely impacted by tariff-related revenue shortfall, for the purpose of raising capital for network improvement and service delivery. 2. NERC/197/2020 on the Capping of Estimated Bill in NESI to among others: a) Provide a framework for the billing of unmetered customers thus reducing the risk of arbitrary billing for unmetered Residential (R2) & Commercial (C1) customers at rates that are largely at variance from their actual consumption; b) Expedite the metering of unmetered R2 & C1 customers; c) Steer DisCost towards fast-tracking meter deployment under MAP Regulations or any other financing plan the Commission approved; d) Improve customer satisfaction in NESI and the willingness of customers to pay for electricity by addressing the pervasive apathy for estimated bills issued to unmetered customers, and e) Reduce the incidence of high collection losses in NESI. * * * 3. NERC/198/2020 on the Transition to cost-reflective tariffs in NESI. This Order stipulates that among others: a) There shall be no increase in tariffs of end-use customers on 1st April 2020, and b) The Commission's Orders (NERC/GL/184/2019 to NERC/GL/194/2019) titled 'the December 2019 Minor Review of Multi-Year Tariff Order ("MYTO") 2015 and Minimum Remittance Order for the Year 2020 shall remain in force until 30th June 2020 when a new Minor Review Order shall be issued by the Commission. The Order further provided guidelines for a revised tariff design for DisCos in which customer tariffs are disaggregated and aligned in accordance with the quality of service provided to end-users. 4-14. NERC/198/2020-NERC/208/2020 on the Extra Ordinary Review of Multi-Year Tariff Order ("MYTO") 2015 for DisCos The Orders seek to among other things: a) Ensure that prices charged by DisCos are fair to customers and are sufficient to allow DisCos to fully recover the efficient cost of operation, including a reasonable return on the capital invested in the business; b) Reclassify and disaggregate customers and customer clusters on the basis of DisCos' commitment on the quality of services to customer clusters; c) Ensure that customer tariffs are commensurate and aligned with the quality and availability of power supply committed to customer clusters by DisCos, and d) Develop and implement a framework for enforcing market discipline in respect of market remittances and managing future revenue shortfalls in the industry including minimum market remittance requirements that account for differences between cost-reflective tariffs and allowed tariffs in the settlement of invoices issued by NBET and MO. 15. NERC/209/2020 on the 14-Day Suspension of the Extraordinary Review of MYTO 2020 for DisCos.The Order suspends for a period of 14-days, effective from 28th September to 11th October 2020,the MYTO 2020 that was issued to DisCos. It also ordered that all tariffs for end-use customers and market obligations of the DisCos during the 14-day suspension shall be computed on the basis of rate 2020. applicable as at 31st August 16.26. NERC/198B/2020-NERC/208B/2020 on the Extra Ordinary Review of Multi-Year Tariff Order ("MYTO") 2015 for DisCos The Orders titled "Revised MYTO 2020" repealed the Orders NERC/198/2020-NERC/208/2020 titled 'MYTO 2020' and Order NERC/209/2020 on Suspension of the Extra Ordinary Review of MYTO 2020 for DisCos. The Orders adjusted the tariffs payable by DisCos' customers in compliance with the policy direction on end-user tariff intervention received from the Minister of Power in accordance with section 33 of ESPRA, and the MRTs in accordance with FGN tariffs policy support. The Orders, among others: a) Ensure that prices charged by DisCos are fair to customers and are sufficient to allow DisCos to fully recover the efficient cost of operation, including a reasonable return on the capital invested in the 27-37. NERC/210/2020-NERC/220/2020 on the Amendment of the Order on the Capping of Estimated Bills for the respective DisCos. The Orders amended Order NERC/197/2020 on the capping of estimated bills in the NESI and, among others ordered that: a) Energy caps of unmetered end-use non-maximum demand customers shall be computed based on the weighted averages of prepaid and post-paid metered end-use customers based on actual consumption data of these customers from feeders and distribution transformers; and b) The Commission shall review periodically the meter deployment target achieved by the respective DisCo and shall quarterly review the base data on vending records and supply availability to review the energy caps prescribed in this Order. * * * 38-48. NERC/221/2020-NERC/231/2020 on the December 2020 Minor Review of MYTO 2020 and Minimum Remittance Orders for the respective DisCos. The Orders, among others: a) Reflect the impact of changes in the projected Minor Review variables (i.e., the Nigerian and US inflation rates, gas prices, NGN/US$ foreign exchange rates, available generation capacity, MDA losses and CAPEX adjustment) for the period January to December 2021 for the determination of CRT; b) Implement a framework to manage revenue shortfalls for the year 2021 through MMRR to account for differences between CRT and allowed end-user tariffs in the settlement of invoices issued by NBET and MO; c) Establish the interim payment arrangements and reaffirm the payment securitisation requirement and flow of funds from DisCos to NBET & MO; and d) Steer the market to gradual transitioning to CRT and activation of markets contracts in line with the requirements of the Transitional Electricity Market. 49. NERC/232/2020 on the December 2020 Minor Review of MYTO 2020 for the Transmission Company of Nigeria Plc ("TCN"). This Order has some similar objectives to Orders NERC/221/2020-/231/2020 and also seeks to: a) Reaffirm the obligation of the System Operator to comply with the Economic Merit Order of Dispatch prescribed in the Order towards ensuring compliance with projected least generation cost; b) Reaffirm the obligation of the Transmission System Provider ("TSP") under TCN for the payment of generation capacity charge and loss of revenue to DisCos based on the deviation between energy delivered to a DisCo and the MYTO allocation arising from TCN inability to deliver power to the affected DisCo; and c) Reaffirm the obligation of DisCos for the payment of loss of revenue in favour of TCN in accordance with terms of the Service Level Agreement ("SLA"). During the year 2020, the Commission issued two (2) new guidelines for the industry operators. * * * are freely available on the website of the Commission [www.nerc.gov.ng](http://www.nerc.gov.ng/). Licensing and Permits: Following the their applications, the Commission iss permits and certifications. satisfactory evaluation of ed the following licenses, The nameplate capacity of the generation licences and permits issued by Commission totalled 667.70MW in 2020 while 33 MAPs and 17 MSPs were approved and certified respectively. - Five (5) new and three (3) renewed generation licences with capacities of 235MW and 346MW respectively. The new licences include on-grid, off-grid and embedded generation. - Two (2) new Independent Elec ("IEDN") Licences. ricity Distribution Network - Nine (9) new permits for Captive Power Generation ("CPG") spread across Nigeria with a total capacity of 86.70MW. - Seven (7) new Meter Assets Providers ("MAPs") making the total certified MAPs in NESI to be thirty-three (33) as at 2020. The Commis handle existing enforcer cases by forward the prece year. ment sought fromeding - Seventeen (17) Meter Service Providers ("MSPs") comprise eight (8) meter installers, five (5) meter importers, three (3) meter manufacturers and one (1) meter vender. In addition to the licences and permits that were issued during the year 2020, other applications are under evaluation by the Commission for renewal or issuance as may be applicable. Compliance and Enforcement: Enforcement actions against violations, breaches and infractions of regulations, orders and technical codes of the NESI are key mandates of the Commission. In this regard, the Commission, during the year, continued with enforcement actions brought forward from the preceding year against some licensees for violations of rules and infractions. These include failure to submit required data within stipulated timelines, electric accidents and electrocution cases, and the failure to adhere to forum decisions without filing appeals within the stipulated timeframe. * * * CONSUMER AFFAIRS: In 2020, the Commission organised on physical and several virtual town hall meetings to enlighten and address key issues affecting electricity consumers. e (1) I I ng Only 39.40% of the registered electricity customers have been metered as at 31 December 2020. 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 2020 relative to their proposed schedules for the year. On its part, the Commission continued a radio enlightenment program titled "Electricity Update" which is being aired on local radio stations in each of the 36 states and FCT, Abuja. This is in addition to the virtual town hall meetings held with electricity consumers to educate them on customer rights and obligations, MAP and NMMP schemes, health & safety etc. Only 2 DisCos had metered more than 50% of its registered electricity customers as at December 2020. Metering: During the year 2020, additional 537,400 end-use customers' meters were installed. This is significantly greater than the 334,896 meters installed in 2019 (60.47% increase). The recorded improvement in metering in 2020 was due to the Commission's successful effort in reducing the bottlenecks hitherto hampering the deployment of meters under the MAP scheme and subsequent deployment of meters under NMMP. Despite the huge metering gap for end-use customers is still a key challenge in the industry. The records of the Commission indicate that, of the 11,841,819 registered energy customers as at 31 December 2020, only 4,666,191 (39.40%) have been metered. Therefore, 60.60% of the registered electricity customers are on estimated billing contributing to apathy toward payment for electricity bills. A review of the customer population data in Figure 2.4 indicates that only Eko, Ikeja, Kano and Kaduna DisCos recorded progress in the percentage of metered customers in 2020 when compared to 2019. 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 were computed based on three-month data of actual consumption records of metered customers according to customer class and tariff band. The Commission also continues monitoring meter deployment under MAP and NMMP. * * * Figure 2.4: Metering Status in NESI as at 31 December 2020 Metering a billing still dominated customer complaints accounting 44.87% of total comp received in 2020. and the for the laints Customer Complaints: In 2020, the eleven (11) DisCos received 857,108 complaints from consumers, which is 32.16% more complaints than those received in 2019 (648,537 complaints). This amounts to an average of 2,348 complaints/day. In total, the DisCos attended to 799,236 complaints representing 93.25% resolution rate. Benin, followed by Eko DisCo had the lowest resolution rates of 84.96% and 89.14% respectively based on the proportion of complaints not addressed in 2020. A review of the customer complaints data represented in Figure 2.5 indicates that metering, billing and service interruption are the prevalent sources of customer complaints, accounting for 62.73% (i.e. 537,642) of the total complaints in the year. * * * Like complaints categories of DisCos CCUs, metering and billing dominated customers' complaints at Forum Offices. Over 90.21% of the cases that got to the Forum Offices in 2020 were resolved. Forum Offices: Forum panels review unresolved disputes at DisCos Complaint Handling Units, as enshrined in the Commission's Customer Complaints Handling Standards and Procedure ("CCHSP") Regulations. The chart in Figure 2.6 indicates that in 2020 the Forum Offices had a total of 8,438 complaints (plus the pending complaints of 1,258 in 2019) from customers who were dissatisfied with DisCos' decision on their lodged complaints. Billing and metering issues dominated the category of complaints received by the Forum Offices. This implies that billing and metering issues were mostly the complaints not satisfactorily resolved by DisCos' Complaints Handling Units during the year under review. Figure 2.6: Complaints Received by Forum Office during 2017-20 During the period, the Forum panels held 115 Hearings and 7,612 (90.21%) of the complaints lodged at Forum Offices nationwide were resolved either through Hearings or preliminary engagements between the Forum Secretaries and the concerned DisCos - this represents a 45.76 percentage points increase in the resolution rate compared to 44.45% average of the prior 3 years (2017-2019). Furthermore, 36 (4.36%) out of the 826 unresolved cases in 2020 were a result of incomplete submission and/or withdrawal of complaints by consumers.The Commission continues to monitor the operation and efficacy of its Forum Offices to ensure quick resolution of all outstanding and new complaints in line with the Forum Offices operating manual. * * * In 2020, there were reported 40 deaths and 76 injuries of various degrees involving both employees of utilities and third parties. Health and Safety: The Commission received a total of 456 accident reports from industry operators during the year as against 364 reports received in 2019 (92 more complaints received in 2020). The accidents, unfortunately, resulted in 40 deaths and 76 injuries (compared to 42 deaths and 77 injuries in 2019) of various degrees involving both employees of the companies and third parties. 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 accidents in the NESI. The programs being implemented include but not limited to, public enlightenment on the safe use of electricity, the standardisation of system protection schemes, a review of operational procedure for Distribution System Operators ("DSO") on fault clearing, and engagement of stakeholders on Right of Way ("ROW") violations. FINANCIAL REPORTS: Results at a Glance: The summary of the audited financial statement of the Commission in Table 2.3 indicates that the total revenue the Commission realised from operations in 2020 was N14.25 billion compared to N12.52 billion realised in 2019 (13.79% increase). Similarly, the total expenditure of the Commission increased by 6.60% from N10.42 billion in 2019 to N11.10 billion in 2020. A comparison of the revenue and expenditure (excluding the Commission's outstanding liabilities) indicates a positive net cash flow of N4.11 billion in 2020- this represents a 4.43% decrease compared to 2019 (N4.30 billion). The efficient and prudent management of the Commission's cash flow is a key priority just as its regulatory interventions are to improve industry liquidity. | Description | | --- | | Income generated from operations | | Total expenditure | | Surplus for the year | | Amount payable to Rural Electrification Fund (REF) | | Total Comprehensive (loss)/income for the year | | Retained earnings | | Total Reserves | \| 2020 N' 000 \| 2019 N' 000 \| % Change change \| \| \-\-\- \| \-\-\- \| \-\-\- \| \| 14,245,028 \| 12,518,662 \| 45 \| \| (11,103,784) \| (10,416,720) \| 44 \| \| 4,114,358 \| 4,304,965 \| (4) \| \| (3,825,270) \| (1,803,267) \| 112 \| \| (114,796) \| 3,250,470 \| (104) \| \| 2,872,507 \| 2,708,319 \| 6 \| \| 18,837,789 \| 18,952,584 \| (1) \| Table 2.3: Results at a Glance of the 2020 Auditor's Report * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION NERC PART 3: CORPORATE ACTIVITIES OF THE COMMISSION * * * 3.1 The Commission 3.2 Strategic Plan and Performance Monitoring 3.3 Staff Composition 3.4 Capacity Development 3.5 Promotion, Awards & Retirement 3.6 Reporting Obligations * * * 3.1. The Commission 3.1.1. Background to the Creation of the Commission Persistent issues (of poor access to electricity, low accessibility, high technical and commercial losses, low power generation capacity, inadequate transmission and distribution facilities, ineffective regulation, non-cost reflective tariff, and inefficient use of electricity by consumers) in the Nigerian Electricity Supply Industry ("NESI") led to the decision of the Federal Government to embark on power sector reforms. The reforms aim to liberate the power sector from the lingering problems and attract much-needed private sector investment. The Nigerian Electric Power Policy ("NEPP") released by the Federal Government in March 2001 and subsequently adopted in 2002 kicked off the power sector reform in Nigeria. A major step taken towards reforming the enactment of the Electric Power Sector R was recorded as a critical milestone in the sector. The EPSRA gave legal authority and repealed all previous legislation on the pow power sector took place in 2005 with Reform Act ("EPSRA" or the "Act"). This transformation of the Nigerian power support to the ongoing reform and also sector. More importantly, Section (31) of the EPSRA provides Nigerian Electricity Regulatory Commission ("NERC) Commission, which was officially inaugurated on the headquarters in Abuja, serves as an independent way to drive the power sector reform by ensuring fairness playing field for all investors and the customers. for the establishment of the or the "Commission"). The 31st October 2005 with its chdog and regulatory body s, transparency and a level 31^{,\\mathrm s{}\\dagger} * * * Since its inception, the Commission has cor regulatory intervention as the power sector to a more competitive market structure. inued to position itself to give robust transits from a state-owned monopoly 3.1.2. Principal Objects of the Commission The principal objects of the Commission outlined under section 32 (1) of the EPSRA are listed below; 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 acces consumer connecti s to electricity services, by promoting and facilitating ns 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 a sufficient to allow the licensees to finance the reasonable earnings for efficient operation; e fair to consumers and are activities and to allow for e) To ensure the safety, security, reliability, production and delivery of electricity to consumers. and quality of service in the owners; f) To ensure that regulation is fair and balanced for licensees, consumers investors, and other stakeholders and; In furtherance to the objects highlig following functions outlined in Section ed above, the Commission performs the 32 (2) of the EPSRA as follows: c) Establish appropriate con provision and use of electric umer rights and obligations regarding thly 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. Lastly, in compliance with Section 32 (3), the Commission, in the discharge of its functions, consults from time to time, and to the extent, the Commission considers appropriate, such persons or groups of persons who may or are likely to be affected by the decision or orders of the Commission including, but 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 The Commission has four (4) guiding values: Leadership: Excellence, transparency, courage and discipline; Good Governance: Making da in compli decisions in a fair, transparent and consistent manner,ince with the laws of Nigeria and our regulations. Professionalism: Proficiency, diligence, respect, fairness and accountability; * * * 3.1.4. Structure of the Commission The Commission maintained its organisation the most of 2020. The structure seeks to all and authority along functional lines and state that have the requisite skills and expect appropriately. The structure is made up of se into twenty-five (25) Units. al structure as in the previous year for now an adequate flow of responsibility acting with professionally qualified staff hence to carry out their functions then (7) Divisions which are sub-divided Following the change in the composition of the Board of the Commissioners in December 2020 upon the exit of Chairman James Momoh, the organisational structure of the Commission was slightly adjusted. The adjustments involved the relocation of the Inspectorate and Tactical Unit ("ITU") formerly under the Chairman's Office ("CO") to the Legal Licencing and Compliance ("LLC") Division and renamed Inspectorate Unit ("IU"). The Registry Unit ("RU") formerly under the CO was relocated to a newly created General Administration Unit ("GAU") domiciled in the Finance and Management Services ("FMS") Division. The Regulatory Financial Reporting & Analysis Unit ("RFRAU"), which hitherto was under the FMS Division, was relocated to the Market Competition and Rates ("MCR") Division. (^{\\prime}\\mathrm{C O^{\\prime\\prime}}) (^{\\prime\ }!C^{\\prime\\prime}) ({}^{\\prime}\\mathsf{G A U^{\\prime\\prime}}) (^{\\prime\\prime}\\mathsf{R U}{^{\\prime\\prime}}) & Notwithstanding the restructuring, the current or Commission represented in Figure 3.1 is still made u are sub-divided into twenty-five (25) Units. anizational structure of the of seven (7) Divisions which * * * Corporate Information Figure 3.2: Organisational Structure of NERC as at Dec. 2020 Nigerian Electricity Regulatory Commission * * * 1. Board of Commissioners: The Board is responsible for the leadership of the Commission. 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. 2. Chairman's Office ("CO"): This D provide overall governance and Commission. The Units are Secreta Procurement. vision is made up of four (4) units that coordination of the activities of theiat, Public Affairs, Internal Audit, and 3. Engineering Performance and Monitor with developing technical standards technical codes & standards by all or responsible for the technical evaluation to the Commission. ng ("EPM"): This Division is tasked and monitoring compliance with operators. In addition, the Division is of all licence applications submitted 4. Legal, Licensing and Compliance ("LLC"): This Division is responsible for coordinating and evaluating licence applications before the Commission. It provides legal support and advisory services to the Commission.The Division is also in charge of hearings, resolution of disputes through alternative dispute resolution mechanisms, and the enforcement of all Commission's Orders and decisions. 5. 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 planning and strategy of the Commission and monitors the status and emerging trends in the electricity industry. This is with a view to developing and updating regulatory regimes and policies that would increase and promote investments and access to electricity.The Division also prepares the quarterly and annual reports of the Commission and provides it with the required database and policy instrument to carry out its various activities. 6. 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. Moreover, it is responsible for consumer enlightenment programmes and has the mandate of ensuring speedy resolution of customer complaints by DisCos. The Division is also responsible for the management of the Commission's Forum Offices. 7. Finance and Management Services ("FM services to the Commission in critical accounts, asset administration, human information technology. (5"): This division provides support areas that include finance and capital development, and 3.2. Strategic Plan and Performance Monitoring System 1. Creation of a financially viable electricity market; The Commission in the year 2020, continued with the implementation of its Strategic Plan which covers 2017-2020. The plan is intended to drive improvements and growth within the Commission as an institution and the Nigerian Electricity Supply Industry ("NESI"). Specifically, the plan provides for the realisation of the under-listed ten (10) critical goals with effective performance monitoring systems while ensuring a fair and firm regulatory environment: II. Metering for all customers within three years; III. Effective compliance monitoring & enforcement; IV. Institutionalise code of corporate governance; * * * Corporate Information V. Recapitalisation of licensees in the sector; 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. Enhancement of safety standards; X. Development of improved customer care standards. These goals are not only applicable within the context of the overall objects of the Commission as outlined in Section (32) of the EPSRA but are also consistent with the overarching policy directives issued by the Federal Government of Nigeria in line with Section (33) of the EPSRA. In the year 2020, the Commission continued to strive to achieve these ten (10) critical goals. Table 3.1 presents the details of the progress so far made in implementing actions towards achieving the ten (10) critical goals as at 31st December 2020. * * * Corporate Information Table 3.1: Summary of Progress Reports on NERC's Strategic Plan 2017-20 | Goals | Actionable items to Achieve Goals | Timeline | Achievements/Actions Taken as at 2020/Q4 | Remarks | | --- | --- | --- | --- | --- | | 1\. Creation of a financially viable electricity markets | a Forensic audit of collection, disbursement and utilisation of market funds | 2017/Q4-2020/Q4 | ·The Commission has concluded the procurement of four suitable firms. However,the commencement of the audit has been stalled by Court action. | Behind target | | b Development of equitable bases for the appropriation and disbursement of market funds | 2018/Q1 | ·The Commission introduced the Minimum Remittance Obligation for the DisCos. | | | | ·Also,the Commission has commenced a payment securitization system that escrow all DisCos collection with the CBN and ensures equitable disbursement across the value chain. | On track | | | | | c Review of MYTO methodology with a view to reducing regulatory lag and accumulation of deficits | 2017/Q4-2018/Q4 | ·Since June 2019,the Commission has consistently carried out minor reviews of the MYTO to reflect changes in four key exogenous variables-exchange rate, inflation,gas prices and available capacity.The previous review was delayed by Court action. | | | | ·The last minor review for the year 2020 was done by the Commission in December 2020. | | | | | | ·The Commission has commenced an extra-ordinary review of MYTO that is based on quality of service | On track | | | | | d Introduction of Uniform System of Accounting(USoA)for all licensees | 2018/Q1 | ·The USoA Regulations were issued in 2018/Q1 and are now binding on all licensees. | | | | ·The staff of the Commission and the licensees have been trained on the application of USoA | | | | | | ·The Commission has consistently been issuing the quarterly report of the USoA | On track | | | | | e Tariff affordability study in support of tariff design for the industry | 2018/Q3-2018/Q4 | ·The commission has finalised the Terms of Reference (“TOR”)to engage a consultant that will conduct the study on behalf of the Commission.The study is expected to be finalised by 2021/22 | Behind target | | * * * | Corporate Information | | | --- | --- | | f. Comprehensive customer enumeration incl. geotagging to distribution assets | 2018/Q4 | | g. Detailed and periodic review of revenue requirements of licensees for completeness and prudence | Continuous | | h. Work with all stakeholders for the development of an integrated resource plan | 2019/Q4 | | i. Development and implementation of a new framework to ensure timely settlement of bills by MDAs | 2017/Q4-2018/Q2 | | j. Development of PCAF regulations | 2017/Q4-2020/Q2 | \| In 2018Q1, all DisCos were mandated to carry out customers' enumeration to identify the metering gap. The exercise is still ongoing as some DisCos requested for an extension to allow the coverage of all unregistered consumers of electricity and brought the same customers onto their billing platform | Additional 1,467,240 electricity customers were registered in 2020 | On track | | --- | --- | | The PIPs covering the period 2020-2025 submitted by the licensees based on the guidelines issued by the Commission have been approved. | On track | | The approved PIPs now form the basis of the revenue requirement of the respective licensee for completeness and prudence | On track | | The Commission will use the approved PIPs as one of the bases for the implementation of the SBT | Behind target | | Reviews of the distribution expansion plan, transmission plan and generation adequacy reports are ongoing. | | | Review of interphase point challenges is ongoing | | | The next phase would follow immediately after the completion of the review | Behind target | | Concept paper has been presented to Policymakers | | | Several conversations were held with the relevant stakeholders-Ministries of Power and Finance,DisCos,NBET,etc. | Behind target | | Comprehensive audit has been carried out to ascertain unsettled MDAs debt | Behind target | | Some payments have been processed for disbursement to DisCos and a framework to address outstanding MDSs debt is being finalised. | Behind target | | Consultant (Messrs CPS consulting) report on PCAF has been reviewed by the tariff committee and recommendation made to the Commission on the way forward in view of the current service-based tariff | Behind target | * * * Corporate Information | | kDesign and install data aggregation and revenue assurance system | 2018/Q4-2020/Q4 | | --- | --- | --- | | all20 | aEnforce the order that no new connection to customers should be made without appropriate meters | Continuous | | | bDevelopment of alternative customers metering framework | 2018/Q1 | \| The Commission, with the support of USAID, has developed new data collection templates based on the identified data required for effective regulation With the help of NIAF, the Commission has migrated some of its historical data into the new templates The Commission has developed TOR for procurement of consultants to help set up a temporary automated data gathering system pending the installation of a near real-time data aggregation system The World Bank has started the procurement process for the appointment of consultants for the data aggregation An Order that all new customers must be metered before connection is in place and being enforced Also, the Commission has been issuing Orders on the Capping of Estimated Bills to protect customers that are yet to be metered from overbilling The Meter Assets Provider (MAP) Regulations, which allow DisCos to engage a third party to fast-track the roll-out of meters were issued in 2018/Q1. Meters deployment commenced in 2019/Q1 by the MAPs with permits procured by the DisCos The FGN in collaboration with CBN and the Commission launched National Mass Metring Project (“NMMP”) in 2020 to increase meter deployment in order to close the metering gap in NESI and ensure the successful implementation of the SBT. Meter deployment under NMMP started in October 2020. | The Commission has finalised the review of the MAP Regulations (2018) into the MAP and NMMP Regulations that provides a framework which allows a smooth and concurrent implementation of both MAP | | --- | 2. Metering of all customers by 2020 * * * Corporate Information | | cDevelopment of alternative customer metering framework-Community Choice Aggregation Model&Franchising | 2018,3 | | --- | --- | --- | | 3\. Effective compliance monitoring&enforcement | aCreation and staffing of compliance units | 2017,2018,3 | | 4\. Institutionalise code of corporate governance | aIssuance of code of corporate governance for all licensees | 2018,3 | | | bReview of the current status of the key management staff of the licensees in compliance with‘Fit&Proper’ regulation | Continued | | | cDevelopment of regulation on procurement-prudence and mitigation of related party transactions | 2017,2018,3 | | | dDevelopment of Business Continuity Strategy | 2017,2018,3 | \| TQ3 \| benefits of both schemes are obtained to close the metering gap in the NESI on time Guidelines for sub-franchising DisCos operations and coverage areas to a third party for investment in metering, billing, collection, rehabilitation and expansion of networks were released in 2020 \| Behind target \| \| \-\-\- \| \-\-\- \| \-\-\- \| \| TQ4-Q1 \| The Inspectorate and Compliance units were created in 2017/Q4 and are currently domiciled in the Legal, Licencing & Compliance division of the Commission Following the internal call for applications, some of the vacant positions in the Unit were filled by staff More staff will be recruited to the unit in due course \| Behind target \| \| TQ1 \| The final draft guidelines incorporating the twenty-eight (28) principles of the National Code of Corporate Governance adapted to the NESI have been prepared and are undergoing review \| Behind target \| \| uous \| The Commission continuously reviews the status of the key management staff of the licensees Also, as a continuity plan, the Commission has conducted KYL for potential management staff that may take over from the DisCos' current management staff in the event of force majeure/change of ownership \| On track \| \| TQ4-Q2 \| The draft NESI national code of corporate governance developed by the Commission already incorporated the sector-specific guidelines on procurement \| On track \| \| TQ3-Q2 \| The Commission finalised the Consultation Paper on Business Continuity and subjected same to public consultations with stakeholders including investors, market participants (NBET, GenCos, DisCos, network operators), and consumer groups. \| Behind target \| * * * Corporate Information NERC Annual Report 2020 | 5\. Recapitalisation of licensees in the sector | aReview of audited accounts (ended 31 December 2016) of DisCos and other related regulatory filings | 2018/Q1 | DisCos' audited accounts are continuously reviewedThe Commission is planning to review of the revenue requirements of the DisCos. This is targeted for 2021 for subsequent implementation upon the expiration of the performance agreement | Behind target | | --- | --- | --- | --- | --- | | bProcurement of management consultants for the review and recommendation of recapitalisation | 2018/Q1-2018/Q4 | This has been scheduled for 2021 upon the expiration of the performance agreement | Behind target | | | cConsultations and issuance of an order for the implementation of recommendations on capital-base | 2018/Q4 | Pending | Behind target | | | 6.Sustained growth in availability & quality of supply | aCommittee of stakeholders to evaluate the investments required by TCN and DisCos at all TCN/DisCo interface points | 2017/Q4-2018/Q2 | Emtech was engaged to evaluate investments required at TCN/DisCos interface points and a committee was then set up to review Emtech reports.The Commission is currently reviewing the findings submitted by the Committee for necessary actions | Behind target | | bMeasurement of availability of electricity nationwide associated quality of service-SAIDI and SAIFI indices | 2018/Q2 | Data loggers have been installed while data collection for baseline study and benchmarking is ongoingProcurement/deployment of additional real-time monitoring devices ongoing | Behind target | | | 7.Enhancement of the nation's security of supply of electricity | aDevelop regulatory guidance and recommended policy support for the realisation of coal-to-power generation and on-grid renewable | 2018/Q2 | Discussion with policymakers ongoing | Behind target | | 8.Promotion of local content and manpower development in NESI | aAllow licensees sufficient funding under revenue requirement filling for human capacity development for licensees | 2018/Q4 | Minimum Remittance Obligation allows DisCos to earn revenue requirements subject to efficient performance | On track | | | bEvaluate the capacity gaps within the Commission and identify relevant training and recruitment and placement plan | 2017/Q4-2018/Q2 | Capacity gaps identified.There is continuous training and retraining of staffThrough the manning and fitting exercise conducted,the Commission has continued to conduct reallocation and realignment of staff for effective service delivery | Behind target | * * * | Corporate Information | | | --- | --- | | c | Review and update the draft regulation on national content in NESI 2018/06 | | 9\. Enforcement of safety standard | aDevelop a framework to ensure effective enforcement of the safety codes issued to licensees2018/06 | | • Standardisation of protective schemes at 11KV & 33KV levels2018/06 | | | • Engagement of government agencies on RoW violation2018/06 | | | • Public Enlightenment on safety2018/06 | | | • Review of operational procedures for DSOs on fault clearing2018/06 | | | • Monitoring of networks for optimal involvement2018/06 | | | • Work with NAPTIN for the certification of distribution and transmission system operators and safety professionals in NESI2018/06 | | | • Push for the rehabilitation of the SCADA system2018/06 | | | b | Partner with NEMSA to revise design and standards for construction/installations at the distribution level2018/06 | | Q1-2 | • In 2019/Q1, the Commission held a 2-day stakeholders’ workshop on minimum specification of Nigerian content and requirement for labour in NESI• The workshop sensitises stakeholders on the existence of the Regulation of national content development (2014) for NESI• The Commission has appointed new members to the Nigerian National Content Consultative Forum (NNCCP) for continuous monitoring and evaluation of local content participation in NESI | On track | | --- | --- | --- | | Q1-4 | The under-listed were initiated during 2018/Q1-Q4 and work is still ongoing.• The Commission is developing a framework for the standardization of the distribution network which will include the protective schemes and the 11KV and 33KV feeders• The Commission is about to finalise the framework for the training certification of SOs and DSO and Safety Practitioners in NESI. | Behind targetOn trackOn track | | | • Implementation scheduled for 2021• Implementation scheduled for 2021• Procurement is ongoing – TCN procurement is ongoing while Disco (Eko) has almost completed testing | Behind target | | Q1-3 | • The Commission, in collaboration with NEMSA and other stakeholders, is working on a framework that would ensure the standardization of distribution networks, in particular, for constructions/installations | Behind target | * * * | | Corporate Information | | | --- | --- | --- | | | cOrder all distribution licensees to undertake remedial works on their existing feeder lines that are below standard | 2018/2018/ | | 10\. Review of standards for customer care | aReview the existing customer care standard for NESI | 2018/ | | | bLunch IT platform for monitoring customer complaints handling | 2017/2018/ | | | cReview the roles of the Forum in customer complaint/resolution in order to make Forum Offices more effective | 2018/ | | Q1- Q3 | The Commission is considering supporting DisCos to receive loans from CBN to facilitate remedial works on DisCos' existing feeders in line with their approved PIPs | On track | | --- | --- | --- | | Q2 | In 2018/Q1, the Commission set up a committee to handle the review process of the existing customer care standard. The Committee made substantial progress and engaged several stakeholders to make contributions. Further review is ongoing to guide the final decision-making by the Commission. | Behind target | | Q3- Q2 | The Commission has successfully developed an IT Complaints Handling System (CHS) which has been test-run. However, for the platform to reflect current realities and be a best practice framework for addressing customer complaints, the Commission requested some modifications from the consultant. | | | The Commission is training its key staff for effective management of the platform. | | | | It is expected that this process and the formal launch of the platform would be completed in earnest. | Behind target | | | Q1 | This review is being done continuously | Behind target | * * * 3.3. Staff Composition As at 31st December 2020, the count of the Commission's total manpower was 161 broken down as follows - Chairman/CEO, Vice Chairman, five (5) Commissioners; thirty-seven (37) Management Staff, ninety-four (94) non-Management staff, and twenty-three (23) Junior staff. The Commissioners and members of staff, which collectively, have been able to discharge the needed regulatory duties, are made up of experienced professionals from diverse disciplines ranging from engineering, law, economics, accounting and finance, amongst others. The distribution of staff by Divisions, Cadre, Gender, Positions, Age and Geopolitical Zones is presented below. - Distribution by Division: Following the restructuring of the Commission's Divisions carried out in 2017 and the subsequent redeployment of a few members of staff in 2018,2019,and 2020, the distribution of staff across the Divisions is presented in Table 3.2. The Finance & Management Services Division, due to the nature of its activities and the number of Units it oversees, has the highest number of staff followed by the Consumer Affairs Division which coordinates all the Forum Offices. The Market Competition & Rates division,which has three Units,has the least number of staff. | S/N | Divisions | Number of staff | Percentage Share(%) | | --- | --- | --- | --- | | 1 | Chairman's office | 17 | 11.04 | | 2 | Finance&Management Services(Including Junior Staff) | 42 | 27.27 | | 3 | Market,Competition&Rates | 9 | 5.84 | | 4 | Consumer Affairs(including Forum Offices) | 41 | 26.62 | | 5 | Legal Licensing&Compliance | 12 | 7.79 | | 6 | Engineering,Performance&Monitoring | 22 | 14.29 | | 7 | Planning,Research&Strategy | 11 | 7.14 | | | Total | 154 | 100.00 | Notes of the table: The staff's distribution excludes the Chairman, Vice Chairman, 5 Commissioners and 6 Aides. * * * Corporate Information - Distribution by Cadre: The distribution of staff by cadre presented in December 2020, the Commission has thirty-sev (representing 24.03%) , seventy-three (73) mid 47.40%) , and forty-four (44) lower level and jun table 3.3 shows that as at 31st in (37) senior management staff management staff (representing or staff (representing 24.55%). Table 3.3: Distribution of NERC's Staff by Cadre | S/N | Position | Num | | --- | --- | --- | | 1 | General Manager | | | 2 | Deputy General Manager | | | 3 | Assistant General Manager | | | 4 | Principal Manager | | | 5 | Senior Manager | | | 6 | Manager | | | 7 | Assistant Manager | | | 8 | Analyst I | | | 9 | Analyst II | | | 10 | Analyst III | | | 11 | Junior Staff | | | | Total | | | Number of Staff | Cadre | Percentage share | | --- | --- | --- | | 8 | Mgt. Cadre | 24.03% | | 8 | " | | | 21 | " | | | 27 | Senior Cadre | 47.40% | | 19 | " | | | 27 | " | | | 17 | Middle Cadre | 13.64% | | 3 | " | | | 1 | " | | | 0 | " | | | 23 | Junior Cadre | 14.91% | | 154 | All Cadre | 100.00% | Notes of the table: The staff's distribution excludes the Chairman, the 6 Commissioners and 6 Aides - Distribution by Gender: The Commission is committed to diversity and inclusion in its policy as can be seen in the gender representation of its workforce in Figure 3.2. Excluding the junior staff who are mainly drivers, approximately 31.30% of the professional workforce of the Commission were females as at 31st December 2020. * * * Figure 3.3: Distribution of NERC's Staff by Cadre & Gender Figure 3.3, which indicates a fair representation average of 36.11% ranging from a minimum cadre) to a maximum of 100% (of the Analyst of the Commission acknowledges the key role w is committed to increasing their participation. m of females in each cadre with an 12.50% (of the General Manager cadre), further buttresses the fact that men play in the power sector and it - Distribution by age: The review of the age groups of the staff of the Commission represented in Figure 3.4 indicates that the Commission has only one (1) staff below the age of 35 years and approximately 86.36% of the staff is 40 years above.Based on the 60 years mandatory retirement age for public servants, at least twenty-two (22) staff are to retire within the next 5 years and another thirty-three (33) staff are to retire within 10 years.As highlighted in the preceding Annual Report,the Commission notes the importance of succession planning in the organisation and has developed a strategy for succession which includes the recruitment of suitably qualified Nigerians to join its workforce in due course. * * * Figure 3.4: Staff Distribution by Age as at 31st December 2020 - Distribution by Geo-political zone: The composition of the staff of the Commission by geo-political zone as at 31st December 2020 is represented in Figure 3.5. The Figure shows that 23.38% of the total workforce of the Commission are of South-South origin. This is followed by the North Central region with 21.43%. On the other hand, however, the South West region is the least represented, accounting for 10.39% of the total workforce of the Commission. Figure 3.5: Staff Distribution (%) by Geo-Political Zone * * * 3.4. Capacity Development The Commission places a high premium on the training and capacity development of its staff as it recognizes that the quality of personnel impacts significantly on its operation and success. Prior to the outbreak of the COVID-19 pandemic and its consequential effects on the country, the Commission sponsored some members of staff, based on their job/skill gaps and needs assessment of the Commission, to training on Utility Regulation and Strategy, Strategic Management of Regulatory and Enforcement Agencies, and the 2020 World Future Energy summit during the first quarter of 2020. Upon the outbreak of COVID-19 within the year, however, the Commission in its commitment to staff safety, while ensuring business continuity during the pandemic and adhering to its long-standing capacity-building principle, leveraged Information Communication Technology ("ICT") in conducting and attending meetings, training, workshops and engaging industry operators. The use of ICT has enabled the Commission to work faster and more effectively and is a key component of the "Project work Smart, Agile, Focused and Efficient ("S.A.F.E") embarked on by the Commission during the third quarter of 2020. This project not only helped the Commission to comply with the directives and guidance on physical gathering issued by the Nigeria Centre for Disease Control ("NCDC") and the Presidential Task Force on COVID-19 pandemic in Nigeria, it also helped to optimise the Commission's productivity, enable collaboration and effective communication. Table 3.3 presents the details of the face-to-face and virtual training, workshops and meetings attended by staff of the Commission in the year 2020. In addition to the aforementioned, the Commission organised a number of in-house virtual training and workshops for staff development. Members of staff of the Commission were also sponsored to attend virtual conferences of their respective professional bodies among which include; 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 Nigeria Bar Association ("NBA"). Table 3.3: Training, Workshop and Conferences Attended in 2020 | S/N | | Category | Mode | | --- | --- | --- | --- | | | A. | Training | | | 1 | 1 | Strategic Management of Regulatory and Enforcement Agencies | In-person | | 2 | 2 | Utility Regulation and Strategy | In-person | | 3 | 3 | Effective Use of NEPLAN Power System Modelling Software Package | Virtual | | 4 | 4 | Cyber Security Awareness for Safety and Security of Working Online | Virtual | | 5 | 5 | DocStream System to Digitalise the Operations of the Commission | Virtual | | | B. | Summit | | | 6 | 1 | World Future Energy Summit | In-person | 3.5. Promotion, Awards and Retirement The Commission conducted the 2020 promotion exercise for eligible staff between 23rd November and 8th December 2020. This is consistent with the Commission's policy to conduct transparent and regular promotion exercises for eligible staff. At the end of the exercise, members of staff who were adjudged to have satisfied the stipulated requirements were duly promoted. Due to the outbreak of COVID-19 pandemic and in compliance with the directives on social gathering issued by relevant authorities managing the consequential effects of the pandemic in Nigeria, no award ceremony was held in 2020. Section 55(3) of the EPSRA mandates the Commission to submit quarterly reports on the performance of the electricity industry and the Commission's activities to both the President and National Assembly. Specifically, the reports contain the 3.6. Reporting Obligations During the year under review, one (1) member of staff exited the Commission based on voluntary retirement. * * * analyses of the state of the Nigerian electricity industry (covering both the operational and commercial performance), regulatory functions, consumer affairs, the Commission's finances, and staff development during a given quarter. The Planning, Research and Strategy ("PRS") Division of the Commission is saddled with the responsibility of preparing the reports using the industry data and input from other Divisions. In compliance with the aforementioned section of the EPSRA, the Commission has submitted its four (4) quarterly reports for 2020 to the President and National Assembly. 3.6.2. Financial Reports The Commission's financial statement for the year ended 31st December 2020 was prepared in compliance with Section 55(1) of the EPSRA, which mandates the commission to keep proper accounts and other records relating to its financial statement in respect of all the Commission's activities, funds and property, including such particular accounts and records as the Minister may require. And in compliance with Section 56(1)-(3) of the EPSRA, which mandates an auditor within six (6) months after the end of each financial year to audit the account of the Commission, Deloitte & Touche Ltd was appointed to audit the account of the Commission for the 2020 financial year. The abridged audited financial statements of the Commission for the year ended 31st December 2020 prepared by the firm are presented in Part 7 of this report. * * * PART 4: STATE OF THE NIGERIAN ELECTRICITY SUPPLY INDUSTRY * * * 4.1 Operational Performance 4.2 Grid Performance 4.3 Commercial Performance * * * 4.1. Operational Performance 4.1.1. Electricity Generation In line with the mandate derived from the EPSRA, the Commission continues to monitor the technical, operational and commercial performance of the industry. During the year under review, the average daily available generation capacity stood at 6,107MW. Figure 4.1 shows the summary statistics of the average daily available capacity (MW) for January to December in 2019 and 2020. On a year-on-year basis, the average available capacity fell slightly by 2.75%, declining from 6,227MW in 2019 to 6,107MW in 2020. The decrease in daily available capacity despite the increase in the number of available generation units from 63 in 2019 to 71 in 2020 indicates that the generation units that were undergoing maintenance and overhaul in 2020 (which made them unavailable for operation), are of bigger capacity than those available during the period. Despite the decrease (2.75%) in the available generation capacity in 2020, the total electric energy generated increased by 5.24% from 33,489,1 Figure 4.1: Average Daily Available Capacity in 2019 and 2020 * * * The industry's peak daily generation is recorded on the 30th day of October the average daily electricity generation despite the decrease in daily availa generation in 2020 rose significa 3,826MWh/h recorded in 2019. The attributed to an improvement in capac F 5,520MWh/h for the year 2020 was Figure 4.2 presents a summary statistic on in 2019 and 2020. It was noted that, le capacity, the average daily electricity tly by 5.97% to 4,054MWh/h from its positive impact on daily generation is utilisation. Figure 4.2: Average Daily Generation (MWh/h) in 2019 and 2020 Figure 4.3 represents the available capacity Figure shows that 66.69% of the available indicating 5.39 percentage points increase 2019. By implication, fewer available cap 2020 as compared to 38.70% that were capacity utilisation was due to a reduction relating to; gas supply shortage, water ma transmission constraints, limited distribution low load off-take by DisCos. y utilisation in 2019 and 2020. Theable capacity was utilised in 2020, from the capacity utilisation rate in capacities (~ 33.31%) were redundant in redundant in 2019. The improved technical and operational constraints management at the hydropower stations, networks, and commercially induced * * * Figure 4.3: Average Capacity Utilisation Rate in 2019 and 2020 Notwithstanding the improvements achieved, the complete resolution of both the technical and operational challenges in NESI remains one of the top priorities of the Commission. The CBN-Payment Assurance Facility ("PAF") was set up to cover tariff shortfalls thereby helping the Nigerian Bulk Electricity Trading ("NBET") Plc to meet its obligations to the GenCos who then make payments to gas suppliers. The Commission identified the risk associated with the expiration of this facility with respect to payment to gas suppliers. To this end, the Commission commenced work on a payment securitization framework, the CBN-NEMSF Escrow Arrangement, that will provide payment assurance to GenCos and gas suppliers pending full activation of contract obligations. The Commission also continued consultations with relevant stakeholders to develop lasting solutions to the gas supply challenges affecting the power industry. * * * its decisions on the Performance Improvement ensure the execution of projects critical to imp performances. The PIPs include DisCos propos ans ("PIPs") filed by the DisCos $ ^{2} $ to moving their operational & technical ls on: 1. Utilisation of capital and operating expenditure allowances for relevance and cost-efficiency; II. Investments required to address distribution net part of the yet unutilised generation capacities constraints inhibiting the flow of energy. ork bottlenecks and free up and address other related In response to feedback received during the public hearings on the consideration of applications filed for extraordinary tariff review by the DisCos, in September 2022, the Commission commenced Service-Based Tariffs ("SBT") to improve the utilisation of existing capacity and liquidity of the industry. $ ^{3} $ Additionally, the Commission, approved the June and December 2020 minor reviews of the Multi-Year Tariff Order ("MYTO") 2020 to determine the relevant SBT and market-related shortfalls and prescribe the minimum remittance thresholds for the year 2020 for each DisCo in line with the allowed end-user tariffs payable by customers. 4.1.2. Load Factor and Average Generation of Power Plants Load factor (i.e., the dispatch rate) is defined as the amount of energy that a power plant generated over a certain period relative to its available capacity for the same period. The load factor plays an important role in the cost of generation per unit kWh. The higher the load factor of a plant, the better the capacity utilization and profitability as the fixed costs of generation plants are spread across more dispatched energy. The formula for Plant Load Factor is represented by Eq. 4.1: L o a d,F a c t o r,(%)=\\frac{T o t a l,E n e r g y,C e n e r a t e d,(M W h)}{A v e r a,A v a i l a b l e,,a p p a c i t y(M W) _24_ p e r i o d(i n,d a y s)}\\times100,,(4.1) (4.1) $ ^{2} $ 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. $ ^{3} $ SBT is a location-based tariff that ties rate payable by end-users to actual quality of service. * * * The average load factor across all plants stood at 61.74% in 2020, indicating that an average power plant operating in the year 2020 had 61.74% of its available capacity dispatched by the System Operator ("SO"). This represents a slight increase of 1.06 percentage points from the 60.68% recorded in 2019. As represented in Figure 4.4, Kanji, Jebba and Shiroro hydro plants, respectively had 83.60% ,78.73% and 67.59% of their available capacities dispatched by the SO and were respectively first, third and eight plants with the highest dispatch rates. Thus, the dispatch rates of the three (3) hydro plants complied with the Commission's Order NERC/182/2019, declaring hydropower plants as "mustrun" by SO. The Order was to ensure that hydro plants are efficiently dispatched, given their low tariffs and in consideration of safety associated with spilling of water from dams during the rainy season. In 2020, Azura power plant had a load factor of 79.74% while Sapele NIPP had the least dispatch rate of 33.71%. Figure 4.4: Average Plant Availability Factor (%) in 2020 * * * The contribution of the individual power plant to the total energy output in the year 2020 is represented in Figure 4.5. Nine $ (9)^{4} $ of the twenty-six (26) operational power plants accounted for 71.80% of the total electric energy generated in 2020. Due to its size and availability, Egbin power plant accounted for the highest share （13.54%）of the total energy output followed by Kainji hydropower plant which accounted for 8.31% energy share. Azura Edo, Jebba, Shiroro and Delta were also among the top-six contributors to generation output during 2020. During the same period, Gbarain power plant accounted for the least share of output contributing 0.24%. Compared to 2019,the reliance on the aforementioned 9 power plants increased by 4.54 percentage points as they only accounted for 67.26% of total generation in 2019. (9)^{4} Figure 4.5: Average Share (%) of Generation Output by Plants in 2020 4 The plants are Egbin, Kainji, Azura-Edo IPP, Jebba, Delta, Shiroro, Odukpani, Afam VI and Geregu with a minimum share of 5.76% each. * * * The implication from Figure 4.5 is that the (over)reliance of the grid on the energy supplied by nine (9) power plants may pose a risk to the industry because downtime in any of them may result in grid instability if there is no adequate reserved capacity from other plants to timely offset adverse impact of any sudden loss of generation from any of the nine (9) plants. The Commission has commenced the process of gradually activating the industry contracts to provide certainty to the minimum volume of energy expected of each generating plant and properly allocate risks among the industry operators. This is expected to lead to incremental growth in power availability and utilisation. 4.1.3. Generation Mix The electricity generation mix refers to the combination of electricity over a period of time. The generation mix varies country to another depending on the availability of new policies, environmental factor, type of generating plant energy required, as well as seasonal variations. An important for energy cost reduction, continuous energy sustainability of the country's energy supply. n of fuels used to generateuries considerably from one natural resources, government nts installed, the quantity of appropriate energy mix is energy generation and the The share of electricity generation by fuel source for the years 2020 and 2019 is represented in Figure 4.6. The share of electric energy generated from gas-fired plants increased in 2020 as compared to 2019 and still dominated the electricity generation mix accounting for 76.69% of the electricity generated in 2020. Compared to 2019 (25.17%)，there was a 1.86 percentage point decline in the share of electric energy generated from hydro which accounted for 23.31% of the total energy output.The country's current energy mix means that seasonal variation 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 Government's climate change mitigation commitments. * * * State of the Industry Figure 4.6: Share of Output (%) Generated by Fuel Sources To ensure improvement in the generation mix, the C with stakeholders in the NESI to develop regulator policies necessary for the actualisation of an improve these interventions is the Commission's constant Electrification Agency ("REA") which has continued sources to underserved communities. commission will continue to work by interventions and implement red energy mix. Notable among engagement with the Rural to provide renewable energy 4.1.4. Grid Performance To assess the grid performance of the grid, the Commission focuses on four (4) key performance indicators ("KPIs") that relate to power transmission. These are - - Stability of grid frequency Transmission Loss Factor ("TLF") refers to the proportion of the total energy sent out by the power plants that was lost in transmission and unaccounted for as delivered to the DisCos or exported by the Transmission System Provider ("TSP"). As a measure of the efficiency of the transmission system, a decline in the TLF indicates an improvement in transmission efficiency. The formula for TLF is represented by Equation 4.2 below: - Incidence of system collapse - Transmission Loss Factor * * * T L F(\\theta\_{0})=\\frac{\\mathrm{E n e r g y\ S e n t,o u,b y,G e n C o s-(E n e r g y,D e l i v e r e d,t o,D i s C o s,a n d,E x p o r t e d)}}{\\mathrm{E n e r g y,S e n t,u t t,,o t\ a l C}C o s}\\times100\ (4.2). (4.2) The average TLF decreased significantly in 2020. As represented in Figure 4.7, the transmission loss factor declined by 0.38 percentage points from the average of 7.72% recorded in 2019 to 7.34% in 2020.More importantly,the average TLF of 7.34% in 2020 is significantly lower than the 8.05% industry Multi-Year Tariff Order ("MYTO") reference loss factor indicating relatively improved performance in TCN's operation. Improvements (reductions) in the TLF lower the overall losses that are transferred to end-use customers thereby contributing towards a reduction in the cost-reflective tariff. To spur TCN to an even better performance that investments in the transmission network of the transmission system using the neces the Commission will continue to ensure s are targeted to improve the efficiencyary regulatory instrument. Figure 4.7: Transmission Loss Factor during 2019 and 2020 - Grid Frequency Frequency is a major power quality parameter that consumers (especially industrial customers) are concerned about. 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 but may reach an upper bound stress limit of 51.25Hz and a lower bound stress limit of 48.75Hz in extreme circumstances. A summary of the system frequency pattern in NESI from 2019 to 2020 is represented in figure 4.8. The figure indicates that the grid was moderately stable during 2020 similar to 2019. Except for the last quarter of the year for the low frequency, the actual system (low and the high) frequencies did not deviate significantly from their respective regulatory limits. However, both the low and the high system frequencies were still far from the industry nominal standard (50Hz) by averages of -0.34Hz and 0.73Hz respectively per month. Hence, there is an urgent need to ensure the grid frequency falls within the statutory limits to attain the envisaged quality of grid electricity and make it acceptable to all consumers. This calls for an improved balancing of load and generation which can be enhanced by an improvement in predictability of load patterns of the DisCos by the SO. Figure 4.8: Average Monthly System Frequency (in Hz) in 2019 and 2020 * * * Many industrial customers have stopped using the grid power supply for production purposes even when available, due to the potential impact of poor quality on their production cycle. This is reinforced by data from the DisCos which indicate that industrial customers account for 12% of DisCos' annual energy sales and constitute the highest tariff class as well as the class with the lowest commercial losses. To increase the patronage of grid electricity by industrial customers, the Commission will continue to push that the quality of grid supply to them improves by ensuring the grid frequency remains within the statutory bounds. In the short/medium term, while the infrastructure investments required to improve the reliability and redundancy of the grid are being done, the Commission will explore options for improved contractual discipline and associated monitoring/evaluation around the quality of energy generated, transported, and delivered along the National grid. - Voltage Fluctuation The system voltage pattern for the years 2019 and 2020 is represented in Figure 4.9. Although system voltage has continuously improved from 2019 as the voltage converged towards the lower regulatory limit, both the low and high system voltages were outside the prescribed regulatory boundaries during 2019 and 2020. To minimise the frequency and voltage fluctuations, the Commission continues to work with TCN and other relevant stakeholders to ensure that system voltage and frequencies operate within the prescribed regulatory limits in order to ensure a safe and reliable electricity supply in the NESI. Strategies being pursued include the use of battery banks, voltage compensators, and embedded generation at the distribution network. Figure 4.9: System Voltage (in kV) in 2019 and 2020 - System Collapse Maintaining a stable grid frequency of 50Hz requires a sus the amount of electricity fed into the electricity grid and the taken by end-users since it is not economically optimal to quantities over a long period. The SO ensures that this free times within a tolerance threshold of plus or minus 0.05Hz tained balance between amount of electricity off store electricity in largeency is sustained at all * * * When supply exceeds demand, the electrical frequency increases and in extreme cases some power plants that are unable to tolerate excessive frequency variation may shut down thereby causing a sudden drop in the available generation on the grid. This exacerbates the frequency imbalance potentially leading to a full/partial system collapse. When demand exceeds supply, the frequency drops and unless the SO immediately brings in additional supply or sheds off some load, there is the risk of cascading (switching off the power plants at very low system frequency) leading to a complete collapse of the grid. The stability of the grid network showed total system collapses declined from the p the industry recorded four (4) total system to 2019 where ten (10) total system colloca was no incident of partial system collapse collapse in 2019. improvement in 2020 as the number of previous years. As presented in Table 3.1, collapses in the year 2020 as comparedases were experienced.Moreover, there in 2020 compared to one (1) partial Table 4.1: Total and Partial System Collapses in 2020 | Category | | | | --- | --- | --- | | 2017 | 2018 | | | Number of Partial Collapses | 9 | | | Number of Total Collapses | 15 | | | Annually: | | | 2020 Quarterly: | | | | | --- | --- | --- | --- | --- | --- | --- | | 2018 | 2019 | 2020 | /Q4 | /Q3 | /Q2 | /Q1 | | 1 | 1 | 0 | 0 | 0 | 0 | 0 | | 12 | 10 | 4 | 1 | 0 | 2 | 1 | The improvement in the grid stability is attributable to the tighter enforcement and adherence to the provisions of the Grid Code which mandates free governor control at grid-connected power plants. To sustain the improvement in grid stability in subsequent years, the Commission will continue to intensify monitoring of strict compliance with the SO's directives to generators on free governor and frequency control mode in line with the provisions of the subsisting operating codes in the industry. The Commission is also exploring options for the enforcement of under frequency load shedding scheme that has been put in place to provide an added layer of security for the grid in the case of a sudden loss of generation. * * * 4.2. Commercial Performance 4.2.1. Energy Received and MYTO Load Allocation The amount of energy received by DisCos at the approximately 12.59% from the 26,485GWh rec in 2020. This increase is partly attributable to energy generated in 2020 as compared to 2019 heir trading points increased by recorded in 2019 to 29,819GWh the 5.24% increase in the total For the individual DisCos, the comparison of the Multi-Year Tariff Order ("MYTO") load allocation with the share of energy received by DisCos in 2020 is represented in Figure 4.10. Two (2) categories of DisCos emerged from this comparative analysis. The first group comprising six (6) DisCos (Benin, Enugu, Ikeja, Jos, Kaduna and Kano) had lesser energy off-take than their MYTO allocation in 2020 due to technical limitations of their networks and/or commercially induced low load offtake. It is noteworthy that the six DisCos had consistently had lower energy off-take than their MYTO allocation in the last two (2) years. On the other hand, the second group comprising Abuja, Eko, Ibadan, Port Harcourt and Yola DisCos received more energy than their MYTO allocation in 2020. To ensure improvement in energy off-take by DisCos, the Commission included in the MYTO Order, effective 1st January 2020, a provision for "take or pay" obligation on the capacity equivalent of MYTO load allocation for each DisCo in accordance with the terms of the vesting contract executed with NBET. The main implication of this obligation is that, unlike in the past when a DisCo was charged energy and capacity for all the energy it offtakes, now, the capacity cost for each DisCo is tied to its MYTO allocation while its energy cost will be tied to actual offtake. This means that a DisCo that fails to take its allocation will pay for unutilised capacity which increases its average wholesale energy cost while conversely, any DisCo that takes above its allocation will enjoy a reduction in its average wholesale energy cost. The net benefits/losses accruable from this variation will be enjoyed/ borne solely by the DisCos and cannot be transferred to customers through tariffs. * * * State of the Industry Figure 4.10: Energy Off-take by DisCos vs.MYTO Load Allocation in 2020 In addition, the Commission Agreement ("SLA") between of the merit order dispatch such that DisCos takes resp this monitoring the implementation of the Service Level DisCos & TCN. SLAs allocate risk arising from deviation and low load offtake/dispatch to the appropriate party, insibility for its low load offtake and vice versa. 4.2.2. Energy Billed and Billing Efficiency Billing Efficiency is an indicator of the proportion of (including metered and unmetered sales) to customer energy supplied to an area within a given period. nergy that has been billed in comparison to the total (4.3) The formula for Billing Efficiency is represented by Equation 4.3 below: B i l l i n g;E f f i c i e n c y;(96);=;\\frac{T o t a l;u n i t s;b i l l e d;(k W h)}{T o t a l;e n e r g y;r e c e i v e d;b y;t h;N e t w o r k;(k W h)}\\times100 The amount of energy received, billed a and 2020 are represented in Table 4.2 billing efficiency in 2020. Out of the 29 d billing efficiency by DisCos in 2019 The table shows a decline in DisCos' 819GWh total energy received by all * * * DisCos in 2020, 22,163GWh 8.44 percentage points decrease a high technical and commercial (74.33%) was billed to the end-users, implying from the billing efficiency in 2019 (82.77%) and losses of 25.67% relative to 2019 (17.23%). One of the reasons why DisCos are unable to record a 100% billing efficiency is their inability to identify who consumes all their energy; owing largely to poor customer enumeration. Other contributory factors to billing inefficiency are - low metering, the presence of inaccurate meters and energy theft (commercial loss). Energy loss to wires and transformers (technical losses) also contribute to DisCos' inability to achieve 100% billing efficiency. Hence, billing efficiency combines technical and commercial efficiencies. The level of DisCos' billing efficiency shown received by DisCos from the TSP in 2020, technical inefficiencies and energy theft. In electricity received by DisCos in 2020, app energy theft and poor distribution infrastructure that, for every 10kWh of energy approximately 2.56kWh was lost to other words, for every N10 worth of approximately N2.56k was lost due to e. Concerned by the decline in DisCos billing performance, the Commission continues to engage the DisCos to address the factors responsible for the observed downward trend in their billing efficiencies in 2020. Furthermore, the Commission is working with DisCos to ensure that distribution losses are significantly reduced as part of efforts toward steering the industry to financial sustainability. The performance of the DisCos in Table 4.2 indicates that Ikeja and Eko DisCo had the highest billing efficiency of 90.95% and 87.96% respectively. Yola DisCo recorded the lowest billing efficiency of 45.67%, indicating that Yola DisCo lost more (i.e., 54.33%) energy to technical inefficiency and energy theft in 2020 than the total energy billed to customers during the same year. Yola DisCo has consistently recorded the lowest billing efficiency since 2017.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 can be said to have contributed to the low operational performance of the utility. * * * Table 4.2: Annual Energy Received and Billed by DisCos for 2020 and 2019 | DisCos | Total Energy Received(GWh) | | | --- | --- | --- | | 2020 | 2019\* | | | Abuja | 3,876 | 3,794 | | Benin | 2,579 | 2,332 | | Eko | 3,558 | 3,358 | | Enugu | 2,426 | 1,179 | | Ibadan | 4,035 | 3,562 | | Ikeja | 4,581 | 4,248 | | Jos | 1,378 | 1,241 | | Kaduna | 2,295 | 1,963 | | Kano | 1,875 | 1,776 | | Port Harcourt | 2,027 | 1,981 | | Yola | 1,189 | 1,050 | | All DisCos | 29,819 | 26,485 | | DisCo Average | 2,711 | 2,408 | | Total Energy Billed(GWh) | | Billing Efficiency(%) | | | --- | --- | --- | --- | | 2020 | 2019\* | 2020 | 2019 | | 2,364 | 2,956 | 60.99 | 77.91 | | 2,165 | 2,025 | 83.96 | 86.84 | | 3,129 | 2,973 | 87.96 | 88.53 | | 1,748 | 1,121 | 72.05 | 95.08 | | 2,857 | 2,958 | 70.82 | 83.04 | | 4,167 | 3,744 | 90.95 | 88.14 | | 779 | 890 | 56.51 | 71.72 | | 1,413 | 1,597 | 61.57 | 81.36 | | 1,434 | 1,459 | 76.46 | 82.15 | | 1,564 | 1,483 | 77.16 | 74.86 | | 543 | 715 | 45.67 | 68.10 | | 22,163 | 21,921 | 74.33 | 82.77 | | 2,015 | 1,993 | 71.28 | 81.61 | Note: DisCos are the electricity distribution companies; \* Indicates the values in the cell for Enugu and Yola are different from those reported in the 2019 report due to adjustment for errors detected Based on relative improvement from the year 2019, only Ikeja and Port Harcourt DisCos recorded improvement of 2.83 and 2.30 percentage points respectively in their billing efficiencies. The decrease in billing efficiency ranges from -0.59 percentage points (Eko DisCo) to -23.03 percentage points (Enugu DisCo). In its effort to address DisCos' technical and commercial inefficiency, the Commission has finalised the review of the 2021-2025 Performance Improvement Plans ("PIP") filed by DisCos. The PIPs are developed on the directive of the Commission to ensure that the proposed investments are targeted toward critical infrastructure to free up stranded capacity and improve service delivery. Also, a revenue adjustment mechanism that claws back any return allowed on previously proposed investments that were not eventually executed by the DisCos has been adopted in tariff reviews. * * * conclusion of the procurement of MAPs as well as the implementation of the National Mass Metering Programme ("NMMP"). 4.2.3. Revenue and Collection Efficiency Collection efficiency is an indicator of from customers compared to the amou reasons, many customers continue to resulting in collection losses. the proportion of the amount that is collected billed to them by the DisCos. For various default in payment of their billed amounts The formula for Collection Efficiency is represented by Equation 4.4 below; C o l l e c t i o n,E f f i c i e n c y,(\\not\\forall\_{0})=\\frac{R e v e m u e,C o l l e c t e d(\\not)\ }{B i l l e d,A m o u n t,(\\not\\Psi)},\\times100 (4.4) The total revenue collection by the eleven (11) DisCos from customers in 2020 stood at N542.73 billion out of the total bill of N816.16 billion. Relative to the year 2019, the DisCos' collection efficiency declined during 2020. As shown in Table 4.3, the overall collection efficiency for all DisCos decreased to 66.50% representing 1.34 percentage points decrease from the 67.84% collection efficiency recorded in 2019. For 2020, this implies that for every N10.00 worth of energy billed to customers by DisCos, approximately N3.35 remained unrecovered from customers. The low collection efficiency combined with billing inefficiency has continued to adversely impact the financial liquidity of the industry, which in turn, has led to low investment in the NESI. In appraising individual DisCo performances, Abuja and Ikeja DisCos had the highest collection efficiency of 88.86% and 78.92% respectively. Kaduna DisCo had the lowest collection efficiency of 37.69%. It is noteworthy that, three (3) of the DisCos namely Ibadan $ (6^{th}) $ , Jos $ (8^{th}) $ and Kaduna $ (11^{th}) $ maintained their 2019 rankings in collection efficiency in 2020. On a year-on-year basis, only Abuja, Jos and Yola recorded an improvement in collection efficiency with Abuja DisCos having the highest increase of 13.23 percentage points moving from 75.64% in 2019 to 88.86% in 2020. (8^{\\dagger h}) * * * Table 4.3: Annual Revenue Performance of DisCos for 2020 and 2019 \| DisCos \| Total Billings (Million) \| \| \| \-\-\- \| \-\-\- \| \-\-\- \| \| 2020 \| 2019\* \| \| \| Abuja \| 92,965 \| 99,381 \| \| Benin \| 85,971 \| 72,296 \| \| Eko \| 107,671 \| 89,930 \| \| Enugu \| 74,638 \| 5,448 \| \| Ibadan \| 101,159 \| 91,195 \| \| Ikeja \| 133,330 \| 104,724 \| \| Jos \| 30,605 \| 31,791 \| \| Kaduna \| 57,136 \| 50,475 \| \| Kano \| 52,573 \| 45,981 \| \| Port Harcourt \| 61,793 \| 53,413 \| \| Yola \| 18,317 \| 16,864 \| \| All DisCos \| 816,158 \| 661,497 \| \| DisCo Average \| 74,196 \| 60,136 \| | Revenue Collected(#’Million) | | Collection Efficiency(%) | | | --- | --- | --- | --- | | 2020 | 2019\* | 2020 | 2019\* | | 82,610 | 75,168 | 88.86 | 75.64 | | 45,656 | 41,199 | 53.11 | 56.99 | | 84,655 | 74,942 | 78.62 | 83.33 | | 47,829 | 3,957 | 64.08 | 72.63 | | 61,802 | 57,389 | 61.09 | 62.93 | | 105,230 | 90,412 | 78.92 | 86.33 | | 17,442 | 17,552 | 56.99 | 55.21 | | 21,534 | 20,594 | 37.69 | 40.80 | | 33,842 | 31,501 | 64.37 | 68.51 | | 31,394 | 27,386 | 50.81 | 51.27 | | 10,735 | 8,649 | 58.61 | 51.29 | | 542,729 | 448,749 | 66.50 | 67.84 | | 49,339 | 40,795 | 63.01 | 64.08 | Note: DisCos are the electricity distribution companies; \* Indicates the values in the cell for Enugu and Yola are different from those reported in the 2019 report due to adjustment for errors detected. A major factor contributing to low collection efficiency is customers' displeasure with estimated billing thereby causing their unwillingness to pay. On this account, the Commission amended the Order on capping of estimated bills during the fourth quarter of 2020. The amended Order aligns the total volume of energy an unmetered customer can be billed to the average monthly energy use of a typical pre-paid meter customer on the same feeders, as against the Business Unit as provided for in the previous Order. The Commission in the third quarter of 2020 also commenced implementation of the service-based tariffs to improve the utilisation of existing capacity and ensure that end-user tariffs are aligned with the quality of services. The Commission also continued the monitoring of the implementation of the MAP scheme in accordance with the MAP Regulations, and the CBN financing of NMMP to ensure the speedy roll-out of meters in NESI. 4.2.4. Aggregate Technical, Commercial and Collection (ATC&C) Losses The Aggregate Technical, Comparison between the amount the amount of electricity for w collections loss. ATC&C losses a mercial and Collection ("ATC&C") Losses are the of electricity received by a DisCo from TCN and which it invoices its customers plus the adjusted broken into the following 3 components: * * * a. Technical Loss: heat losses due to load flow in electrical lines and transformation loss in transformers. b. Commercial loss: due to discrepancy in meter unmetered consumption, or energy theft; eading, erroneous billing, c. Collection losses: unpaid bills. The formula for ATC&C losses is represented by Equation 4.5 below: ATC&C Losses = \[1 - (Billing Efficiency $ \\times $ Collection Efficiency)\] $ \\times $ 100 (4.5) As indicated in Table 4.4, the overall average ATC&C loss for all the DisCos in 2020 increased to 50.57%. Table 4.4: ATC&C Losses for DisCos from 2016 to 2020 \| DisCos \| MYTO Target(%) \| \| \-\-\- \| \-\-\- \| \| 2020 \| \| \| Abuja \| 22.33 \| \| Benin \| 23.91 \| \| Eko \| 11.23 \| \| Enugu \| 20.56 \| \| Ibadan \| 19.67 \| \| Ikeja \| 10.81 \| \| Jos \| 39.12 \| \| Kaduna \| 20.12 \| \| Kano \| 22.06 \| \| Port Harcourt \| 29.70 \| \| Yola \| 23.71 \| \| Overall DisCos: MYTO Level \| 22.11 \| \| Aggregate technical, commercial & collection Losses \| - \| \| Technical & Commercial Losses \| - \| \| Collection Losses \| - \| | Average ATC&C Losses(%) | | | | | | --- | --- | --- | --- | --- | | 2020 | 2019\* | 2018 | 2017 | 2016 | | 45.80 | 41.07 | 40.15 | 47.58 | 48.64 | | 55.41 | 50.52 | 53.24 | 55.80 | 55.30 | | 30.85 | 26.22 | 30.56 | 17.95 | 34.26 | | 53.83 | 30.94 | 51.68 | 67.13 | 61.67 | | 56.74 | 47.74 | 49.96 | 54.08 | 50.05 | | 28.21 | 23.91 | 21.82 | 29.07 | 44.38 | | 67.79 | 60.40 | 69.61 | 76.00 | 72.46 | | 76.80 | 66.81 | 69.82 | 74.27 | 72.84 | | 50.78 | 43.72 | 51.47 | 62.32 | 60.61 | | 60.80 | 61.62 | 63.66 | 66.14 | 59.90 | | 73.24 | 65.08 | 68.42 | 66.46 | 63.37 | | | | | | | | 50.57 | 43.85 | 47.85 | 53.90 | 54.16 | | 25.67 | 17.23 | 19.81 | 23.42 | 18.69 | | 33.50 | 32.16 | 34.97 | 39.80 | 43.62 | The significant rise in ATC&C losses is accounted for by the combined increase in both the technical & commercial and the collection losses which respectively increased by 8.44 and 1.34 percentage points in the year 2020. Similar to the previous years, collection losses (including unpaid bills from sensitive customers, disputed bills, unsettled MDA debts etc.) continue to form a greater part of the ATC&C losses in 2020. This reinforces the need for DisCos to intensify efforts in Notes of the table: DisCos are the electricity distribution companies; ATC&C loss MYTO targets are adjusted for a two-year non-performance mutually agreed by BPE and DisCos' Core Investors.; \* Indicates the values in the cell for Enugu and Yola are different from those reported in 2019 report due to adjustment for errors detected revenue collection to improve their cash flow, thereby allowing them to meet their market obligations. The overall ATC&C losses of 50.57% in 2020 are substantially higher than the expected allowable ATC&C losses (22.11%) provided in the MYTO Order applicable in 2020. The implication of the higher ATCT& losses in 2020 is that, on average, as much as N4.94 in every N10.00 worth of energy delivered to DisCos was unrecovered due to a combination of inefficient distribution networks, energy theft, low revenue collection aggravated by the low level of metering of the end-use customer and unwillingness to pay by customers. In appraising the individual performances of the DisCos as presented in Table 4.4, Ikeja DisCo, despite its underperformance relative to 2019 and deviation from its MYTO target of 10.82% for 2020, was the most technically and commercially efficient DisCo by recording the lowest level of ATC&C losses of 28.21% in 2020. It is noteworthy that Ikeja has since 2018 remained the most technically and commercially efficient DisCo. The least performing DisCos in 2020 was Kaduna with ATC&C losses of 76.80% as against its MYTO target of 20.12%. 4.2.5. Market Remittance Compared to 2019, only Port Harcourt DisCo reduced its ATC&C losses by 0.82 percentage points in 2020, all other DisCos recorded relative increase in their ATC&C losses. The increase in ATC&C losses in 2020 ranges from 4.31% (Ikeja DisCo) to 22.89% (Enugu DisCo). Furthermore, none of the eleven (11) DisCos has attained the level of ATC&C losses trajectory embedded in their performance agreement executed between their core investors and the Bureau of Public Enterprise ("BPE"). The inability of most DisCos to meet their allowed loss targets means they are unable to meet revenue requirements thereby compromising their long-term financial position. The NESI continued to face challenges with market liquidity. This is evidenced in the DisCos'，international and special customers' total remittances to NBET and * * * Market Operator ("MO") relative to the invoices received for energy bought from NBET and for administrative services rendered by MO in 2020. (^{\\prime}\\mathrm{M O}{'}) Figure 4.11: Market Invoice and Remittance by DisCos in 2020 Of the combined invoices of N882.73 billion for energy and administrative services issued by NBET and MO, only a total of N370.34 billion was settled as and when due, creating a total deficit of N512.39 billion (including tariff shortfall). A comparative analysis of market invoice and remittance performance by DisCos in 2020 represented in Figure 4.11 indicates an average settlement rate per DisCo of 41.95% of the invoice. This represents significant progress (+6.08 percentage points) when compared to the average settlement rate of 35.87% recorded in 2019. Ikeja and Yola DisCos had the highest and lowest settlement rates of 54.03% and 16.83% respectively in 2020. The statistics of the DisCos' separate remittances to NBET and MO are summarised in Table 4.5. There was an improvement in the remittances to both NBET and MO in 2020. The remittances of the DisCos points from 28.58% in 2019 to 31.39% MO increased by 14.43 percentage po 2020. to NBET increased by 2.81 percentage in 2020 while the payment by DisCos to ents from 78.30% in 2019 to 92.73% in In 2020, the international customers (i.e., Societe Nigerienne d'electricite NIGELEC, Societe Beninoise d'Energie Electrique -SBEE and Compagnie Energie Electrique du Togo) received a total invoice of N16.31 billion (US$53.22 million) from MO and made a total payment of N10.45 billion (USD34.09 million) for the current and unpaid invoices for the services received from MO.In contrast, no payment was made by the special customers (Ajaokuta Steel Co.Ltd and the host community) in respect of the N0.93 billion and N0.15 billion energy invoices and service charges received from NBET and MO respectively in 2020. Table 4.5: Annual Remittance Performance to NBET and MO by DisCos | | NBET(#’Billion) | | RemitPerformance | | --- | --- | --- | --- | | | Invoice | Remit. | | | DisCos | 2020 | 2020 | 2020 | | Abuja | 89.91 | 34.23 | 38.07 | | Benin | 64.93 | 19.70 | 30.35 | | Eko | 84.12 | 35.60 | 42.32 | | Enugu | 62.88 | 19.74 | 31.40 | | Ibadan | 97.72 | 30.31 | 31.02 | | Ikeja | 107.19 | 47.99 | 44.77 | | Jos | 37.44 | 4.66 | 12.44 | | Kaduna | 58.34 | 12.42 | 21.29 | | Kano | 52.43 | 13.02 | 24.83 | | Port Harcourt | 48.39 | 8.93 | 18.46 | | Yola | 27.37 | 2.76 | 10.10 | | All DisCos | 730.71 | 229.36 | 31.39 | | Special Customer and | | | | | Ajaokuta Steel | 0.93 | 0.00 | 0.00 | | SBEE/PARAS | 0.00 | 0.00 | 0.00 | | CEET | 0.00 | 0.00 | 0.00 | | NIGELEC | 0.00 | 0.00 | 0.00 | | SBEE/Transcorp | 0.00 | 0.00 | 0.00 | | Notes of the table: | | | | | Balanceance (%) | MO (%' Billion) | | Remittance Performance (%) | | | --- | --- | --- | --- | --- | | Invoice | Remit. | 2020 | 2019 | | | 2019 | 2020 | 2020 | 2020 | 2019 | | 39.81 | 19.66 | 16.68 | 84.87 | 73.34 | | 25.98 | 13.51 | 13.64 | 100.94 | 75.96 | | 40.93 | 18.02 | 17.99 | 99.79 | 89.82 | | 23.52 | 13.08 | 13.07 | 99.93 | 74.30 | | 27.33 | 20.81 | 20.27 | 97.37 | 78.66 | | 38.40 | 21.61 | 21.61 | 99.96 | 87.23 | | 7.19 | 7.40 | 7.04 | 95.15 | 70.65 | | 15.15 | 11.86 | 9.21 | 77.70 | 72.22 | | 24.72 | 10.10 | 9.19 | 91.07 | 69.26 | | 18.68 | 10.14 | 9.46 | 93.29 | 72.93 | | 11.28 | 5.84 | 2.82 | 48.39 | 84.90 | | 28.58 | 152.03 | 140.98 | 92.73 | 78.30 | | International Customers: | | | | | | 0.10 | 0.15 | 0.00 | 0.00 | 0.00 | | 0.00 | 4.69 | 3.70 | 78.94 | 0.00 | | 0.00 | 3.49 | 2.02 | 58.01 | 0.00 | | 97.20 | 7.67 | 4.69 | 61.22 | 61.23 | | 0.00 | 0.47 | 0.03 | 6.32 | 0.00 | Notes of the table: 1. NBET, MO, SBEE, CEET and NIGELEC are Nigeria Bulk Electricity Trader, Market Operator, Societe Beninoise d'Energie Electrique, Compagnie Energie Electrique du Togo & Societe Nigerienne d'electricite respectively; 2. Benin DisCo Remitted more than 100% of the invoice to MO in 2020 due to payment of the outstanding MO invoice. * * * The proportion of the market invoice settled by the individual DisCo (remittance performance) for 2019 and 2020 is represented in Figure 4.12 indicates that, except for Yola DisCo,the individual DisCo increased their remittance performances between 2019 and 2020.The increase ranged from 1.73 percentage points (Abuja) to 12.24 percentage points (Enugu). Ikeja DisCo with the highest remittance rate of 54.03% ,recorded an increase of 8.51 percentage points in remittance performance in 2020 as compared to 2019. Yola DisCo with the lowest remittance rate of 16.83% recorded a decrease of 5.31 percentage points in remittance performance in 2020 as compared to 2019 (22.14%). Figure 4.12: Market Remittance by DisCos in 2019 & 2020 The improvement in DisCos remittances is partly linked to the CBN intervention (OpEx loan) administered by NESI Stabilization Strategy Limited ("NESI-SSL") for DisCos to part-finance their payment obligations to NBET and MO, pending improvement in their operational performance during the transition to the Service-Based Tariff ("SBT"). It is envisaged that DisCos will ramp up their collections to meet up subsequent required remittance obligations to NBET and MO,and their OpEx requirement within the tenor of the facility. * * * As part of the conditions for the several interventions that the CBN has extended to the DisCos, an escrow agreement was set up. Under this arrangement, all the revenues of the DisCos are escrowed with DisCos only having access to these funds after relevant deductions have been made. This escrow mechanism provides visibility into the financial performance of the DisCos with respect to collections. In June 2020, the remit of the fund manager responsible for the escrow was expanded to include the implementation of the payment waterfall framework which was designed by the Commission to increase upstream market remittance to NBET to cover the cost of energy taken from Generation Companies ("GenCos") and MO for transmission and administrative services. Prompt payment of upstream market settlements is critical for securing the availability of generation and transmission capacities and ultimately addressing the liquidity crisis facing the NESI. The waterfall regime pushes DisCos to boost their collections because the majority of their allowed revenues rank low in the waterfall. In the absence of cost-reflective tariffs, the Government undertakes to cover the resultant gap (between the cost-reflective and allowed tariff) in the form of tariff shortfall funding. This funding is applied to the NBET invoices that are to be paid by DisCos. The amount to be covered by the DisCo is based on the allowed tariff determined by the Commission and set out as their Minimum Remittance Obligation ("MRO") in the periodic MYTO issued by the Commission. The applicable MRO (%) for each DisCo to NBET and MO during the year under review is contained in Table 4.6. 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 Table 4.6: Minimum Remittance Obligation to NBET and MO by DisCos | DisCos | Minimum Remittance Obligation (NBET) | | | --- | --- | --- | | Abuja | 38.56 | | | Benin | 29.36 | | | Eko | 40.05 | | | Enugu | 35.41 | | | Ibadan | 28.16 | | | Ikeja | 49.07 | | | Jos | 11.69 | | | Kaduna | 29.21 | | | Kano | 46.34 | | | Port Harcourt | 27.06 | | | Yola | 8.00 | | | All DisCos | 34.32 | | | Minimum Remittance Obligation(MO) | Minimum Remittance Obligation(NBET&MO) | | --- | --- | | 100.00 | 49.58 | | 100.00 | 41.53 | | 100.00 | 50.63 | | 100.00 | 46.53 | | 100.00 | 40.77 | | 100.00 | 57.62 | | 100.00 | 26.27 | | 100.00 | 41.17 | | 100.00 | 55.00 | | 100.00 | 39.69 | | 100.00 | 24.17 | | 100.00 | 45.63 | The comparison between the 2020 MRO and actual remittances by DisCos represented in Figure 4.13 shows that the overall actual remittance was approximately 3.68% less than the expected MRT of 45.63% (after adjusting for tariff shortfall). During the year, the gap between the actual remittance rate and the expected MRT of the DisCos ranged from-19.80% (Kano DisCo) to +1.90% (Ibadan DisCo). DisCos must continue to improve on effort toward reducing their ATC&C losses to levels commensurate with the contractual obligations in their performance agreement in order to improve sector liquidity and ensure business continuity. Figure 4.13: Expected and Actual Remittance by DisCos in 2020 * * * The Commission is committed to achieving full compliance with MROs for which failure to comply will result in licence cancellation. In this regard, to enforce market discipline and compliance with payment obligations, the Commission has ordered NBET to exercise its contractual rights on the payment security cover provided by DisCos in accordance with the terms of its vesting contract with the DisCos. Furthermore, in recognition of the importance of improving market remittances to sustain the operations of the sector, the Commission continues to support DisCos with initiatives on revenue growth. The introduction of the SBT and DisCos' ability to migrate customers upwards by increasing the quality of supply provides a clear pathway for DisCos to boost their revenues without absolute tariff increases. The ongoing infrastructure investments and metering interventions being undertaken by DisCos will increase the volume of reliable energy supplied to customers and revenue assurance which should translate into increased collections and market remittances. * * * PART 5: REGULATORY FUNCTIONS * * * 5.1 Regulations, Orders and Guidelines 5.2 Licensing and Permits 5.3 Certification of Meter Assets/Service Providers 5.4 Applications under Evaluation 5.5 Public Consultation and Workshop on Regulations/Orders and Guidelines 5.6 Compliance Monitoring and Enforcement 5.7 Litigation and Alternative Dispute Resolution * * * 5.1. Regulations, Orders and Guidelines 5.1.1. Regulations In the year 2020, no new regulations were issued. However, the Commission intensified the monitoring of compliance based on the provision in existing Regulations, Standards and other industry rules governing the Nigerian Electricity Supply Industry ("NESI"). Having recognised that some of the provisions of its existing regulations are outdated (and in some cases conflicting), the Commission commenced the process for the review of the under-listed Regulations- 1. The Nigerian Electricity Regulatory Commission ("NERC") Customer Complaint Handling: Standard and Procedures, 2006. 2. The Nigerian Electricity Regulatory Commission's Meter Reading, Billing, Cash Collections and Credit Management for Electricity Supplies Regulations, 2007. 3. The Nigerian Electricity Regulatory Commission's Customer Service Standards of Performance for Distribution Companies, 2007. 4. The Nigerian Electricity Regulation Commission ("NERC") Meter Asset Provider Regulations, 2018. 5.1.2. Orders 1. NERC/196/2020 - issued on 28th January 2020 on the Transitional Accounting Treatment of Tariff Related Liabilities in the Financial Records of Participants in the NESI. The objectives of this Order, among others, are to; a) provide a guideline for the transitional accounting treatment of tariff-related liabilities in the financial records of DisCos; b) ensure that no new tariff-related liabilities accrue in the financial records of DisCos and; c) maintain the The Commission issued forty-nine (49) new Orders in 2020. Highlights of these Orders are as follows: * * * creditworthiness of the balance sheets of DisCos for the purpose of raising capital for the improvement of electricity network and service delivery. 2. NERC/197/2020 - issued on 20th February 2020 on the Capping of Estimated Bill in the NESI. The objectives of this Order, among others, are to a) stop the practice of arbitrary billing of unmetered R2 and C1 customers at rates that are largely at variance from their actual consumption; b) expedite the metering of unmetered R2 and C1 customers in the NESI; c) steer DisCos towards fast-tracking meter deployment under the Meter Asset Provider ("MAP") Regulations or any other financing arrangement approved by the Commission; d) improve customer satisfaction in the NESI and the willingness of customers to pay for electricity by addressing the pervasive apathy for estimated bills issued to unmetered customers and; e) to reduce the incidence of high collection losses in NESI. 3. NERC/198/2020 - issued on 31st March 2020 on the Transition to Cost Reflective Tariffs in the NESI. This Order was issued sequel to the outcome of the Public Hearings on the consideration of applications filed for extraordinary tariff review by successor DisCos in the NESI. The Order, among others, stipulates; a) that there shall be no increase in tariffs of end-use customers on the 1st April 2020, and b) that the Orders of the Commission (NERC/GL/184/2019-NERC/GL/194/2019) titled "the December 2019 Minor Review of Multi-Year Tariff Order ("MYTO") 2015 and Minimum Remittance Order for the Year 2020" shall remain in force until 30th June 2020 when a new Minor Review Order shall be issued by the Commission. 4-14. NERC's Orders - NERC/198/2020, NERC/199/2020, NERC/200/2020, NERC/201/2020, NERC/202/2020, NERC/203/2020, NERC/204/2020, NERC/205/2020, NERC/206/2020, NERC/207/2020 & NERC/208/2020 issued on 27th August 2020 on the Extraordinary Review of Multi-Year Tariff Order ("MYTO") 2015 for Abuja, Benin, Eko, Enugu, Ibadan, Ikeja, Kaduna, Kano, Jos, Port Harcourt and Yola electricity distribution Companies ("DisCos") * * * respectively. The objective of the Orders, among others, are: a) to ensure that price charged by DisCos are fair to customers and are sufficient to allow DisCos to fully recover the efficient cost of operation, including a reasonable return on the capital invested in the business pursuant to the provisions of Sections 32(d) and 76(2)(a) of EPSRA; b) to provide a path to a transition to fully service-based cost-reflective tariffs by July 2021; c) to reclassify and disaggregate customers and customer clusters on the basis of DisCos' commitment on quality of services to customer clusters; d) to ensure that customer tariffs are commensurate and are aligned with the quality and availability of power supply committed to customer clusters by DisCos; e) to ensure sustained improvement in reliability and quality of supply by incentivising DisCos to off-take energy in accordance with its Vesting Contracts and MYTO load allocations and; f) to develop and implement a framework for enforcing market discipline in respect of market remittances and managing future revenue shortfalls in the industry including minimum market remittance requirements that 15. NERC's Order NERC/209/2020 issued on 28th September 2020 on the 14-Day Suspension of the Extra Ordinary Review of MYTO 2020 Order for Successor Electricity Distribution Licensees.The Order suspends for a period of 14-days, with effect from 28th September 2020 to 11th October 2020,the MYTO 2020 that was issued to Abuja,Benin,Eko,Enugu,Ibadan,Ikeja, Kaduna,Kano,Jos,Port Harcourt and Yola DisCos respectively. It also ordered that all tariffs for end-use customers and market obligations of the DisCos during the 14-day suspension be computed on the basis of rates applicable as at 31st August 2020. 16-26.NERC's Orders-NERC/198B/2020,NERC/199B/2020,NERC/200B/2020 NERC/201B/2020,NERC/202B/2020,NERC/203B/2020,NERC/204B/2020 NERC/205B/2020,NERC/206B/2020,NERC/207B/2020 & NERC/208B/2020 issued on 30th October 2020 on the Extraordinary Review of Multi-Year Tariff Order ("MYTO") 2015 for Abuja, Benin, Eko, Enugu, Ibadan, Ikeja, Kaduna, Kano, Jos, Port Harcourt and Yola Electricity Distribution Companies ("DisCos") respectively. The Orders titled "Revised MYTO 2020" revoke & replace Orders NERC/198/2020-NERC/208/2020 titled "MYTO 2020" for the respective DisCos, and Order NERC/209/2020 on Suspension of the Extra Ordinary Review of MYTO 2020 for the Electricity Distribution Licensees. The Orders adjust the tariffs payable by DisCos' customers in compliance with the policy direction on end-user tariff received from the Honourable Minister of Power on the 15th October 2020 in accordance with section 33 of EPSRA, and the minimum remittance thresholds in accordance with F a) Band A: 10% reduction in the transition to service-based tariff ("S rginal increase experienced due to T"); b) Band B: 10.5% reduction in the marginal increase experienced due to transition to SBT; c) Band C: 31% reduction in the marginal increase experienced due to the transition to SBT; and d) Bands D & E: No change The objectives of the MYTO Orders, among others, are to: a) ensure that price charged by DisCos are fair to customers and are sufficient to allow DisCos to fully recover the efficient cost of operation, including a reasonable return on the capital invested in the business pursuant to provisions of sections 32(d) and 76(2)(a) of ESPRA; b) provide a path to a transition to fully service-based cost reflective tariffs by July 2021; c) reclassify and disaggregate customers and customer clusters on the basis of DisCos' commitment on quality of services to customer clusters; d) ensure that customer tariffs are commensurate an aligned with the quality and availability of power supply committed to customer clusters by DisCos; e) ensure sustained improvement in reliability and quality of supply by incentivising DisCos to off-take energy in accordance with their Vesting * * * Contracts and MYTO load allocation framework for enforcing market discipline managing future revenue shortfalls in remittance requirements to account for ("CRT") and allowed tariffs in the settle and MO. as and; f) develop and implement a line in respect of market remittances and the industry including minimum market differences between cost-reflective tariffs ment of market invoices issued by NBET 27-37. NERC's Orders - NERC/210/2020, NERC/211/2020, NERC/212/2020, NERC/213/2020, NERC/213/2020, NERC/215/2020, NERC/216/2020, NERC/217/2020, NERC/218/2020, NERC/219/2020 & NERC/220/2020 issued on 30th October 2020 on the Amendment of the Order on the Capping of Estimated Bills for Abuja, Benin, Eko, Enugu, Ibadan, Ikeja, Kaduna, Kano, Jos, Port Harcourt and Yola DisCos respectively. The Orders repealed Order NERC/197/2020 on the capping of estimated bills in the NESI and 38-48. NERC's Orders - NERC/221/2020, NERC/222/2020, NERC/223/2020, NERC/224/2020, NERC/225/2020, NERC/226/2020, NERC/227/2020, NERC/228/2020, NERC/229/2020, NERC/230/2020 & NERC/231/2020 issued on 31st December 2020 on the December 2020 Minor Review of MYTO 2020 and Minimum Remittance Orders for Abuja, Benin, Eko, Enugu, Ibadan, Ikeja, Kaduna, Kano, Jos, Port Harcourt and Yola DisCos respectively. The Orders, among others, seek to: a) reflect the impact of changes in the projected Minor Review variables (i.e., the Nigerian and United States ("US") inflation rates, gas prices, NGN/US$ foreign exchange rates, available generation capacity, Ministries, Departments and Agencies ("MDA") losses and CAPEX adjustment) for the period January to December 2021 for the determination of CRT; b) implement a framework to manage revenue shortfalls for the year 2021 through minimum market remittance requirements to account for differences between CRT and allowed end-user tariffs in the settlement of invoices issued by NBET and MO; c) establish the interim payment arrangements and reaffirm the payment securitisation requirement and flow of funds from DisCos to NBET and MO; d) Steer the market to gradual transitioning to CRT and activation of markets contracts in line with the requirements of the Transitional Electricity Market ("TEM"); and e) reaffirm the obligation of core investors in DisCos under the Performance Agreement and Share Purchase Agreements executed with the Bureau of Public Enterprises ("BPE"). (^{\\prime\ \\mathsf{U U^{\\prime\\prime}}}) 49. NERC/232/2020 issued on 31st December 2020 on the December 2020 Minor Review of MYTO 2020 for the Transmission Company of Nigeria Plc ("TCN"). This Order has some similar objectives to the NERC's Orders NERC/221/2020 - NERC/231/2020 and also seeks to: a) reaffirm the obligation of the System Operator ("SO") to comply with the Economic Merit Order of Dispatch ("EMOD") prescribed in the Order towards ensuring compliance with projected least generation cost; b) Reaffirm the obligation of the Transmission System Provider ("TSP") under TCN for the payment of "generation capacity charge" and "loss of revenue" to DisCos based on the deviation between energy delivered to a DisCo and the MYTO allocation arising from TCN inability to deliver power to the affected DisCo; and c) Reaffirm the obligation of DisCos for the payment of "loss of revenue" in favour of TCN in accordance with terms of the Service Level Agreement ("SLA"). * * * 5.1.3. Guidelines In 2020, the Commission finalised and issued two (2) new guidelines for the industry. These are: 1. Guidelines on Competition Transaction Charge ("CTC"): Pursuant to Section 28 of the Act and Eligible Customer ("EC") Regulations, the CTC guidelines were developed to allow the collection of competition transition charges from customers and EC(s) with a view to allowing DisCos to recover the loss of allowable revenue arising from the exit of EC(s) from their network. 2. Guidelines on Electricity Distribution Franchising ("EDF"): Concerned by the inability of the DisCos to satisfactorily meet stakeholders' expectations in the provision of safe and reliable electricity services to customers within their franchise territories, especially those areas that are not considered to be economically viable, the Commission, pursuant to section 96(1), developed the guidelines on EDF that allow franchising of DisCos' operations and coverage areas. This is with a view to improving the quality of electricity supply to customers through third-party investment in metering, billing, collection and rehabilitation and expansion of networks. Electronic copies of the new and existing Regulations, Orders and Guidelines for the industry are freely available on the Commission's website [www.nerc.gov.ng](http://www.nerc.gov.ng/). 5.2. Licensing and Permits In pursuit of delivering on its mandate to consumers, the Commission granted The on-grid, off-grid and embedded grid in the year are summarised in Table 5 issued a total of five (5) new general three (3) generation licences with name respectively. of ensuring an adequate supply of electricity licences to qualified applicants in 2020. Generation licences issued by the Commission . The Commission, after due consideration, on licences and approved the renewal of replate capacities of 235MW and 346MW * * * During the same period, the Commission ap Electricity Distribution Network ("IEDN") Licenc generation licences formerly issued to Cummins (9) and Coronation Utility Iganmu Limited (1) to proved two (2) new Independent and transfers of ten (10) off-grid Power Generation Nigeria Limited CPGNL Limited. Similarly, the Commission approved the transfer of shi (in Jos DisCo) to Highland DisCo Acquisition Lin Commission granted nine (9) new permits for captive across Nigeria with a total capacity of 86.70MW. res of Aura Energy Limited ited. Further to this, the power generation located As reported in Table 5.1, the namep permits issued in the year totalled 66 permits granted in 2020 are provide rate capacity of the generation licences and 7.70MW.Further details on the licences and in Tables D.1 and D.2 of the Appendix. The Commission approved the registration of applicants and issued two (2) new permits to following the satisfactory evaluation of their Isolated Mini-Grid and Interconnected Mini-G presented in Table D.3 of the Appendix. of two (2) new Isolated Mini-Grid Interconnected Mini-Grid applicants applications. The name of all successful grid applicants and their locations are Table 5.1: Summary of New Licences and Permits Granted in 2020 | S/N | Category | | --- | --- | | A. | Licences: | | 1. | On-grid Licence | | 2. | Off-grid Licence | | 3. | Embedded Generation | | 4. | Independent Electricity Distribution Network (“IEDN”) LicenceSub-total | | B. | Permits | | 5. | Captive Power generation PermitGrand Total | | Newly Issued(Qty) | Renewed(Qty) | Total Nameplate Capacity(MW) | | --- | --- | --- | | - | 3 | 346.00 | | 1 | - | 200.00 | | 2 | - | 35.00 | | 2 | - | N/A | | 5 | 3 | 581.00 | | 9 | - | 86.70 | | 14 | 3 | 667.70 | * * * 5.3. Certification of Meter Assets/Service Providers As at the end of 2020, the Commission had to applicants as Meter Asset Providers ("MA of their applications. In addition, following the Commission issued letters of "No Ob KINOD Global Resources Nigeria Limited Technologies. The letters of No Objection MAPs in any DisCo. issued a total of thirty-three (33) permits (P") following the satisfactory evaluation due consideration of their applications, section" to three (3) applicants namely Idid Nigeria Limited and Brooks Field are to allow the recipients to apply to be The Commission also certified seventen following the satisfactory evaluation breakdown of the certified MSPs is in the certification of two (2) existing MSPs of the successful MAPs and MSPs and Tables D.4 and D.5 and D.6 of the App in (17) Meter Service Providers ("MSPs") of their applications. A summarised table 5.2. The Commission also renewed in the installer category. The complete lists their certification class are presented in appendix respectively. ({}^{\\prime}\\mathsf{M S P s}{}^{\\prime\\prime}) | S/N | Meter Service Providers | | --- | --- | | A. | Newly Issued | | 1. | Meter Manufacturer | | 2. | Meter Importers | | 3. | Meter Installers | | 4. | Meter Vendor | | B. | Renewal | | 5. | Meter Installer | | | Total MSPs certified and | | Category | Quantity | | --- | --- | | | 3 | | | 5 | | | 8 | | | 1 | | | 2 | | renewed | 19 | In 2020, the Commission conducted the technical evaluation of the fourteen (14) Eligible Customer ("EC") applications. The combined nameplate capacity of the EC applications is 245.46MW.The Commission is awaiting additional information from the applicants to help complete the technical evaluation and issuance of licences (as applicable). Details and the updated status of the applications are as follows: 5.4. Applications under Evaluation * * * 1. Applicants: Inner Galaxy Limited, Abia State Power required: 25MW Proposed supplier: Mainstream Energy Solutions Ltd ("MESL") Proposed tariff: 27/per kWh, excluding CTC Application Status: Eligible Comm excess custom NBETZ Customer status is yet to be granted by the mission as MESL is yet to provide evidence of capacity that the plant can sell to the eligible user beyond the already contracted capacity with 2. Applicants: KAM Industrial Limited, Ilorin, Kwara State Power required: 15MW Proposed supplier: Mainstream Energy Solutions Ltd Proposed tariff: 27/per kWh, excluding CTC Application Status: Eligible Customer status is yet to be granted due to lack of executed TUOS and evidence of excess capacity that the plant can sell to the eligible customer beyond the already contracted capacity with NBET. Power required: 60MW 4. Applicants: Yongxing Steel Limited, Benin, Edo State Proposed tariff: 27/per kWh, excluding CTC Application Status: Eligible Customer status is not yet granted as the Commission awaits evidence of excess capacity that the plant can sell to the eligible customer beyond the already contracted capacity with NBET. Proposed supplier: Mainstream Energy Solutions Limited ("MESL") Proposed tariff: 27/per kWh, excluding CTC * * * Application Status: Eligible Cus lack of e capacity the beyond the customer status is yet to be approved due to executed TUOS and evidence of excess at the plant can sell to the eligible customer already contracted capacity. 5. Applicants: Crown Flour Mills Limited, Ilorin, Kwara State Power required: 3MW Proposed supplier: Mainstream Energy Solutions Limited Proposed tariff: 27/per kWh, excluding CTC Application Status: Eligible Customer status is yet to be approved as the applicant is yet to submit the customer's current source of power supply and the voltage level at which supply is taken and the average load system per month. 6. Applicants: Lord's Mint Limited, Abeokuta, Ogun State Power required: 3MW Proposed supplier: Mainstream Energy Solutions Ltd Proposed tariff: 27/per kWh, excluding CTC Application Status: Eligible Customer status yet to be approved as the applicant is yet to submit customer connection point, trading point and types of meters installed, and tax clearance certificate. Power required: 10MW Proposed supplier: Paras Energy Limited Application Status: Eligible Custom executed TUO AEDC. er status yet to be issued due to lack of and letter of no indebtedness from Power required: 20MW Proposed tariff: 38.01/per kWh, excluding CTC * * * Proposed supplier: Mainstream Energy Solutions Ltd Proposed tariff: N/A Application Status: Eligib lack capa beyo the Customer status is yet to be approved due to of executed TUOS and evidence of excessity that the plant can sell to the eligible customer d the already contracted capacity. 9. Applicants: Phoenix Steel Mills, Sagamu, Ogun State Power required: 20MW Proposed tariff: N/A Proposed supplier: Mainstream Energy Solutions Ltd Application Status: Eligible Custom lack of evidence sell to the el contracted cap er status is yet to be approved due to use of excess capacity that the plant can gible customer beyond the already city. 10. Applicants: Edo State Government, Benin City, Edo State Power required: 5MW Proposed supplier: Ossiomo Power Company Limited (Embedded) Proposed tariff: 41/per kWh, excluding CTC Application Status: Provisional ap the submission between Ossi DisCo Plc. proval given by the Commission pending of the final bilateral project agreement mo Power company limited and Benin Power required: 2MW Application Status: The Commission has y status due to incor applicant. t to grant the Eligible Customer complete documentation by the Proposed supplier: Geogrid Lightec Limited Proposed tariff: 47.28/per kWh, excluding CTC * * * 12. Applicants: Ashaka Cement Plc Power required: 15MW Proposed supplier: Mainstream Energy Solutions Limited (MESL) Proposed tariff: N/A Application Status: Eligible lack of sell to contract Customer status is yet to be approved due to evidence of excess capacity that the plant can the eligible customer beyond the already ed capacity. 13. Applicants: Livestock Ltd Power required: 2MW Proposed supplier: Tower Energy Solutions & Systems Proposed tariff: 82/per kWh, excluding CTC Application Status: Undergoing evaluation. 14. Applicants: Viathan Engineering LTD on behalf of NATCOM Union Bank Sura Market Power required: 7.955MW Proposed supplier: Island Power Limited 5.5. Public Consultation and Workshop - Consultation Extraordinary Tariff Review (45) and (47) of EPSRA, Business Rules of Regulations, the Commission conducted filed by all DisCos for a review of their path to financial sustainability, and b) review of rates payable to generation service of spinning reserve. ("ETR"): In compliance with sections of the Commission and the Tariff Review (Public Hearings on; a) applications respective end-user tariffs as part of a application filed by the TCN on the companies that provide the ancillary The Commission conducted the following public consultation and workshop. * * * The public hearings on the consideration of applications filed for ETR by DisCos were held from 25th February to 9th March 2020 at various locations within the franchise areas of the respective DisCos while that of the TCN was held on 11th March 2020 at the Commission's headquarters in Abuja. The industry stakeholders at the Public Hearings included consumer groups, intervenors, investors, GenCos, DisCos, TCN, and network operators among others. Views and comments received during the public hearings were analysed by the Commission prior to the issuance of Order NERC Order/198/2020. - Workshop on Distribution Usage Fee ("DUF"): The Commission, in collaboration with the Nigerian Energy Support Programme ("NESP") co-funded by the European Union and the German Government, held a webinar workshop on Mini-grid Projects on Distribution Usage Fee. The virtual workshop sought to acquaint investors and other interested stakeholders with the Mini-grid Distribution Usage Fee Computation Tool, a methodology for determining the rates payable to a DisCo for using its distribution assets for mini-grid operation. The Commission also conducted stakeholder engagement through town hall meetings, radio programmes and virtual town hall meetings and consumer assembly in accordance with the provisions of the EPSRA. The engagements sought to improve stakeholders' awareness of the existing regulations, and consumer rights and obligations as provided in the industry rules and in the EPSRA. The Commission did not commence new enforcement serious infraction by licensees was identified compliance with industry rules and regulations, existing enforcement actions brought forward. Regulations and Orders, accidents and electric required data within a timeline and the failure within the stipulated timeframe. ement action in 2020 as no new However, in a bid to ensure the Commission continued with the These include the violations of cution cases, failure to provide to comply with Forum decisions 5.6. Compliance Monitoring and Enforcement * * * 5.7. Litigation and Alternative Dispute Resolution 5.7.1. Litigation The Commission was involved in new ongoing litigations, which directly or indi include the following: and ongoing litigations. The new and directly involved the Commission in 2020 1. A declaration that NERC Order:NERC/G abuse of court process; is ultra vires; is hearing and made without due process. October 2020 in favour of the Commissio /168 dated 9th May 2019 is an breach of PIPP's right to a fair This matter was struck out on 7 2. A declaration that it is the responsibility of litigant (Hon. Olufemi Adeniregun) is con independent electricity distribution network was struck out on 7 October 2020 in favor the Commission to ensure that the connected to any private electricity or operator of his choice. This matter ur of the Commission; 3. A perpetual injunction restraining the Commission from with the Commission's proceedings/ruling on Comp NERC/PHF/079/2018 dated 16th August 2018; acting in furtherance paint as contained in 4. A court action by IBEDC and its' core investor challenging the suspension of the Board of Ibadan DisCo by the Commission; 5. A declaration that the failure of the Comm before unilaterally increasing the prescrib DisCo from 22% to 42% and subsequent Orders NERC/GL/173A and NERC/GL/ right to fair hearing and violation of the C provided under Section 32(3) of the EPSRA Constitution as amended; sion to consult with Enugu DisCo and minimum remittance for Enugu to 50%, as contained in NERC 87B, constitutes a denial of the claimant's rights to be consulted as 2004 and Section 36 of the 1999 * * * 7. An order granting leave to the of declaration, certiorari, pro Commission to conduct a for communicated vide the Comm the litigants to apply for judicial review (by way exhibition and injunction) of the decision of the insic audit of the operations of the litigants as mission's letter dated 20 March 2020; 8. The Registered Trustees of African Initiative Again seeking a declaration that the Commission lacks the of intention to cancel licences of erring DisCos; t Abuse of Public Trust power to issue a notice 9. Ibadan DisCo seeking a declaration that the issuance of Eligible Customers ("EC") Regulations on certain electricity consumers are null and void ourported declaration and conferment of EC status and liable to be set aside; 10. The Registered Trustees of Human Right the execution of a DUoS agreement mandatory prior to NERC's approval Foundation seeking a declaration that between an EC and a supplier is for energy delivery to the EC; 11. Enugu DisCo and Interstate Electrics Limited seeking a declaration that the construction of an IEDN by Ariaia Market Energy Solutions Ltd, Gas and Power Infrastructure Development Ltd, Televeras Group of Companies Ltd and Candesco Ltd is an act of trespass, illegal and unlawful and seeking an Order of perpetual injunction restraining NERC from granting licence to the above four (4) Defendants. 12. Olumide Babalola seeking amongst other chapter IV, Sections 17(3) and 18 of the Commission are ultra vires and in case of the EPSRA; and ers a declaration that provisions of AP Regulations (2018) as issued by intravention of Section 67(1) and (2) While final judgements have been given on some of these litigations, judgements are yet to be passed on others. * * * 5.7.2. Alternative Dispute Resolution The Commission did not handle any disputes better as there was no pending dispute and no new Commission however approved the appointment of Resolution Council Panel for the NESI. The appo with section 42 (1.3) of the Market Rules, which constitute the Panel and section 42(3.8)(c) of reappointment of members for a second term. een stakeholders of the industry dispute reported in 2020. The of a twelve (12) members Dispute ment of the members is in line empowers the Commission to the Market which permits the * * * NIGERIAN ELECTRICITY REE REGULATORY COMMISSION PART 6: CONSUMER AFFAIRS * * * 6.1 Consumer Education & Enlightenment 6.2 Metering of End-use Customers 6.3 Consumer Complaints 6.4 Forum Offices 6.5 NESI Situation Room 6.6 SBT Situation Room 6.7 Health and Safety * * * 6.1 Consumer Education and Enlightenment To ensure continuous customer education on their rights and obligations, the Commission monitored the customer enlightenment programmes held by the eleven (11) DisCos in 2020. The Commission also conducted several town hall meetings with electricity consumers. Most of the town hall meetings were held virtually due to the outbreak of COVID-19 pandemic and the subsequent lockdown in 2020. Specifically, the Commission conducted one (1) face-to-face town hall meeting with electricity consumers in Benin City, Edo State, on the $ 17^{\\mathrm{th}} $ March 2020, and in collaboration with Citizen Connect & Advice Centre ("CCAC"), held several virtual town hall meetings with electricity consumers between 14th-17th June 2020. The Commission also continued with the airing of the pre-recorded radio enlightenment program 'Electricity Update' across twelve states of the country including the Federal Capital Territory ("FCT"). In addition to the recorded radio program, the Commission introduced a live radio session where the Commission's staff are on air to address key issues in the Nigerian Electricity Supply Industry ("NESI"). 17^{\\dagger h} & ({}^{\\prime}\\mathsf{C C A C}{}^{\\prime\\prime}) 6.2. Metering of End-use Customers The status of metering of end-use customers the total number of registered customers as out of which 4,666,191 have been metered represented in Table 6.1 indicates that t December 2020 was 11,841,819 representing 39.40% metering rate. * * * Table 6.1: Customers Metering Status by DisCos as at December 2020 | DisCos | Registered Customer as at 2020 | Metered Customer as at 2020 | | --- | --- | --- | | Abuja | 1,468,404 | 707,534 | | Benin | 1,180,650 | 571,600 | | Eko | 541,560 | 286,847 | | Enugu | 1,183,093 | 505,136 | | Ibadan | 2,907,214 | 807,573 | | Ikeja | 1,145,622 | 562,837 | | Jos | 598,430 | 172,627 | | Kaduna | 721,436 | 232,405 | | Kano | 699,618 | 352,493 | | Port Harcourt | 985,782 | 387,025 | | Yola | 410,010 | 80,114 | | Overall DisCos | 11,841,819 | 4,666,191 | | Metered Customer as at 2019 | Metering Progress as as at 2020 | Metering Gap as at 2020 | | --- | --- | --- | | 641,738 | 48.18% | 51.82% | | 553,394 | 48.41% | 51.59% | | 255,880 | 52.97% | 47.03% | | 476,955 | 42.70% | 57.30% | | 783,878 | 27.78% | 72.22% | | 488,917 | 49.13% | 50.87% | | 170,522 | 28.85% | 71.15% | | 157,576 | 32.21% | 67.79% | | 147,104 | 50.38% | 49.62% | | 374,793 | 39.26% | 60.74% | | 78,034 | 19.54% | 80.46% | | 4,128,791 | 39.40% | 60.60% | Notes of the table: DisCos are the electricity distribution companies Since the implementation of the Meter Asset Pro National Mass Metering Programme ("NMMP") progress. In 2020, an additional 537,400 e installed. This is a 60.47% increase (202,504 334,896 meters installed in 2019. ider ("MAP") scheme and the customer metering continues to d-user customer meters were installations) compared to the Notwithstanding the additional meters it for end-use customers is still a key charge Commission in Table 6.1 indicate that electricity customers are still on estimated apathy towards payment for electricity b installed in 2020, the huge metering gap enge in the industry. The records of the as high as 60.60% of the registered billing which has contributed to customer ls. The percentage of metered customers by each DisCo as at 31st December 2020 is represented in Figure 6.1. Only Kaduna, Ikeja, Kano and Eko made progress in metering their customers during the period under review as compared to 2019. While Eko and Kano DisCos have metered 50%+ of their registered customers as at 31st December 2020, Yola, Ibadan and Jos have not metered up to 30% of their customers. * * * Figure 6.1: Share of Customers Metered by DisCos as at 31 Dec. 2020 Similarly, the NMMP is an initiative of the Federal Government of Nigeria launched in 2021 to rapidly bridge the metering gap in the NESI. This is a policy intervention with support from the Central Bank of Nigeria ("CBN") for the provision of longterm (10-year tenure) single-digit interest loans to DisCos strictly for the provision of meters to customers. This policy provides that only local meter manufacturers or assemblers shall participate in the NMMP. Under the NMMP scheme, customers are metered on DisCo's account without payment for the meters by customers except through end-user tariffs. ({}^{\\prime}\ {sf C C B{}^{\\prime\\prime}}) * * * It is noteworthy to highlight that though meter depi with the concurrent operation of MAP and NMM commenced the review of MAP Regulations to in for a smooth implementation and ensure that the realised to close the metering gap in the NESI or ayment in the NESI has increased P schemes, the Commission has corporate NMMP that will allow full benefits of both schemes are time. As part of this review, the Commission is de meter financing (Vendor finance, Self-fun efficient meter financings). Details of the thre finalised by the Commission are as follow: developing three (3) other frameworks for used by DisCos, and Other external (3) more metering frameworks being 1. Vendor Finance: This is a mutual agreement between a DisCo and a Local Meter Manufacturer/Assembler ("LMMA") or Meter Asset Provider ("MAP") on a deferred payment arrangement where the base cost of meters shall not exceed the regulated price approved by the Commission. Where the cost of financing exceeds the rate approved by CBN, the approval of the Commission will be obtained before the execution of the agreement. 2. Self-funded by DisCo: This involves procurement of meters from other sources outside the MAP and NMMP framework.The allowable costs of meters, accessories, installation and warranties should not exceed the regulated pricing approval by the Commission and the terms of supply should not conflict with the terms of existing MAP and NMMP contracts. 3. Other External Efficient Meter financings: The Comm other external meter financings that are efficient, with the terms of existing MAP and NMMP contract session has also approved post-effective and in tune. * * * 6.3. Customers Complaints The complaints received by DisCos over the period 2018-2020 are presented in Table 6.2. The eleven (11) DisCos nationwide received a total of 857,108 complaints in the year 2020 as against 648,537 complaints received in the year 2019. This indicates approximately 2,348 complaints per day in 2020 compared to the daily average of 1,777 complaints received in 2019. Enugu DisCo received the highest number of customer complaints (228,254), followed by Ikeja DisCo (152,817) while Yola DisCo recorded the least complaints (7,909) as in the previous years. During the year under review, 93.25% (799,236) of the complaints were reportedly resolved. On a year-on-year basis, Abuja and Ibadan DisCos recorded the highest improvement of 15.73 and 8.00 percentage points respectively in customers' complaints resolution rate in 2020 relative to their 2019 performance. Conversely, Eko and Yola DisCos recorded declines of -1.68 and -0.19 percentage points respectively in customer complaints handling performance in 2020 relative to 2019. Further details of the categories of complaints received by DisCos from 2016 to 2020 are presented in Table E.4 of the Appendix. Table 6.2: Complaints Received and Resolved by DisCos, 2017-2020 | | 2020 | | | --- | --- | --- | | DisCos | Complaints | | | Total Received | Total Resolved | | | Abuja | 113,000 | 109,462 | | Benin | 50,955 | 43,289 | | Eko | 104,210 | 92,890 | | Enugu | 228,254 | 222,652 | | Ibadan | 34,264 | 27,212 | | Ikeja | 152,817 | 138,749 | | Jos | 27,196 | 25,390 | | Kaduna | 30,358 | 27,954 | | Kano | 29,097 | 28,475 | | Port Harcourt | 79,048 | 75,350 | | Yola | 7,909 | 7,813 | | Overall DisCos | 857,108 | 799,236 | | 2019 | | | 2018 | | | --- | --- | --- | --- | --- | | Complaints | | | Complaints | | | % Resolved | Total Received | % Resolved | Total Received | % Resolved | | 96.87 | 62,112 | 81.14 | 54,418 | 90.66 | | 84.96 | 50,259 | 84.85 | 119,747 | 35.54 | | 89.14 | 78,100 | 90.82 | 56,559 | 91.62 | | 97.55 | 154,879 | 89.99 | 70,957 | 63.90 | | 79.42 | 35,389 | 71.42 | 36,231 | 86.77 | | 90.79 | 123,058 | 87.67 | 91,253 | 84.64 | | 93.36 | 21,318 | 92.04 | 14,217 | 91.26 | | 92.08 | 40,374 | 88.59 | 36,769 | 81.04 | | 97.86 | 23,499 | 94.79 | 20,297 | 91.11 | | 95.32 | 50,841 | 87.87 | 17,183 | 81.48 | | 98.79 | 8,708 | 98.98 | 9,651 | 97.90 | | 93.25 | 648,537 | 87.50 | 527,282 | 72.53 | Notes of the table: DisCos are the electricity distribution companies * * * The DisCos' customer complaints centred on service load shedding, metering, estimated billing, disconnect among others. In 2020, all the eleven (11) DisCos complaints on each of the aforementioned key issu ce interruption, poor voltage, action, and delayed connection received several numbers of As was in the previous years, the most dominant categories of customer complaints were metering and billing in 2020. The category of complaints presented in Table E.5 of the appendix and the summary represented in Figure 6.2 show that metering and billing accounted for 384,562 (44.87%) of the total complaints received in 2020 as against 345,361 (53.25%) of the total complaints recorded in 2019. This implies that, on average, about 1,051 customers complained about metering and billing per day in 2020. Another issue of serious concern to customers is service interruption and disconnection, which accounted for 17.86% (153,080) and 10.43% (89,363) respectively of the total customer complaints received in the year 2020. On a year-on-year basis, customers' complaints of service interruption increased significantly from 11.46% of the total complaints in 2019 to 17.86% in Figure 6.2: Categories of Complaints Received by DisCos * * * To address and ensure an effective way of handling customer complaints, the Commission has continuously monitored the complaint handling and resolution process adopted by all DisCos. The Commission strictly monitors the DisCos' compliance with its directive on monthly submission of their customers' complaint reports ensuring timely regulatory interventions when necessary. Also, the strategy adopted for the monitoring is under review to further improve the regulatory oversights. This also includes the strict review of the operations in the Commission's Forum Offices which are set up to redress the customers' complaints that are not adequately resolved by the DisCos. 6.4. Forum Offices In line with the Commission's mandate on customer protection, Forum Offices were set up pursuant to section 80(1)(b) of the EPSRA to hear and resolve customer complaints not satisfactorily resolved at the DisCos' Customer Complaints Units (DisCos-CCU). The Forum Office is managed by the Forum Secretary while hearings are conducted by five (5) Forum Panel in redressing customers' and operators' unresolved disputes as enshrined in the NERC's Customer Complaints Handling Standards and Procedures ("CCHSP") Regulations. Figure 6.3 presents a graphical representation of the customer complaints resolution procedures in the NESI. * * * Figure 6.3: NERC's Customer Complaint Flow Chart as at December 2020 * * * As at 30th December 2020, the Commission Offices in twenty-nine (29) states and the FCT addresses and contacts of the Commission Appendix XIV. Members of the Forum Panel selected from the following groups/agencies: had thirty (30) operational Forum Abuja. The details including names, Forum Offices are presented in are not Commission Staff and are 1. One representative of Industrial custom Manufacturers' Association of Nigeria ("MA rs to be nominated by the \[1"\]. 2. One representative of Commercial cus Association of Chambers of Comm ("NACCIMA"). omers to be nominated by the Nigerian Force, Industry, Mining and Agriculture 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 nominated by the Commission. 5. One nominee based in the DisCos operating area who has an electrical engineering background nominated by the Commission. The summary of the complaints across the Forum Offices in 2020 is presented in Table 6.3. The total number of new complaints received in 2020 was 7,180 from customers who were dissatisfied with DisCos' effort at resolving their lodged complaints while there were an additional 1,258 pending complaints which were carried over from 2019 making a total of 8,438 complaints. The Forum Office covering Ibadan DisCo's franchise area had the highest number of complaints (2,092) representing 29.14% of total complaints received at the Forum Offices in 2020. This was followed by the Forum Office covering Ikeja DisCo's franchise area which received 1,571 complaints during the same period. The Forum Office covering Yola DisCo's franchise area had the lowest number of complaints (347) representing 4.11% of total complaints received at the Forum Offices in 2020. The Forum Offices' Panels had a total of 115 sittings in 2020 as compared to 240 sittings held in 2019. The decline in the Panels' sittings in 2020 was caused by the restriction of movement imposed by the government to curb the spread of COVID19 and the subsequent resolution of the Commission suspending Forum Hearings for 6 months (from 4th April-31st September 2020). To compensate for this, the Forum Offices leveraged technology to communicate customers' complaints to the respective DisCos for redress. Approximately 90.21% of the total 8,438 complaints before the Forum Offices were resolved either through formal hearings or preliminary engagements between the Forum Secretaries and the DisCos. This resolution rate indicates that about nine (9) in every ten (10) disputes that got to the Forum Offices in 2020 were resolved. The Forum Offices covered by Enugu DisCo had the highest number of sittings (29) and those covered by Ibadan DisCo had the highest number of resolved complaints (1,689, 80.74%) in 2020. It is worthy of note that, except for Forum Offices covering Enugu and Ibadan DisCos, the Forum Offices had more than 85% of complaints received in 2020 resolved during the period. The Forum Offices covering Benin DisCo resolved about 99.68% of the complaints received. On average 254 complaints were resolved per Forum Office in 2020. The up-to-date list of the Commission's Forum Offices with the addresses and contacts is presented in Table 6.4. Table 6.3: Complaints Handled by Forum Offices in 2020 | Forum Offices | Accountable DisCos | | --- | --- | | Abuja, Lafia & Lokoja | Abuja | | Asaba & Benin | Benin | | Eko | Eko | | Abakaliki, Akwa, Enugu, Owerri, & Umuahia | Enugu | | Ibadan, Ilorin & Osogbo | Ibadan | | Ikeja | Ikeja | | Bauchi, Gombe, Jos & Makurdi | Jos | | Gusau, Kaduna, Kebbi & Sokoto | Kaduna | | Jigawa, Kano & Katsina | Kano | | Calabar, Port Harcourt & Uyo | P/Harcourt | | Yola | Yola | | All Forum Offices | All DisCos | | $Complaint Received^{1}$ | $Complaint Resolved^{2}$ | $Complaint Pending^{3}$ | No of Sittings | | --- | --- | --- | --- | | 411 | 372 | 22 | 6 | | 621 | 619 | 2 | 12 | | 508 | 484 | 24 | 4 | | 690 | 551 | 127 | 29 | | 2,092 | 1,689 | 400 | 14 | | 1,571 | 1,503 | 66 | 19 | | 142 | 122 | 20 | 1 | | 403 | 360 | 41 | 13 | | 418 | 405 | 7 | 4 | | 1,235 | 1,171 | 62 | 13 | | 347 | 336 | 11 | 0 | | 8,438 | 7,612 | 782 | 115 | Complaint resolved excludes 44 complaints withdrawn or rejected 3. Some of the pending complaints are still within the regulatory timeframe of 2 months to resolve * * * The different categories of complaints received at the Forum Offices in 2020 are represented in Figure 6.4. Similar to the categories of complaints received by the DisCos, billing and metering issues topped the complaints received by Forum Offices and accounted for approximately 54.91% and 17.29% of the total complaints respectively. This implies that billing and metering issues were mostly the complaints not satisfactorily resolved by DisCos' CCUs.The Commission is working on harmonising its customer service regulations as well as ensuring improved and increased customer education in a bid to reduce complaints on these issues. Further details on the customers' compla Forum Offices during the period under Appendix section. ests received, resolved and outstanding by review are presented in Table E.6 of the Figure 6.4: Category of Complaints Received by Forum Offices in 2020 While some of the undecided cases at the Forum Offices were due to incomplete submission and/or withdrawal by the concerned consumers, the Commission continued the review of the operation of the Forum Offices to ensure speedy resolution of complaints in line with the Commission's strategic objective of upholding high customer care standards. The Commission is working towards establishing additional Forum Offices and other customer complaint resolution channels in a bid to increase overall customer complaint management in the NESI. * * * Table 6.4: Lists and Addresses of NERC Forum Offices as at December 2020 | No. | Forum Office | Location | Telephone | Email | | --- | --- | --- | --- | --- | | 1 | Abakaliki, Ebonyi State | 3, Ezekuna Crescent, Off Nsugbe Street, Abakaliki Ebonyi State | 09037808590 | [abakalikiforum@nerc.gov.ng](mailto:abakalikiforum@nerc.gov.ng) | | 2 | Abuja, FCT | 14, Road 131, Gwarinai, Federal Capital Territory, Abuja | 08146822250 | [abujaforum@nerc.gov.ng](mailto:abujaforum@nerc.gov.ng) | | 3 | Asaba, Delta State | Denis Osadebe Way, Beside Mobil Filling Station, Asaba, Delta State | 09062277247 | [asabaforum@nerc.gov.ng](mailto:asabaforum@nerc.gov.ng) | | 4 | Awka, Anambra State | Plot 80, Aroma Junction Layout, Opp. CBN, Awka, Anambra State | 09037808594 | [awkaforum@nerc.gov.ng](mailto:awkaforum@nerc.gov.ng) | | 5 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bauchi, Bauchi State | 09062924607 | [bauchiforum@nerc.gov.ng](mailto:bauchiforum@nerc.gov.ng) | | 6 | Benin, Eda State | 34, Akpakpawa Street, Benin City, Edo State | 09037808592 | [beninforum@nerc.gov.ng](mailto:beninforum@nerc.gov.ng) | | 7 | Birnin Kebbi, Kebbi State | 8, Ahmadu Bello Way, Opp. Kebbi State Government House, Kebbi State | 09062863161 | [birninkebbiforum@nerc.gov.ng](mailto:birninkebbiforum@nerc.gov.ng) | | 8 | Calabar, Cross Rivers State | Plot 109, MCC Road by Ibok Street, Calabar, Cross River State | 09062863159 | [calabaforum@nerc.gov.ng](mailto:calabaforum@nerc.gov.ng) | | 9 | Dutse, Jigawa State | Dutse G.R.A, Dutse, Jigawa State | 07031704827 | [jigawaforum@nerc.gov.ng](mailto:jigawaforum@nerc.gov.ng) | | 10 | Eko, Lagos State | 61, Odunlami Street, Off Marina, Lagos Island, Lagos State | 08106807261 | [ekotorforum@nerc.gov.ng](mailto:ekotorforum@nerc.gov.ng) | | 11 | Enugu, Enugu State | John Anichukwu Close, Plot 7 Mkpkoki Pocket Layout, Enugu, Enugu State | 08146822300 | [enuguforum@nerc.gov.ng](mailto:enuguforum@nerc.gov.ng) | | 12 | Gombe, Gombe State | Government Layout GDP/2, Along Ministry of Education Road, Gombe State | 08140440079 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) | | 13 | Gusau, Zamfara State | 2 Cante Daij, J. B. Yakubu Road, Gusau, Zamfara State | 09062863163 | [gusauforum@nerc.gov.ng](mailto:gusauforum@nerc.gov.ng) | | 14 | Ibadan, Oyo State | Jibowu Street, Opp. Magara Police Station, Iyaganko G.R.A, Ibadan, Oyo State | 08146826252 | [ibadaforum@nerc.gov.ng](mailto:ibadaforum@nerc.gov.ng) | | 15 | Ikeja, Lagos State | 199, Obafemi Awolowo Way, Alausa, Ikeja, Lagos State | 08106807298 | [ikejaforum@nerc.gov.ng](mailto:ikejaforum@nerc.gov.ng) | | 16 | Ilorin, Kwara State | 30, Stadium Road, Off Taiwo Road, Ilorin, Kwara State | 09062924603 | [ilorinforum@nerc.gov.ng](mailto:ilorinforum@nerc.gov.ng) | | 17 | Jos, Plateau State | 5a, Ray-field Road, Jos, Plateau State | 09037808597 | [josformorum@nrc.gov.ng](mailto:josformorum@nrc.gov.ng) | | 18 | Kaduna, Kaduna State | 22, Ahmadu Bello Way, Opposite NNDC Building, Kaduna, Kaduna State | 08106807299 | [kadunaforum@nrc.gov.ng](mailto:kadunaforum@nrc.gov.ng) | | 19 | Kano, Kano State | 2, Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 08146822222 | [kanoforum@nrc.gov.ng](mailto:kanoforum@nrc.gov.ng) | | 20 | Katsina, Katsina State | 7, Abuja Crescent, Off Hassan Usman Katsina Road, Katsina State | 07031704821 | [katsinaforum@nrc.gov.ng](mailto:katsinaforum@nrc.gov.ng) | | 21 | Lafia, Nasarawa State | Manyi Street, Off Jos Road, Bukan Sidi, Lafia, Nasarawa State | 09062924601 | [lafiforum@nrc.gov.ng](mailto:lafiforum@nrc.gov.ng) | | 22 | Lokoja, Kogi State | Hassan Kastina Rd, Opp. State Civil Service Commission, Zone 8 Police HQ, Lokoja, Kogi State. | 09062924599 | [lokojaforum@nrc.gov.ng](mailto:lokojaforum@nrc.gov.ng) | | 23 | Makurdji, Benue State | Hephzibah Plaza, Atom Kpera Road, Opp, Makurdi Int'l School, Benue State | 09062277249 | [makurdiforum@nrc.gov.ng](mailto:makurdiforum@nrc.gov.ng) | | 24 | Osogbo, Osun State | 51, Isika Adeleke Way, Along Okefia-Alekuwodo Road, Osogbo, Osun State | 09062924604 | [osogboforum@nrc.gov.ng](mailto:osogboforum@nrc.gov.ng) | * * * 6.5. NESI Situation Room During the period of the COVID-19 lockdown in 2020, the Commission established a NESI Situation Room led by the Commissioners and top management staff to ensure electricity customers continue to receive uninterrupted electric power services. The NESI situation lasted for 6 Months (4th April-31st September 2021) during which the Forum Offices were closed as a result of the national lockdown imposed by the government at the Federal and state levels to curtail the spread of the COVID-19 outbreak in Nigeria. The Situation Room leveraged on technology to monitor and coordinate electricity services across the country by gathering data on grid performance across the value chain (including generation, transmission, distribution and end-user level), reports on issues as they arose and providing immediate resolutions. The summary presented in Table 6.5 indicates that, during the period 4th April 31st September 2020, the NESI's Situation Room, through its sub-committee on Customer Complaints Handling, received a total of 6,552 complaints on service interruption from the end-users indicating an average of 36 complaints per day. The end-users under Abuja and Jos DisCos service areas were respectively accountable for the highest and lowest number of complaints. The NESI's Situation Room tracked daily the customers' complaints with the relevant DisCos to ensure expeditious resolution and at the end of September 2020, 55.36% of the total complaints were resolved satisfactorily. Many of the service interruption complaints that could not be immediately resolved during the period had to do with issues requiring capital investment such as the replacement of faulty transformers. Resolutions of others were delayed by DisCos' inability to immediately access the materials required for fixing the technical challenges on their networks due to the restrictions on movement imposed by some states limiting movement of DisCos' workers. * * * Table 6.5: Interruption Complaints Handled by NESI Situation Room in 2020 | Situation Room | Accountable DisCos | | --- | --- | | NESI Situation Room at NERC Headquarters | Abuja | | Benin | | | Eko | | | Enugu | | | Ibadan | | | Ikeja | | | Jos | | | Kaduna | | | Kano | | | P/Harcourt | | | Yola | | | All DisCos | | | Complaint Received | Complaint Resolved | Complaint Pending | Resolution Rate(%) | | --- | --- | --- | --- | | 1,480 | 1,129 | 351 | 76.28 | | 419 | 141 | 278 | 33.65 | | 503 | 243 | 260 | 48.31 | | 609 | 256 | 353 | 42.04 | | 978 | 473 | 505 | 48.36 | | 1,248 | 755 | 493 | 60.50 | | 191 | 125 | 66 | 65.45 | | 289 | 111 | 178 | 38.41 | | 207 | 91 | 116 | 43.96 | | 375 | 184 | 191 | 49.07 | | 253 | 119 | 134 | 47.04 | | 6,552 | 3,627 | 2,925 | 55.36 | Note of tables: Customers' complaints on service interruption were received from electricity customers through telephone calls, text and WhatsApp messages, and emails; The complaints received, resolved and pending cover the period 4 April-30 September 2020. 6.6. SBT Situation Room Following the introduction of the service-based payable by end-users to the quality of service Commission, during the year, established an SBT objectives of the SBT-SR, among others, are to: ariff ("SBT") that ties the rate committed by the DisCo, the Situation Room ("SBT-SR"). The - Respond to customers' enquiries with regards to the rationale for the SBT. - Monitor Customer Bands or Hours of Supply for different localities (feeders) of the DisCo approved by the Commission and tariffs payable. - Resolve or refer (where applicable) customers' complaints on SBT-related issues to the relevant DisCo for resolution. - Leverage technology (e.g., Email, phone calls, WhatsApp, and Twitter) to monitor the resolution of customers' complaints referred to specific DisCos. 6 The SBT system was introduced in September 2020 while the SBT situation room operated between September - December 2020. * * * and/or quality of service from the end-users, indicating an average of 20 complaints per month. Ikeja DisCo's customers accounted for the highest number of complaints. SBT-SR responded daily to customers' complaints and enquiries to ensure expeditious resolution and at the end of the year 2020, 50.79% of the complaints were resolved satisfactorily. The pending complaints are those specific to the DisCos and have been referred to the relevant DisCos with a clear timeline for resolution. Also, the Commission, through its compliance monitoring team, gathered data on the feeders and assessed the level of compliance with SBT vis-à-vis the service level commitments by DisCos as provided for in the Multi-Year Tariff Orders ("MYTO"). Table 6.6: SBT Complaints Handled by SBT Situation Room in 2020 | Situation Room | Accountable DisCos | Critical DisCos | | --- | --- | --- | | SBT Situation Room at NERC's Headquarters | Abuja | | | Benin | | | | Eko | | | | Enugu | | | | Ibadan | | | | Ikeja | | | | Jos | | | | Kaduna | | | | Kano | | | | P/Harcourt | | | | Yola | | | | All DisCos | | | | Complaint Received | Complaint Resolved | Complaint Pending | Resolution Rate(%) | | --- | --- | --- | --- | | 9 | 5 | 4 | 55.56 | | 3 | 3 | 0 | 100.00 | | 2 | 0 | 2 | 0.00 | | 0 | 0 | 0 | - | | 6 | 3 | 3 | 50.00 | | 32 | 14 | 18 | 43.75 | | 1 | 1 | 0 | 100.00 | | 3 | 3 | 0 | 100.00 | | 0 | 0 | 0 | - | | 7 | 3 | 4 | 42.86 | | 0 | 0 | 0 | - | | 63 | 32 | 31 | 50.79% | Note of tables: Customers' complaints on SBT were received from electricity customers through telephone calls, text, WhatsApp and Twitter messages, and emails; This report covers the period 24 September - 31 December 2020. 6.7. Health and Safety The safety of all electricity providers are priorities of the Commission. In accordance Commission continued to monitor the order to guarantee the delivery of so 2020, the Commission received a mandatory health and safety reports fr and users in Nigeria remains one of the key assurance with section 32 (1)(e) of EPSRA, the health and safety performance of NESI in use and reliable electricity to Nigerians. In total of four hundred and fifty-six (456) from licensees. * * * These reports were analysed in line with the provision of section 32(1)(e) of ESPRA for monitoring and evaluating of health and safety performance of licensees in order to ensure that operators abide by their responsibility of delivering safe electricity services to consumers. The summary statistics on the accidents experienced in the NESI between 2016 and 2020 are presented in Table 6.7. Table 6.7: Electrical Accident in NESI between 2016 and 202 | Item | | --- | | Number of Expected H&S Reports | | Number of H&S Reports Submitted | | Number of Injuries | | Number of Deaths (employees & third parti | | | Year | | | | | | --- | --- | --- | --- | --- | --- | | | 2020 | 2019 | 2018 | 2017 | 2016 | | (es) | 480 | 480 | - | - | - | | 456 | 364 | 323 | 268 | 317 | | | 76 | 77 | 29 | 55 | 77 | | | 40 | 42 | 104 | 116 | 151 | | There was a slight improvement in the health and safety performance of the operators between 2019 and 2020 as the number of deaths involving both employees of the operators and third parties declined from 42 to 40 deaths in 2020. Also, the number of injured persons decline from 77 to 76 persons during the same period. In line with its 2017-2020 strategic goals, the Commission has intensified efforts at implementing various safety programmes aimed at eliminating accidents in the industry. Some of the safety programs being implemented by the Commission 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. * * * PART 7: AUDITED FINANCIAL STATEMENTS * * * 7.1 Result at a Glance 7.2 Report of the Commissioners 7.3 Statement of Commissioners Responsibilities 7.4 Report of the Independent Auditors 7.5 Statement of Income and Expenditure and other Comprehensive Income 7.6 Statement of Financial Position 7.7 Statements of Changes in Accummulated Funds * * * 7.1. Result at a Glance | RESULTS AT A GLANCE | | --- | | Income generated from operations | | Total expenditure | | Surplus for the year | | Amount payable to Rural Electrification Fund (REF) | | Total comprehensive (loss)/income for the year | | Retained earnings | | Total reserves | | Number of employees(number) | | 2020N'000 | 2019N'000 | % changechange | | --- | --- | --- | | 14,245,028(11,103,784) | 12,518,662(10,416,720) | 4544 | | 4,114,358(3,825,270) | 4,304,965(1,803,267) | (4)112 | | (114,796) | 3,250,470 | (104) | | 2,872,507 | 2,708,319 | 6 | | 18,837,789 | 18,952,584 | (1) | | Number | Number | | | 167 | 169 | (2) | * * * 7.2. Report of the Commissioners NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 REPORT OF THE COMMISSIONERS FOR THE YEAR ENDED 31 DECEMBER 2020 The Commission hereby submit its report together with the audited financial statements of Nigerian Electricity Regulatory Commission (NERC) for the year ended 31 December 2020. The Commission is to ensure that proper accounts and other records relating to its financial statement are kept in respect of all the Commission's activities, funds and property including such particular accounts and records as the Minister may require in line with Section 55(1), Electric Power Sector Reform Act, 2005. STATEMENT OF COMMISSIONERS' RESPONSIBILITIES The Commission is to: - Select suitable accounting policies and then apply them consistently; · Make judgements and estimates that are reasonable and prudent; . Ensure proper accounts and other records relating to such accounts are kept in respect of all Commission's activities, funds and property, including such particular accounts and records as the Minister may require. Prepare the financial statements on the going concern basis unless it is inappropriate to presume that the Commission will continue in operation. The Commissioners confirm that they have complied with the above requirements in preparing the financial statements of the Commission. The Commissioners are responsible for keeping proper books of account which disclose with reasonable accuracy at any time the financial position of the Commission and to ensure that the financial statement are prepared in accordance with the International Financial Accounting Standards (IFRS) and the provisions of the Electric Power Sector Reform Act 2005. The Commissioners are also responsible for safeguarding fraud and other irregularities. REVIEW OF ACTIVITIES AND FUTURE DEVELOPMENTS. The level of activities during the year and the financial position as at 31 December 2020 were satisfactory. The Commission expects that the present level of activities will be sustained for the foreseeable future. The statement of income and expenditure and other comprehensive income, statement of financial position, statement of changes in accumulated funds and statement of cash flows for the year ended 31 December 2020 are as set out on pages 11 to 14. The Commission pursues an equal employment opportunity policy. It does not discriminate against any person on the ground of race, religion, colour, or physical disability. EMPLOYMENT OF PHYSICAL DISABLED PERSONS. The Commission maintains a policy of giving fair consideration to applications from physically disabled persons, bearing in mind their respective aptitudes and abilities. In the event of members of staff becoming disabled, every effort is made to ensure that their employment with the Commission continues and that the appropriate training is arranged. * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 The Commission places great emphasis on the training and development of its staff and other stakeholders and believes that its employees are its greatest assets. Training courses are geared towards the development needs of staff and the improvement in their skill sets to face the increasing challenges in the industry.The commission will continue to invest in its human capital to ensure that employees are well motivated and positioned to compete in the industry. COMMISSIONERS. There was a change in the composition of the board of commissioners during the year. CURRENT COMMISSIONERS. The following Commissioners were appointed by the Federal Government of Nigeria and were in office when this financial statement were presented, approved and signed: | Professor James Momoh | - | | --- | --- | | Sanusi Garba | - | | Musiliu Oseni | - | | Moses Arigu | - | | Dafe Akpeneye | - | | Nathan Rogers Shatti | - | | Frank Okafor | - | | Aisha Mahmud | - | | Chairman/Chief Executive Officer(Retired26November2020) | | --- | | Chairman/Chief Executive Officer(Appointed26November2020) | | Vice Chairman/Commissioner,Market Competition&Rates (Appointed8December2020) | | Commissioner(Commissioner,Planning,ResearchandStrategy) | | Commissioner(Legal,LicensingandCompliance) | | Commissioner(FinanceandManagementServices) | | Commissioner(Engineering,PerformanceandMonitoring) | | Commissioner(ConsumerAffairs)(Appointed8December2020) | TRANSACTIONS INVOLVING COMMISSIONERS. There were no contracts in relation to the business of the Commission in which the Commissioners had any interest at any time during the year ended 31 December 2020. The Auditors, Messrs. Deloitte & Touche (Chartered Accountants) will no longer continue in office having come to the end of their 5-year term. IMPACT OF COVID-19 There were no material adjusting events after the reporting period (31/12/2020) that affected the financial statement of the Commission. However, during the year, there was aa widespread global uncertainty associated with the COVID-19 pandemic. Beyond the tragic health hazards and human consequences of the pandemic, the economic uncertainties, and disruptions that have resulted, the impact of the outbreak of COVID-19 come at a significant cost to the global economy. The restriction imposed on movement during the lockdown from April to June 2020 impacted negatively on the demand for electricity, payment of bills and collections as most companies were closed during the lockdown period. However, the revenue and expenditure of the Commission were not significantly affected as economic activities resumed gradually after the lockdown. At the time of this report, the impact of the new variant of the virus is still being assessed but the commissioners do not anticipate it will significantly affect economic activities of the commission. EVENTS AFTER REPORTING PERIOD Signature y FRC/2017/NBA/00000017445 Dafe Akpeneye Commissioner (Legal, Licencing & Compliance) * * * 7.3. Statement of Commissioners' Responsibilities NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 Statement of Commissioners' Responsibilities for the preparation and approval of the Financial Statements The Commissioners of Nigerian Electricity Regulatory Commission are responsible for the preparation of the financial statements that give a true and fair view of the financial position of the Commission as at 31 December 2020 and the results of its operations, cash flows and changes in accumulated funds for the year then ended, in compliance with the applicable financial reporting framework and in the manner required by the Companies and Allied Matters Act of Nigeria and the Financial Reporting Council of Nigeria Act, 2011. In preparing the financial statements, the Commissioners are responsible for: - properly selecting and applying accounting policies; - presenting information, including accounting policies, in a manner that provides relevant, reliable, comparable and understandable information. - providing additional disclosures when compliance with the specific requirements in IFRSs are insufficient to enable users to understand the impact of particular transactions, other events and conditions on the commission's financial position and financial performance; and - making an assessment of the commission's ability to continue as a going concern. Going concern: The Commissioners have made an assessment of the Commission's ability to continue as a going concern and have no reason to believe the Commission will not remain a going concern in the year ahead. Commissioner (Legal, Licensing and Compliance) FRC/2017/NBA/00000017445 Nathan Rogers Shatti Commissioner (Finance & Management services) FRC/2015/ICAN/00000013331 * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 Certification of financial statements In accordance with section 405 of the Companies and Allied Act of Nigeria, the Chairman and the Commissioner, Finance and Management Services certify that the financial statements have been reviewed and based on our knowledge,the (i) audited financial statements do not contain any untrue statement of material fact or omit to state a material fact, which would make the statements misleading, in the light of the circumstances under which such statement was made,and (ii) audited financial statements and all other financial information included in the statements fairly present, in all material respects,the financial condition and results of operation of the company as of and for,the periods covered by the audited financial statements. We state that management and commissioners: (i) are responsible for establishing and maintaining internal controls and have designed such internal controls to ensure that material information relating to the Commission is made known to the officer by other officers of the Commission, particularly during the period in which the audited financial statement report is being prepared, (ii) have evaluated the effectiveness of the Commission's internal controls within 90 days prior to the date of its audited financial statements, and (iii) certifies that Commission's internal controls are effective as of that date; We have disclosed: (i) all significant deficiencies in the design or operation of internal controls which could adversely affect the Commission's ability to record, process, summarise and report financial data,and has identified for the Commission's auditors any material weaknesses in internal controls,and (ii) whether or not, there is any fraud that involves management or other employees who have a significant role in the Commission's internal control; and (iii) as indicated in the report, whether or not, there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of their evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses. (iv) as indicated in the report, whether or not, there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of their evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses. The financial statements of the Commission for the year ended 31 December 2020 were approved by the Commissioners on 6th April, 2022. Signed on behalf of the Commission FRC/2017/COREN/00000017444 (Legal, Licensing and Compliance) FRC/2017/NBA/00000017445 Nathan Rogers Shatti (Finance & Management services) * * * 7.4. Report of Independent Auditors Deloitte. PO Box 3710 Garki Abuja Nigeria Deloitte & Touche BOI House (4th Floor) Plot 256 Zone A O Off Herbert Macaulay Way Behind Unity Bank Building Central Business District Abuja, Nigeria INDEPENDENT AUDITOR'S REPORT Tel: +234 (9) 278 0200 [www.deloitte.com.ng](http://www.deloitte.com.ng/) TO THE COMMISSIONERS OF NIGERIAN ELECTRICITY REGULATORY COMMISSION Opinion We have audited the financial statements of Nigerian Electricity Regulatory Commission ("the Commission") set out on pages 11 to 47 which comprise the statement of financial position as at 31 December 2020, the statement of income and expenditure and other comprehensive income, statement of changes in accumulated funds and statement of cash flows for the year then ended, the notes to the financial statements including a summary of significant accounting policies. In our opinion, the accompanying financial statements give a true and fair view of the financial position of Nigerian Electricity Regulatory Commission as at 31 December 2020 and the financial performance and cash flows for the year ended in accordance with the International Financial Reporting Standards, the Companies and Allied Matters Act, 2020 and the Financial Reporting Council of Nigeria Act, 2011. Basis for Opinion We conducted our audit in accordance with International Standards on Auditing (ISAs). Our responsibilities under those standards are further described in the Auditor's Responsibilities for the Audit of the Financial Statements section of our report. We are independent of the Commission in accordance with the requirements of the International Ethics Standards Board for Accountants (IESBA), International Code of Ethics for professional (including International Independence Standards) (IESBA Code) and other Independence requirements applicable to performing audits of financial statements in Nigeria. We have fulfilled our other ethical responsibilities in accordance with the IESBA Code and other ethical requirements that are relevant to our audit of financial statements in Nigeria. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion. Key audit matter is the matter that, in our professional judgement, was of most significance in our audit of the financial statements of the current year. This matter was addressed in the context of our audit of the financial statements as a whole, and in forming our opinion thereon, and we do not provide a separate opinion on this matter. The key audit matter below relates to the audit of the financial statements. * * * Deloitte. | Key Audit MatterExpected Credit Loss(ECL) on Trade Receivables | | --- | | IFRS 9- Financial Instruments requires the Commission to recognize Expected Credit Loss(ECL) on its trade receivable balances.This has been discussed further in note 14. | | The commission uses the simplified approach of the expected credit loss model to analyse historical data by risk groups to capture defaults, migration to defaults, collections, etc.for a statistically reasonable number of years. | | Based on the level of judgements involved in estimating the expected credit and the possibility of management bias in estimating the amount,we have considered expected credit loss on trade receivables a key audit matter. | | How the matter was addressed in the audit | | | --- | --- | | In addressing this matter, we adopted a substantive approach to the audit of expected credit losses on trade receivables. | | | The procedures adopted included the following: | | | 1. | Updated our understanding of the procedures put in place by management to identify impaired trade receivables. | | 2. | Tested the ageing of receivables to confirm that all outstanding receivable balances have been accurately aged. | | 3. | Confirmed the appropriateness of the groupings of trade receivables based on the shared credit characteristics for the purpose of determining the loss rate. | | 4. | Reviewed and challenged the judgements made by management in estimating the expected credit loss to identify whether indicators of possible management bias exist. | | 5. | Reviewed and independently confirmed the accuracy of the forecast macro-economic data and other inputs used in the entity's expected credit loss model. | | Based on the procedures performed, we considered the method used and assumptions made by management to be reasonable. | | Other Information The Commissioners are responsible for the other information. The other information comprises the Commissioners' Report and the Statement of Commissioners' responsibilities, which we obtained prior to the date of this Auditor's report. The other information does not include the financial statements and our Auditor's report thereon. Our opinion on the financial statements does not cover the other information and we do not express any form of assurance conclusion thereon. In connection with our audit of the financial statements, our responsibility is to read the other information and, in doing so, consider whether the other information is materially inconsistent with the financial statements or our knowledge obtained in the audit, or otherwise appears to be materially misstated. Responsibilities of the Commissioners for the Financial Statements The Commissioners are responsible for the preparation of financial statements that give a true and fair view in accordance with International Financial Reporting Standards and the requirements of the Companies and Allied Matters Act, Financial Reporting Council Act, 2011 and for such internal control as the Commissioners determine is necessary to enable the preparation of financial statements that are free from material misstatement, whether due to fraud or error. * * * Deloitte. In preparing the financial statements, the Commissioners are responsible for assessing the Commission's ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless the Commissioners either intend to liquidate the Commission or to cease operations, or have no realistic alternative but to do so, ensuring proper accounts and other records relating to such accounts are kept in respect of all Commission's activities funds and property, including such particular accounts and records as the Minister may require. Auditor's Responsibilities for the Audit of Financial Statements Our objectives are to obtain reasonable assurance about whether the financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an Auditor's report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee that an audit conducted in accordance with ISAs will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and are considered material if, individually or in the aggregate, they could reasonably be expected to influence the economic decisions of users taken on the basis of these financial statements. As part of an audit in accordance with ISAs, we exercise professional judgment and maintain professional skepticism throughout the audit. We also: - Identify and assess the risks of material misstatement of the financial statements, whether due to fraud or error, design and perform audit procedures responsive to those risks, and obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control. - Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Commission's internal control. - Evaluate the appropriateness of accounting policies used and the reasonableness of accounting estimates and related disclosures made by the Commissioners. - Conclude on the appropriateness of the Commissioners' use of the going concern basis of accounting and based on the audit evidence obtained, whether a material uncertainty exists relating to events or conditions that may cast significant doubt on the Commission's ability to continue as a going concern. If we conclude that a material uncertainty exists, we are required to draw attention in our auditor's report to the related disclosures in the financial statements or, if such disclosures are inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to the date of our auditor's report. However, future events or conditions may cause the Commission to continue as a going concern. - Evaluate the overall presentation, structure and content whether the Commission's financial statements represent achieves fair presentation. the financial statements, including the disclosures, and the underlying transactions and events in a manner that We also provide the Commissioners with a statement that we have complied with relevant ethical requirements regarding independence, and to communicate with them all relationships and other matters that may reasonably be thought to bear on our independence, and where applicable, related safeguards. * * * Deloitte. Report on Other Legal and Regulatory Requirements In accordance with the fifth schedule of the Companies and Allied Matters Act 2020, we expressly state that: i) We have obtained all the information and explanation which to the best of our knowledge and belief were necessary for the purpose of our audit. ii) The Commission has kept proper books of account, so far as appears from our examination of those books. iii) The Commission's financial position and its statement of income and expenditure and other comprehensive income are in agreement with the books of account and returns. Folorunso Hunga, FCA FRC/2013/ICAN/00000001709 For: Deloitte & Touche Chartered Accountants Abuja, Nigeria 11 April 2022 * * * 7.5. Statement of Income & Expenditure and Other Comprehensive Income NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 | Income generated from operations | | --- | | Other income | | Total income | | Regulatory expenses | | Employee benefits expense | | Administrative expenses | | Total expenditure | | Other gains and losses | | Surplus for the year | | Amount payable to Rural Electrification Fund (REF) | | Net Surplus for the year | | Other comprehensive income | | Items that will not be reclassified subsequently to profit or loss | | Remeasurement of defined benefit obligation | | Other comprehensive income | | Total comprehensive (loss)/income for the year | | Notes | 31-Dec-20N'000 | 31-Dec-19N'000 | | --- | --- | --- | | 5 | 14,245,028 | 12,518,662 | | 6 | 130,889 | 1,086,493 | | | 14,375,917 | 13,605,155 | | 7 | (3,524,992) | (1,180,715) | | 8 | (5,301,770) | (4,922,576) | | 9 | (2,277,022) | (4,313,429) | | | (11,103,784) | (10,416,720) | | 10 | 842,225 | 1,116,530 | | | 4,114,358 | 4,304,965 | | 21.2 | (3,825,270) | (1,803,267) | | | 289,088 | 2,501,698 | | 18 | (403,884) | 748,772 | | | (403,884) | 748,772 | | | (114,796) | 3,250,470 | The accompanying notes on pages 15 to 44 and other national disclosures on pages 46 and 47 form an integral part of these financial statements. * * * 7.6. Statement of Financial Position NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 | STATEMENT OF FINANCIAL POSITION | | | --- | --- | | Assets | | | Non-current assets | | | Property, plant and equipment | | | Intangible asset | | | Retirement benefit | | | Total non-current assets | | | Current assets | | | Receivables | | | Other assets | | | Cash and bank balances | | | Total current assets | | | Total assets | | | Accumulated funds and liabilities | | | Reserves | | | Grant allocation | | | Other reserves | | | Retained earnings | | | Total reserves | | | Non-current liabilities | | | Retirement benefit | | | Total non-current liabilities | | | Current liabilities | | | Trade and other payables | | | Total current liabilities | | | Total liabilities | | | Total accumulated funds and liabilities | | | Notes | 31-Dec-20N'000 | 31-Dec-19N'000 | | --- | --- | --- | | 12 | 13,289,709 | 13,668,522 | | 13 | 4,113 | 11,199 | | 20 | 230,435 | 208,379 | | | 13,524,257 | 13,888,100 | | 14 | 5,390,903 | 2,505,084 | | 15 | 4,704,129 | 3,556,227 | | 16 | 4,307,943 | 1,274,521 | | | 14,402,975 | 7,335,832 | | | 27,927,232 | 21,223,932 | | 17 | 11,850,695 | 11,725,795 | | 18 | 4,114,587 | 4,518,471 | | 19 | 2,872,507 | 2,708,319 | | | 18,837,789 | 18,952,585 | | 20 | - | - | | | - | - | | 21 | 9,089,443 | 2,271,347 | | 9,089,443 | 2,271,347 | | | 9,089,443 | 2,271,347 | | | 27,927,232 | 21,223,932 | | The financial statements on pages 11 to 47 were approved by the board of Commissioners and authorised for issue on Nathan Rogers Shatti Commissioner (Finance and Management services) Chairman FRC/2017/COREN/00000017444 Dafe Akpeneye The accompanying notes on pages 15 to 44 and other national disclosures on pages 46 and 47 form an integral part of these financial statements. Commissioner, Legal, Licensing and Compliance FRC/2017/NBA/00000017445 * * * Audited Financial Statement 7.7. Statement of Changes in Accumulated Funds STATEMENT OF CHANGES IN ACCUMULATED FUNDS NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 | | Federal Government capital grant allocations N'000 | World bank grant allocation N'000 | | --- | --- | --- | | Balance at 1 January 2019 | 10,656,220 | 28,524 | | Surplus for the financial year | - | - | | Net amount appropriated in/(out) of reserves.(See note 19) | 857,401 | - | | Other comprehensive income | - | - | | Balance at 31 December 2019 | 11,513,621 | 28,524 | | Net surplus for the financial year | - | - | | Net amount appropriated in/(out) of reserves.(See note 19). | 49,000 | - | | Other comprehensive loss | - | - | | Balance at 31 December 2020 | 11,562,621 | 28,524 | | MacArthur Foundation grant allocation N'000 | Internally generated revenue capital fund N'000 | Employee benefit reserve N'000 | Retained earnings N'000 | Total N'000 | | --- | --- | --- | --- | --- | | 122,350 | 3,627,152 | 142,547 | 1,125,322 | 15,702,115 | | - | - | - | 2,501,698 | 2,501,698 | | 61,300 | - | - | (918,701) | - | | - | - | 748,772 | - | 748,772 | | 183,650 | 3,627,152 | 891,319 | 2,708,319 | 18,952,585 | | - | - | - | 289,088 | 289,088 | | 75,900 | - | - | (124,900) | - | | - | - | (403,884) | - | (403,884) | | 259,550 | 3,627,152 | 487,435 | 2,872,507 | 18,837,789 | * * * 7.8. Notes of the Financial Statements NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 NOTES TO THE FINANCIAL STATEMENTS 1. General information The Nigerian Electricity Regulatory Commission is an independent body, established by the Electric Power Sector Reform Act of 2005 to undertake technical and economic regulation of the Nigerian Electricity Supply Industry. The Commission is to, among others license operators, determine operating codes and standards, establish customer rights and obligations and set cost reflective industry tariffs. The Commission has its headquarters in Abuja. Being an independent regulator of the Nigerian Electricity Industry, the entity is not for profit business but is meant to be a self-financing regulator. The key stakeholders are the Federal Government (National Assembly and the Office of the President), the public and the other key operators in the market (i.e. generating companies, transmission companies and distribution companies). The address of its registered office and principal place of operations are disclosed in the corporate information page. Composition of financial statements The financial statements comprise: - Statement of income and expenditure and other comprehensive income - Statement of financial position - Statement of changes in accumulated funds - Statement of cash flows - Notes to the financial statement Additional information provided by the management include - Value added statement - 5-year financial summary Basis of preparation and measurement The Financial Statements have been prepared under the historical cost convention except for certain assets that are measured at revalued amounts or fair values as stated in the accounting policies. (For example- Retirement benefit planned asset). Historical cost is generally based on the fair value of the consideration given in exchange for goods and services. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date, regardless of whether that price is directly observable or estimated using another valuation technique. In estimating the fair value of an asset or a liability, the Commission takes into account the characteristics of the asset or liability if market participants would take those characteristics into account when pricing the asset or liability at the measurement date. The accounting policies have been applied consistently unless stated otherwise. These financial statements cover the financial year from 1 January 2020 to 31 December 2020, with comparative figures for the financial year from 1 January 2019 to 31 December 2019. tatement of Compliance These financial statements have been prepared in accordance with International Financial reporting Standards Going concern considerations The Commissioners are of the opinion that the Commission will continue to be in operation in the nearest future without the need or intention on the part of management to liquidate the entity or to significantly curtail its operational activities. * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 NOTES TO THE FINANCIAL STATEMENTS 2 Application of new and revised International Financial Reporting Standards (IFRS) 2.1 Accounting standards and interpretations issued and effective The following revisions to accounting standards and pronouncements were issued and effective during the year. | Pronouncement | Nature of change | Required to be implemented for periods beginning on or after | | --- | --- | --- | | Interest Rate Benchmark Reform (Amendments to IFRS 9, IAS 39 and IFRS 7) | In September 2019,the IASB issued Interest Rate Benchmark Reform(Amendments to IFRS 9,IAS 39 and IFRS 7). These amendments modify specific hedge accounting requirements to allow hedge accounting to continue for affected hedges during the period of uncertainty before the hedged items or hedging instruments affected by the current interest rate benchmarks are amended as a result of the on-going interest rate benchmark reforms. | 1 January 2020 | | Covid-19-Related Rent Concessions (Amendment to IFRS 16) | In May 2020,the IASB issued Covid-19-Related Rent Concessions(Amendment to IFRS 16) that provides practical relief to lessees in accounting for rent concessions occurring as a direct consequence of COVID-19,by introducing a practical expedient to IFRS 16.The practical expedient permits a lessee to elect not to assess whether a COVID-19-related rent concession is a lease modification.A lessee that makes this election shall account for any change in lease payments resulting from the COVID-19-related rent concession the same way it would account for the change applying IFRS 16 if the change were not a lease modification.The practical expedient applies only to rent concessions occurring as a direct consequence of COVID-19 and only if all of the following conditions are met:a)The change in lease payments results in revised consideration for the lease that is substantially the same as,or less than,the consideration for the lease immediately preceding the change;b)Any reduction in lease payments affects only payments originally due on or before 30 June 2021(a rent concession meets this condition if it results in reduced lease payments on or before 30 June 2021 and increased lease payments that extend beyond 30 June 2021);andc)There is no substantive change to other terms and conditions of the lease. | 1 January 2020 | | Amendments to References to the Conceptual Framework in IFRS Standards | The amendments include consequential amendments to affected Standards so that they refer to the new Framework.Not all amendments,however,update those pronouncements with regard to references to and quotes from the Framework so that they refer to the revised Conceptual Framework.Some pronouncements are only updated to indicate which version of the Framework they are referencing to(the IASC Framework adopted by the IASB in 2001,the IASB Framework of 2010,或the new revised Framework of2018)or to indicate that definitions in the Standard have not been updated with the new definitions developed in the revised Conceptual Framework.The Standards which are amended are IFRS 2,IFRS 3,IFRS 6,IFRS 14,IAS 1,IAS 8,IAS 34,IAS 37,IAS 38,IFRC 12,IFRC 19,IFRC 20,IFRC 22,and SIC-32. | 1 January 2020 | * * * NOTES TO THE FINANCIAL STATEMENTS NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 2.1 Accounting standards and interpretations issued and effective (continued) | Pronouncement | Nature of change | Required to be implemented for periods beginning on or after | | --- | --- | --- | | Definition of a Business (Amendments to IFRS 3) | The amendment is aimed at resolving the difficulties that arise when an entity determines whether it has acquired a business or a group of assets.The amendments in Definition of a Business(Amendments to IFRS 3) are changes to Appendix A Defined terms,the application guidance,and the illustrative examples of IFRS 3 only.They:>clarify that to be considered a business,an acquired set of activities and assets must include,at a minimum,an input and a substantive process that together significantly contribute to the ability to create outputs;>narrow the definitions of a business and of outputs by focusing on goods and services provided to customers and by removing the reference to an ability to reduce costs;>add guidance and illustrative examples to help entities assess whether a substantive process has been acquired;>remove the assessment of whether market participants are capable of replacing any missing inputs or processes and continuing to produce outputs;and add>an optional concentration test that permits a simplified assessment of whether an acquired set of activities and assets is not a business. | 1 January 2020 | | Amendments to IAS 1 and IAS 8 Definition of material | The amendments make the definition of material in IAS 1 easier to understand and are not intended to alter the underlying concept of materiality in IFRS Standards.The concept of‘obscuring’material information with immaterial information has been included as part of the new definition.The threshold for materiality influencing users has been changed from‘could influence’to‘could reasonably be expected to influence’.The definition of material in IAS 8 has been replaced by a reference to the definition of material in IAS 1.In addition,the IASB amended other Standards and the Conceptual Framework that contain a definition of‘material’or refer to the term‘material’to ensure consistency. | 1 January 2020 | The commissioners have determined that the application of these standards has had no material impact on the disclosures or the amounts recognised in the Company's financial statement. * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 NOTES TO THE FINANCIAL STATEMENTS 2.2 Accounting standards and interpretations issued but The following revisions to accounting standards and period. bot yet effective announcements were issued but not effective at the reporting | Pronouncement | Nature of change | Required to be implemented for periods beginning on or after | | --- | --- | --- | | IFRS 17 Insurance Contracts | “IFRS 17 establishes the principles for the recognition, measurement, presentation and disclosure of insurance contracts and supersedes IFRS 4 Insurance Contracts. IFRS 17 outlines a general model, which is modified for insurance contracts with direct participation features, described as the variable fee approach. The general model is simplified if certain criteria are met by measuring the liability for remaining coverage using the premium allocation approach. The general model uses current assumptions to estimate the amount, timing and uncertainty of future cash flows and it explicitly measures the cost of that uncertainty. It takes into account market interest rates and the impact of policy holders' options and guarantees. In June 2020, the IASB issued Amendments to IFRS 17 to address concerns and implementation challenges that were identified after IFRS 17 was published. The amendments defer the date of initial application of IFRS 17 (incorporating the amendments) to annual reporting periods beginning on or after 1 January 2023. At the same time, the IASB issued Extension of the Temporary Exemption from Applying IFRS 9 (Amendments to IFRS 4) that extends the fixed expiry date of the temporary exemption from applying IFRS 9 in IFRS 4 to annual reporting periods beginning on or after 1 January 2023. IFRS 17 must be applied retrospectively unless impracticable, in which case the modified retrospective approach or the fair value approach is applied. For the purpose of the transition requirements, the date of initial application is the start if the annual reporting period in which the entity first applies the Standard, and the transition date is the beginning of the period immediately preceding the date of initial application. | 1 January 2023 | | Amenments to IFRS 10 and IAS 28-Sale or Contribution of Assets between an Investor and its Associate or Joint Venture | 1 January 2023 | | * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 2.2 Accounting standards and interpretations issued but not yet effective (continued) | Pronouncement | Nature of change | Required to be implemented for periods beginning on or after | | --- | --- | --- | | Ammendments to IAS 1-Classification of Liabilities as Current or Non-current | The amendments to IAS 1 affect only the presentation of liabilities as current or non-current in the statement of financial position and not the amount or timing of recognition of any asset, liability, income or expenses, or the information disclosed about those items.The amendments clarify that the classification of liabilities as current or non-current is based on rights that are in existence at the end of the reporting period, specify that classification is unaffected by expectations about whether an entity will exercise its right to defer settlement of a liability, explain that rights are in existence if covenants are complied with at the end of the reporting period,and introduce a definition ofsettlementto make clear that settlement refers to the transfer to the counterparty of cash,equity instruments,other assets or services.The amendments are applied retrospectively for annual periods beginning on or after1 January2023,with early application permitted. | 1 January2023 | | Ammendments to IFRS 9-Reference to the Conceptual Framework | The amendments update IFRS 3 so that it refers to the 2018 Conceptual Framework instead of the 1989 Framework.They also add to IFRS 3 a requirement that,for obligations within the scope of IAS 37,an acquirer applies IAS 37 to determine whether at the acquisition date a present obligation exists as a result of past events.For a levy that would be within the scope of IFRC 21 Levies,the acquirer applies IFRIC 21 to determine whether the obligating event that gives rise to a liability to pay the levy has occurred by the acquisition date.Finally,the amendments add an explicit statement that an acquirer does not recognise contingent assets acquired in a business combination.The amendments are effective for business combinations for which the date of acquisition is on or after the beginning of the first annual period beginning on or after1 January2022.Early application is permitted if an entity also applies all other updated references (published together with the updated Conceptual Framework)at the same time or earlier. | 1 January2022 | | Ammendments to IAS 16-Property,Plant and Equipment-Proceeds before Intended Use | The amendments prohibit deducting from the cost of an item of property,plant and equipment any proceeds from selling items produced before that asset is available for use,i.e.proceeds while bringing the asset to the location and condition necessary for it to be capable of operating in the manner intended by management.Consequently,an entity recognizes such sales proceeds and related costs in profit or loss.The entity measures the cost of those items in accordance with IAS 2 Inventories.The amendments also clarify the meaning of testing whether an asset is functioning properly'.IAS 16 now specifies this as assessing whether the technical and physical performance of the asset is such that it is capable of being used in the production or supply of goods or services,for rental to others,or for administrative purposes.If not presented separately in the statement of comprehensive income,the financial statements shall disclose the amounts of proceeds and cost included in profit or loss that relate to items produced that are not an output of the entity's ordinary activities,and which line item(s)在the statement of comprehensive income include(s)such proceeds and cost.The amendments are applied retrospectively,but only to items of property,plant and equipment that are brought to the location and condition necessary for them to be capable of operating in the manner intended by management on or after the beginning of the earliest period presented in the financial statements in which the entity first applies the amendments.The entity shall recognise the cumulative effect of initially applying the amendments as an adjustment to the opening balance of retained earnings(or other component of equity,as appropriate)at the beginning of that earliest period presented.The amendments are effective for annual periods beginning on or after1 January2022,with early application permitted. | 1 January2023 | * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 NOTES TO THE FINANCIAL STATEMENTS 2.2 Accounting standards and interpretations issued but not yet effective (continued) | Pronouncement | Nature of change | Required to be implemented for periods beginning on or after | | --- | --- | --- | | Amendments to IAS 37-Onerous Contracts-Cost of Fulfilling a Contract | The amendments specify that the‘cost of fulfilling’a contract comprises the‘costs that relate directly to the contract’.Costs that relate directly to a contract consist of both the incremental costs of fulfilling that contract(examples would be direct labour or materials) and an allocation of other costs that relate directly to fulfilling contracts(an example would be the allocation of the depreciation charge for an item of property, plant and equipment used in fulfilling the contract).The amendments apply to contracts for which the entity has not yet fulfilled all its obligations at the beginning of the annual reporting period in which the entity first applies the amendments.Comparatives are not restated.Instead,the entity shall recognise the cumulative effect of initially applying the amendments as an adjustment to the opening balance of retained earnings or other component of equity,as appropriate,at the date of initial application.The amendments are effective for annual periods beginning on or after1January2022,with early application permitted. | 1 January2022 | | Annual Improvements to IFRS Standards2018-2020 | The Annual Improvements include amendments to four Standards.IFRS1First-time Adoption of International Financial Reporting Standards.The amendment provides additional relief to a subsidiarywhich becomes a first-time adopter later than its parent in respect of accounting for cumulative translation differences.As a result of the amendment,a subsidiarythat uses the exemptionin IFRS1.D16(a)can now also elect to measure cumulative translation differences for all foreign operations at the carrying amount that would be included in the parent's consolidated financial statements,based on the parent's date of transition to IFRS Standards,if no adjustments were made for consolidation procedures and for the effects of the business combination in which the parent acquired the subsidiary.A similar election is available to an associate or joint venture that uses the exemptionin IFRS1.D16(a).The amendment is effective for annual periods beginning on or after1January2022,with early application permitted. | 1 January2022 | | IFRS9Financial Instruments | The amendment clarifies that in applying the‘10 per cent’test to assess whether to derecognise a financial liability,an entity includes only fees paid or received between the entity(borrower)和the lender,including fees paid or received by either the entity or the lender on the other's behalf.The amendment is applied prospectively to modifications and exchanges that occur on or after the date the entityfirst applies the amendment.The amendment is effective for annual periodsbeginning on or after1January2022,with early application permitted. | 1 January2022 | | IAS41Agriculture | The amendment removes the requirement in IAS41for entities to exclude cashflows for taxation when measuring fair value.This aligns the fair value measurement in IAS41with the requirements ofIFRS13Fair ValueMeasurementto use internally consistent cash flows and discount rates and enables preparers to determine whether to use pretax or post-tax cashflowsand discount rates for the most appropriate fair value measurement.The amendment is applied prospectively,i.e.for fair value measurements onorafter the date an entity initially applies the amendment.The amendment is effective for annual periods beginning on or after1January2022,with earlyapplication permitted. | 1 January2022 | * * * 7.9. Other National Disclosures 7.9.1. Statement of Value Added NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 STATEMENT OF VALUE ADDED | Income generated from operations | | --- | | Other income | | Bought in materials and services | | Foreign | | Local | | APPLIED AS FOLLOWS: | | To pay employees: | | Salaries, wages, pension and social benefits | | To the government: | | Surplus to Rural Electrification Fund (REF) | | Retained in the business | | Depreciation | | Amortization | | Surplus for the year | | 2020N'000 | % | 2019N'000 | % | | --- | --- | --- | --- | | 14,245,028 | | 12,518,662 | | | 130,889 | | 1,086,493 | | | 14,375,917 | | 13,605,155 | | | (4,262,760) | | (455,651) | | | 10,113,157 | 100 | 9,812,658 | 100 | | 5,301,770 | 52 | 4,922,576 | 50 | | 3,825,270 | 38 | 1,803,267 | 18 | | 689,943 | 7 | 577,345 | 6 | | 7,086 | - | 7,772 | - | | 289,088 | 3 | 2,501,698 | 26 | | 10,113,157 | 100 | 9,812,658 | 100 | "Value added" represents the additional wealth, which the Commission has been able to create by its own, and its employees' efforts. This statement shows the creation of that wealth amongst employees, capital providers, government, and that retained for future creation of wealth. * * * 7.9.2. Financial Summary NIGERIAN ELECTRICITY REGULATORY COMMISSION Annual Report and Financial Statements - 31 December 2020 FINANCIAL SUMMARY | 31 DECEMBER | 2020N'000 | | --- | --- | | Statement of Financial Position | | | Assets/Liabilities | | | Non-current asset | 13,524,257 | | Current assets | 14,402,975 | | Total assets | 27,927,232 | | Accumulated Funds and liabilitiesLiabilities | | | Current liabilities | 9,089,443 | | Non-current liabilities | - | | Total liabilities | 9,089,443 | | RESERVES | | | Grant allocation | 11,850,695 | | Other reserves | 4,114,587 | | Retained earnings | 2,872,507 | | Total reserves | 18,837,789 | | Total accumulated funds and liabilities | 27,927,232 | | Statement of activities | | | Income | 15,218,142 | | Expenditure | (11,103,784) | | | 4,114,358 | | 2019N'000 | 2018N'000 | 2017N'000 | Restated2016N'000 | | --- | --- | --- | --- | | 13,888,1007,335,83221,223,932 | 13,131,2684,488,34417,619,612 | 12,921,5705,195,67218,117,242 | 13,064,6123,492,42216,557,034 | | 2,271,347-2,271,347 | 1,652,918264,5791,917,497 | 2,069,20233,7272,102,929 | 1,993,0751,993,075 | | 11,725,7954,518,4712,780,319 | 10,684,7443,769,6991,247,672 | 10,374,7853,540,8502,098,678 | 9,429,0353,777,4231,357,501 | | 18,952,585 | 15,702,115 | 16,014,313 | 14,563,959 | | 21,223,932 | 17,619,612 | 18,117,242 | 16,557,034 | | 14,721,685(10,416,720) | 6,285,339(6,826,386) | 6,778,382(5,061,731) | 8,927,110(8,798,480) | | 4,304,965 | (541,047) | 1,716,651 | 128,630 | * * * NIGERIAN ELECTRICIT REGULATORY COMMISSION APPENDIX: KEY STATISTICS * * * A Electricity Generation B Grid Performance C Commercial Performane D Licence, Permit and Certification E Consumer Enlightenment, Metering and Complaints * * * A. Electricity Generation Table A.1: Daily Available Capacity, Plant Units & Units on Bars, 2017-20 | Period | Installed Available Capacity(MW) | | | | | --- | --- | --- | --- | --- | | 2020 | 2019 | 2018 | 2017 | | | January | 5,663 | 5,597 | 7,457 | 6,006 | | February | 5,755 | 6,553 | 7,515 | 6,301 | | March | 5,275 | 6,158 | 7,475 | 6,866 | | April | 6,315 | 6,094 | 7,250 | 6,763 | | May | 6,421 | 5,949 | 8,034 | 7,107 | | June | 6,341 | 6,162 | 7,679 | 6,977 | | July | 6,301 | 6,617 | 7,914 | 7,140 | | August | 6,673 | 6,862 | 8,206 | 6,961 | | September | 6,048 | 6,647 | 7,804 | 6,953 | | October | 6,710 | 6,697 | 7,741 | 7,369 | | November | 5,893 | 6,486 | 7,387 | 7,011 | | December | 5,888 | 5,532 | 5,687 | 7,373 | | Average Annual | 6,107 | 6,280 | 7,513 | 6,907 | | | Number of Available Plant Units | | | | Number of Plant Units on Bars | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2020 | 2019 | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | | 65 | 58 | 78 | 66 | 56 | 53 | 51 | 38 | | | 68 | 63 | 78 | 68 | 64 | 55 | 56 | 47 | | | 65 | 62 | 79 | 72 | 62 | 57 | 56 | 49 | | | 73 | 61 | 79 | 72 | 63 | 53 | 55 | 45 | | | 73 | 62 | 81 | 75 | 66 | 53 | 49 | 49 | | | 73 | 63 | 78 | 74 | 61 | 53 | 48 | 48 | | | 74 | 67 | 81 | 77 | 61 | 54 | 52 | 50 | | | 77 | 68 | 82 | 74 | 64 | 55 | 50 | 50 | | | 71 | 64 | 80 | 76 | 61 | 49 | 48 | 52 | | | 77 | 66 | 80 | 78 | 65 | 48 | 50 | 55 | | | 68 | 68 | 77 | 76 | 66 | 51 | 54 | 56 | | | 68 | 56 | 59 | 78 | 67 | 49 | 56 | 56 | | | 71 | 63 | 78 | 74 | 63 | 52 | 52 | 49 | | Table A.2: Ave. Daily Transmission Capacity, Energy Generated & Sent-Out | | Transmission Capacity(MW) | | | | | | --- | --- | --- | --- | --- | --- | | Period | 2020 | 2019 | 2018 | 2017 | 2020 | | January | 4,800 | 4,800 | 4,800 | 4,800 | 3,817 | | February | 4,800 | 4,800 | 4,800 | 4,800 | 4,114 | | March | 4,800 | 4,800 | 4,800 | 4,800 | 3,912 | | April | 4,800 | 4,879 | 4,800 | 4,800 | 4,099 | | May | 4,800 | 4,848 | 4,800 | 4,800 | 4,168 | | June | 4,800 | 4,818 | 4,800 | 4,800 | 3,726 | | July | 4,800 | 4,917 | 4,800 | 4,800 | 3,821 | | August | 4,800 | 4,886 | 4,800 | 4,800 | 4,045 | | September | 4,800 | 4,856 | 4,800 | 4,800 | 3,863 | | October | 4,800 | 4,825 | 4,800 | 4,800 | 4,155 | | November | 4,800 | 4,828 | 4,800 | 4,800 | 4,424 | | December | 4,800 | 4,713 | 4,800 | 4,800 | 4,504 | | Ave. Annual | 4,800 | 4,831 | 4,800 | 4,800 | 4,054 | | Energy Generated (MW) | | | | Energy Sent Out (MW) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2019 | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | | 4,003 | 3,744 | 3,006 | 3,732 | 3,952 | 3,690 | 2,952 | | | 4,209 | 4,005 | 3,741 | 4,008 | 4,148 | 3,941 | 3,683 | | | 4,228 | 4,079 | 3,832 | 3,858 | 4,167 | 4,011 | 3,771 | | | 4,068 | 3,999 | 3,574 | 4,031 | 4,008 | 3,933 | 3,521 | | | 3,831 | 3,827 | 3,643 | 4,100 | 3,774 | 3,765 | 3,587 | | | 3,711 | 3,643 | 3,525 | 3,660 | 3,648 | 3,588 | 3,462 | | | 3,737 | 3,674 | 3,405 | 3,757 | 3,676 | 3,608 | 3,350 | | | 3,584 | 3,727 | 3,397 | 3,981 | 3,526 | 3,660 | 3,340 | | | 3,524 | 3,571 | 3,484 | 3,806 | 3,474 | 3,514 | 3,433 | | | 3,463 | 3,821 | 3,770 | 4,088 | 3,411 | 3,763 | 3,719 | | | 3,804 | 4,100 | 3,921 | 4,358 | 3,751 | 4,040 | 3,861 | | | 3,744 | 4,149 | 4,137 | 4,432 | 3,688 | 4,093 | 4,065 | | | 3,826 | 3,861 | 3,618 | 3,984 | 3,768 | 3,800 | 3,561 | | * * * Table A.3: Daily Stranded Capacity by Type of Constraints, 2016-18 | Period | Gas Constraint (MW) | | | Distrib | | --- | --- | --- | --- | --- | | 2018 | 2017 | 2016 | 2018 | | | January | 1948.3 | 2,061.8 | 1,750.5 | 425.3 | | February | 1640.2 | 1,491.1 | 1,752.0 | 743.6 | | March | 2138.8 | 2,111.7 | 2,276.1 | 191.7 | | April | 1476.7 | 2,257.9 | 2,915.4 | 698.5 | | May | 2076.0 | 2,053.5 | 3,555.5 | 989.0 | | June | 1972.5 | 1,662.1 | 3,992.8 | 637.3 | | July | 1755.9 | 893.5 | 4,126.7 | 1263.2 | | August | 2010.1 | 515.1 | 3,606.6 | 1842.0 | | September | 1196.4 | 608.3 | 2,910.6 | 2368.6 | | October | 1132.4 | 465.5 | 3,076.5 | 2333.2 | | November | 1467.1 | 842.6 | 3,462.5 | 1128.4 | | December | 85.7 | 313.7 | 3,339.2 | 442.7 | | Ave. Annual | 1575.0 | 1,270.5 | 3,068.1 | 1090.2 | | Limited Solution Network (MW) | | Transmission Line Limitation (MW) | | | Water Management (MW) | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2017 | 2016 | 2018 | 2017 | 2016 | 2018 | 2017 | 2016 | | 18.7 | 9.5 | 99.5 | 0.0 | 196.0 | 239.4 | 121.9 | 82.9 | | 75.9 | 13.6 | 91.8 | 26.4 | 207.9 | 145.0 | 139.3 | 17.6 | | 211.5 | 130.9 | 60.6 | 12.5 | 340.4 | 0.0 | 67.7 | 5.5 | | 91.0 | 25.1 | 90.4 | 57.9 | 269.9 | 158.3 | 38.3 | 300.2 | | 204.7 | 4.5 | 124.6 | 221.0 | 334.3 | 98.1 | 212.6 | 491.7 | | 666.2 | 14.5 | 140.9 | 174.8 | 266.2 | 226.8 | 0.0 | 232.8 | | 1,567.4 | 11.1 | 76.5 | 75.8 | 288.5 | 220.6 | 0.0 | 0.0 | | 2,137.5 | 237.5 | 51.9 | 25.5 | 300.2 | 0.0 | 0.0 | 90.2 | | 1,947.5 | 318.7 | 49.0 | 0.0 | 454.8 | 0.0 | 0.0 | 4.1 | | 1,620.0 | 194.7 | 47.9 | 2.3 | 336.3 | 0.0 | 0.0 | 0.0 | | 853.2 | 92.6 | 55.3 | 144.1 | 131.5 | 41.5 | 140.0 | 0.0 | | 669.4 | 66.9 | 5.1 | 24.1 | 1.3 | 72.9 | 87.1 | 65.2 | | 844.3 | 93.5 | 74.2 | 63.7 | 260.7 | 99.8 | 66.9 | 107.7 | | GENCOs | Availability F | | | | --- | --- | --- | --- | | 2020 | 2019 | 2018 | | | AES Barge IPP | 0.00 | 0.00 | 0.00 | | Afam IV-V | 60.23 | 60.23 | 46.64 | | Afam VI IPP | 73.38 | 73.38 | 79.64 | | Alaoji NIPP | 52.08 | 52.08 | 65.27 | | ASCO IPP | 0.00 | 0.00 | 0.00 | | Azura Edo IPP | 99.18 | 99.18 | 68.07 | | Delta | 88.28 | 88.28 | 94.01 | | Egbin | 80.56 | 80.56 | 90.04 | | Gbarain NIPP | 59.45 | 59.45 | 71.35 | | Geregu | 90.79 | 90.79 | 70.78 | | Geregu NIPP | 77.41 | 77.41 | 55.22 | | Ibom Power IPP | 51.40 | 51.40 | 66.72 | | Ihovbor NIPP | 53.49 | 53.49 | 76.45 | | Jebba | 74.95 | 74.95 | 86.24 | | Kainji | 54.59 | 54.59 | 76.23 | | Odukpani NIPP | 98.95 | 98.95 | 100.00 | | Okpai IPP | 97.17 | 97.17 | 97.94 | | Olorunsogo | 100.00 | 100.00 | 100.00 | | Olorunsogo NIPP | 29.29 | 29.29 | 63.77 | | Omoku IPP | 43.97 | 43.97 | 74.45 | | Omotosho | 100.00 | 100.00 | 100.00 | | Omotosho NIPP | 63.25 | 63.25 | 83.42 | | Paras Energy IPP | 99.45 | 99.45 | 98.66 | | Rivers IPP | 88.89 | 88.89 | 70.57 | | Sapele | 23.33 | 23.33 | 72.08 | | Sapele NIPP | 49.44 | 49.44 | 82.04 | | Shiroro | 79.46 | 79.46 | 82.50 | | Trans-Amadi IPP | 68.33 | 68.33 | 75.37 | | All GenCos | 66.33 | 66.33 | 73.12 | | Factor (%) | Load Factor (%) | | | | | | --- | --- | --- | --- | --- | --- | | 2017 | 2020 | 2019 | 2018 | 2017 | | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | | | 15.15 | 62.84 | 44.13 | 55.62 | 48.42 | | | 67.58 | 68.79 | 38.13 | 35.24 | 50.1 | | | 75.00 | 40.06 | 37.26 | 11.20 | 36.7 | | | 27.40 | 0.00 | 0.00 | 0.00 | 43.10 | | | 0.00 | 79.74 | 57.47 | 57.31 | 0.00 | | | 87.29 | 67.77 | 68.60 | 75.74 | 54.8 | | | 69.29 | 65.36 | 56.06 | 73.45 | NA | | | 47.67 | 42.91 | 44.54 | 47.47 | 58.46 | | | 73.68 | 64.04 | 57.50 | 45.75 | 53.83 | | | 32.61 | 64.84 | 63.74 | 26.09 | 46.25 | | | 70.90 | 55.02 | 62.20 | 65.43 | 44.97 | | | 73.03 | 36.79 | 66.36 | 37.31 | 46.45 | | | 74.83 | 78.73 | 75.04 | 67.10 | 56.03 | | | 54.67 | 83.60 | 81.60 | 74.65 | 60.14 | | | 100.00 | 61.62 | 47.49 | 35.58 | 46.42 | | | 95.18 | 59.02 | 58.06 | 62.43 | 60.71 | | | 100.00 | 61.87 | 57.90 | 41.47 | 49.13 | | | 55.80 | 60.54 | 66.43 | 19.16 | 35.60 | | | 57.50 | 55.60 | 71.39 | 67.47 | 47.51 | | | 100.00 | 65.69 | 67.61 | 40.02 | 46.68 | | | 84.33 | 60.50 | 69.05 | 32.55 | 51.05 | | | 13.97 | 73.87 | 83.51 | 92.01 | 64.18 | | | 80.00 | 72.92 | 67.77 | 52.67 | 51.24 | | | 43.89 | 55.98 | 38.12 | 35.12 | 54.62 | | | 50.00 | 33.71 | 72.23 | 53.55 | 56.21 | | | 67.63 | 67.59 | 59.62 | 63.77 | 54.39 | | | 60.00 | 65.98 | 65.91 | 47.67 | 54.47 | | | 59.91 | 61.74 | 60.26 | 51.32 | 50.81 | | * * * Table A.5: Annual Electricity Output and Share by Fuel Type, 2017-2020 | Period | Fuel Type | Total Electricity(MV) | | | --- | --- | --- | --- | | 2020 | 2019 | | | | Q1 | Thermal | 6,327,403.79 | 7,449,255.20 | | Hydro | 2,286,594.00 | 1,604,635.45 | | | Q2 | Aggregate | 8,613,997.79 | 9,053,890.65 | | Thermal | 7,121,437.04 | 7,128,993.83 | | | Hydro | 1,613,490.00 | 1,322,433.90 | | | Q3 | Aggregate | 8,734,927.04 | 8,451,427.73 | | Thermal | 6,318,883.46 | 6,608,096.62 | | | Hydro | 1,946,535.00 | 1,376,588.17 | | | Q4 | Aggregate | 8,265,418.46 | 7,984,684.79 | | Thermal | 7,248,672.72 | 6,239,039.30 | | | Hydro | 2,379,530.80 | 1,862,153.42 | | | Annual | Aggregate | 9,628,203.52 | 8,101,192.72 | | Thermal | 27,016,397.01 | 27,425,384.95 | | | Hydro | 8,213,819.00 | 6,165,810.94 | | | Aggregate | 35,230,216.01 | 33,591,195.89 | | | City Output (%) | | Fuel Share of Electricity Output(%) | | | | | | --- | --- | --- | --- | --- | --- | --- | | | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | 6,879,599.70 | 6,743,998.69 | 73.45 | 82.28 | 77.47 | 77.47 | | | 1,631,881.00 | 1,961,607.00 | 26.55 | 17.72 | 22.53 | 22.53 | | | 8,511,480.70 | 8,705,605.69 | 100.00 | 100.00 | 100.00 | 100.00 | | | 6,806,324.08 | 5,433,026.07 | 81.53 | 84.35 | 71.78 | 71.78 | | | 1,543,850.00 | 2,135,465.80 | 18.47 | 15.65 | 28.22 | 28.22 | | | 8,350,174.08 | 7,568,491.87 | 100.00 | 100.00 | 100.00 | 100.00 | | | 6,097,910.59 | 6,244,816.82 | 76.45 | 82.76 | 79.84 | 79.84 | | | 1,979,572.00 | 1,576,365.00 | 23.55 | 17.24 | 20.16 | 20.16 | | | 8,077,482.59 | 7,821,181.82 | 100.00 | 100.00 | 100.00 | 100.00 | | | 6,251,827.63 | 5,528,017.19 | 75.29 | 77.01 | 72.72 | 72.72 | | | 2,536,433.00 | 2,073,322.00 | 24.71 | 22.99 | 27.28 | 27.28 | | | 8,788,260.63 | 7,601,339.19 | 100.00 | 100.00 | 100.00 | 100.00 | | | 26,035,662.00 | 23,949,858.8 | 76.69 | 81.64 | 75.56 | 75.56 | | | 7,691,736.00 | 7,746,759.8 | 23.31 | 18.36 | 24.44 | 24.44 | | | 33,727,398.00 | 31,696,618.6 | 100.00 | 100.00 | 100.00 | 100.00 | | Table A.6: Plant Share of Total Electricity Output, 2017-2020 | GENCOs | Electricity Our (MW) | | | --- | --- | --- | | 2020 | 2019 | | | AES Barge IPP | 0.00 | 0.00 | | Afam IV-V | 0.00 | 288628.59 | | Afam VI IPP | 83410.00 | 1460615.12 | | Alaoji NIPP | 130427.45 | 208902.11 | | ASCO IPP | 185750.40 | 0.00 | | Azura Edo IPP | 250096.09 | 2269720.09 | | Delta | 306094.32 | 2756916.61 | | Egbin | 326471.73 | 3795468.60 | | Gbarain NIPP | 453119.81 | 265123.15 | | Geregu | 481933.21 | 1905798.30 | | Geregu NIPP | 492858.56 | 1209916.09 | | Ibom Power IPP | 539307.26 | 490624.22 | | Ihovbor NIPP | 628273.44 | 699618.51 | | Jebba | 652285.57 | 2865322.00 | | Kainji | 814569.00 | 2971924.50 | | Odukpani NIPP | 834167.24 | 1951380.93 | | Okpai IPP | 1054817.71 | 1357827.30 | | Olorunsogo | 1128712.29 | 1392731.76 | | Olorunsogo NIPP | 1571297.00 | 215158.90 | | Omoku IPP | 2028424.11 | 505714.99 | | Omotosho | 2240288.85 | 1036133.03 | | Omotosho NIPP | 2463926.11 | 806313.50 | | Paras Energy IPP | 2579190.00 | 483269.96 | | Rivers IPP | 2663931.01 | 829886.05 | | Sapele | 2705708.00 | 289330.70 | | Sapele NIPP | 2915109.15 | 590093.95 | | Shiroro | 2928921.00 | 2616212.50 | | Trans-Amadi IPP | 4771126.70 | 328564.44 | | ALL GENCOs | 35230216.01 | 33591195.89 | | Output by Plant (%) | | Electricity Output by Plant(%) | | | | | | --- | --- | --- | --- | --- | --- | --- | | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | | 312815.85 | 90518.00 | 1.29 | 0.86 | 0.93 | 0.29 | | | 1809726.24 | 2262878.34 | 6.36 | 4.35 | 5.37 | 7.14 | | | 270113.79 | 479049.29 | 1.53 | 0.62 | 0.80 | 1.51 | | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | | | 1561281.44 | 0.00 | 8.27 | 6.76 | 4.63 | 0.00 | | | 3938311.85 | 3045025.26 | 7.56 | 8.21 | 11.68 | 9.61 | | | 4321424.50 | 3504415.00 | 13.54 | 11.30 | 12.81 | 11.06 | | | 376400.94 | 344839.33 | 0.24 | 0.79 | 1.12 | 1.09 | | | 1587954.16 | 1677515.22 | 5.76 | 5.67 | 4.71 | 5.29 | | | 715548.05 | 875606.96 | 2.31 | 3.60 | 2.12 | 2.76 | | | 543565.88 | 490883.17 | 0.93 | 1.46 | 1.61 | 1.55 | | | 838695.27 | 869628.75 | 0.53 | 2.08 | 2.49 | 2.74 | | | 2609493.00 | 2808216.80 | 7.68 | 8.53 | 7.74 | 8.86 | | | 2652046.00 | 2701736.00 | 8.31 | 8.85 | 7.86 | 8.52 | | | 735007.05 | 1443152.15 | 6.99 | 5.81 | 2.18 | 4.55 | | | 1881600.71 | 2349953.50 | 4.46 | 4.04 | 5.58 | 7.41 | | | 1160460.44 | 1180600.08 | 3.20 | 4.15 | 3.44 | 3.72 | | | 548439.87 | 669798.10 | 0.37 | 0.64 | 1.63 | 2.11 | | | 495269.27 | 550164.85 | 1.78 | 1.51 | 1.47 | 1.74 | | | 1112907.00 | 1153332.90 | 2.99 | 3.08 | 3.30 | 3.64 | | | 980051.59 | 969670.11 | 1.85 | 2.40 | 2.91 | 3.06 | | | 562664.64 | 521375.20 | 1.37 | 1.44 | 1.67 | 1.64 | | | 629021.38 | 30782.90 | 2.37 | 2.47 | 1.87 | 0.10 | | | 251314.50 | 321116.80 | 0.87 | 0.86 | 0.75 | 1.01 | | | 1154780.16 | 974803.12 | 0.71 | 1.76 | 3.42 | 3.08 | | * * * Key Statistics B. Grid Performance Table B.1: Monthly Transmission Loss Factor in 2018-2020 | Month/Year | Energy Injected into Grid (GWh) | | | Energy to Dis | | --- | --- | --- | --- | --- | | 2020 | 2019 | 2018 | 2020 | | | January | 2,813 | 2,937 | 2,750 | 2,603 | | February | 2,826 | 2,776 | 2,658 | 2,593 | | March | 2,863 | 3,087 | 3,008 | 2,665 | | April | 2,900 | 2,798 | 2,884 | 2,730 | | May | 3,062 | 2,636 | 2,783 | 2,820 | | June | 2,640 | 2,737 | 2,562 | 2,441 | | July | 2,810 | 2,737 | 2,689 | 2,601 | | August | 2,967 | 2,640 | 2,720 | 2,741 | | September | 2,743 | 2,513 | 2,533 | 2,535 | | October | 3,067 | 2,514 | 2,783 | 2,843 | | November | 3,118 | 2,647 | 2,904 | 2,903 | | December | 3,295 | 2,769 | 3,052 | 3,053 | | Monthly Ave. | 2,925 | 2,733 | 2,777 | 2,711 | | Total Annual | 35,104 | 32,791 | 33,325 | 32,527 | | Energy Delivered Cos & Exported (GWh) | | Transmission Losses Factor(%) | | | MYTO Assumption(%) | | --- | --- | --- | --- | --- | --- | | 2019 | 2018 | 2020 | 2019 | 2018 | 2018-2020 | | 2701 | 2,506 | 7.48% | 8.02% | 8.87% | 8.05% | | 2560 | 2,456 | 8.23% | 7.77% | 7.58% | 8.05% | | 2874 | 2,708 | 6.91% | 6.89% | 9.98% | 8.05% | | 2576 | 2,609 | 5.87% | 7.93% | 9.52% | 8.05% | | 2426 | 2,538 | 7.93% | 7.95% | 8.80% | 8.05% | | 2519 | 2,356 | 7.55% | 7.96% | 8.07% | 8.05% | | 2519 | 2,470 | 7.45% | 7.96% | 8.13% | 8.05% | | 2425 | 2,508 | 7.60% | 8.13% | 7.77% | 8.05% | | 2306 | 2,329 | 7.56% | 8.26% | 8.05% | 8.05% | | 2349 | 2,556 | 7.30% | 6.56% | 8.13% | 8.05% | | 2440 | 2,680 | 6.90% | 7.82% | 7.72% | 8.05% | | 2564 | 2,816 | 7.34% | 7.40% | 7.73% | 8.05% | | 2,522 | 2,544 | 7.34% | 7.72% | 8.36% | 8.05% | | 30,261 | 30,533 | 7.34% | 7.72% | 8.36% | 8.05% | Table B.2: Numbers of System Collapse, 2010-2020 | Year | Type | Jan. | Feb. | Mar. | Apr. | | --- | --- | --- | --- | --- | --- | | 2010 | Total Collapse | 0 | 3 | 1 | 0 | | Partial Collapse | 1 | 0 | 0 | 1 | | | 2011 | Total Collapse | 0 | 0 | 0 | 0 | | Partial Collapse | 0 | 1 | 1 | 0 | | | 2012 | Total Collapse | 0 | 0 | 2 | 1 | | Partial Collapse | 0 | 0 | 2 | 3 | | | 2013 | Total Collapse | 0 | 1 | 2 | 2 | | Partial Collapse | 0 | 0 | 0 | 0 | | | 2014 | Total Collapse | 2 | 0 | 0 | 2 | | Partial Collapse | 0 | 0 | 0 | 0 | | | 2015 | Total Collapse | 1 | 0 | 1 | 0 | | Partial Collapse | 0 | 0 | 1 | 0 | | | 2016 | Total Collapse | 0 | 0 | 2 | 3 | | Partial Collapse | 0 | 0 | 1 | 0 | | | 2017 | Total Collapse | 5 | 3 | 0 | 3 | | Partial Collapse | 1 | 0 | 1 | 0 | | | 2018 | Total Collapse | 5 | 1 | 0 | 0 | | Partial Collapse | 0 | 0 | 0 | 1 | | | 2019 | Total Collapse | 4 | 1 | 0 | 1 | | Partial Collapse | 0 | 0 | 0 | 0 | | | 2020 | Total Collapse | 1 | 0 | 0 | 1 | | Partial Collapse | 0 | 0 | 0 | 0 | | | May | Jun. | Jul. | Aug. | Sep. | Oct. | Nov. | Dec. | Total | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 3 | 3 | 3 | 0 | 2 | 2 | 1 | 4 | 22 | | 1 | 3 | 4 | 4 | 3 | 2 | 0 | 1 | 20 | | 4 | 3 | 1 | 1 | 1 | 2 | 1 | 0 | 13 | | 0 | 0 | 0 | 1 | 0 | 1 | 2 | 0 | 6 | | 5 | 2 | 1 | 0 | 0 | 2 | 2 | 1 | 16 | | 0 | 0 | 0 | 0 | 1 | 0 | 1 | 1 | 8 | | 3 | 4 | 1 | 1 | 1 | 1 | 4 | 2 | 22 | | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 2 | | 0 | 3 | 1 | 0 | 0 | 1 | 0 | 0 | 9 | | 1 | 0 | 0 | 0 | 0 | 0 | 2 | 1 | 4 | | 2 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 6 | | 2 | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 4 | | 6 | 5 | 0 | 0 | 1 | 1 | 2 | 2 | 22 | | 1 | 3 | 1 | 0 | 0 | 0 | 0 | 0 | 6 | | 1 | 1 | 0 | 0 | 1 | 1 | 0 | 0 | 15 | | 0 | 0 | 1 | 0 | 3 | 3 | 0 | 0 | 9 | | 0 | 1 | 1 | 0 | 2 | 0 | 0 | 2 | 12 | | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | | 1 | 1 | 0 | 1 | 0 | 0 | 0 | 1 | 10 | | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | | 0 | 1 | 0 | 0 | 0 | 0 | 1 | 0 | 4 | | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | * * * Table B.3: Average Daily System Frequency (Hz), 2017-2020 | Period | Stress: | | | | Nominal Standard | | --- | --- | --- | --- | --- | --- | | Upper Limit | Lower Limit | Higher Bound | Lower Bound | | | | January | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | February | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | March | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | April | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | May | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | June | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | July | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | August | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | September | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | October | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | November | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | December | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | Annual | 50.25 | 49.75 | 51.25 | 48.75 | 50 | | High Frequency | | | | Low Frequency | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2020 | 2019 | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | 50.82 | 50.65 | 50.58 | 51.43 | 49.67 | 49.50 | 49.49 | 48.60 | | 50.70 | 50.46 | 50.61 | 51.48 | 49.75 | 49.77 | 49.90 | 48.76 | | 50.65 | 50.46 | 50.58 | 51.56 | 49.48 | 49.60 | 49.75 | 48.91 | | 50.77 | 50.43 | 50.69 | 51.48 | 49.63 | 49.71 | 49.77 | 48.63 | | 50.67 | 50.62 | 50.81 | 51.30 | 49.70 | 49.72 | 49.88 | 49.06 | | 50.86 | 50.51 | 50.65 | 50.69 | 49.73 | 49.77 | 49.66 | 49.61 | | 50.78 | 50.51 | 50.74 | 50.61 | 49.83 | 49.73 | 49.94 | 49.76 | | 50.74 | 50.61 | 50.71 | 50.63 | 49.84 | 49.78 | 49.89 | 49.73 | | 50.81 | 50.74 | 50.84 | 50.67 | 49.86 | 50.22 | 49.82 | 49.73 | | 50.88 | 50.93 | 50.93 | 50.63 | 49.70 | 49.89 | 49.99 | 49.80 | | 50.58 | 50.88 | 50.72 | 50.54 | 49.34 | 49.72 | 49.93 | 49.95 | | 50.44 | 50.81 | 50.60 | 50.55 | 49.40 | 49.52 | 49.55 | 50.02 | | 50.73 | 50.63 | 50.71 | 50.96 | 49.66 | 49.74 | 49.80 | 49.38 | Table B.4: Ave. Daily System Voltage (kV), 2017-2020 | Period | Upper Voltage(kV) | Lower Voltage(kV) | Nominal Standard(kV) | 2020 | | --- | --- | --- | --- | --- | | 346.5 | 313.5 | 330.0 | 355.48 | | | January | 346.5 | 313.5 | 330.0 | 351.52 | | February | 346.5 | 313.5 | 330.0 | 352.65 | | March | 346.5 | 313.5 | 330.0 | 352.65 | | April | 346.5 | 313.5 | 330.0 | 356.80 | | May | 346.5 | 313.5 | 330.0 | 355.29 | | June | 346.5 | 313.5 | 330.0 | 355.90 | | July | 346.5 | 313.5 | 330.0 | 355.00 | | August | 346.5 | 313.5 | 330.0 | 354.47 | | September | 346.5 | 313.5 | 330.0 | 354.83 | | October | 346.5 | 313.5 | 330.0 | 353.74 | | November | 346.5 | 313.5 | 330.0 | 352.37 | | December | 346.5 | 313.5 | 330.0 | 349.55 | | Annual Ave. | 346.5 | 313.5 | 330.0 | 353.97 | | High Voltage(kV) | | | | Low Voltage(kV) | | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2019 | 2018 | 2017 | 2020 | 2019 | 2018 | 2017 | | | 348.26 | 355.58 | 357.0 | 298.19 | 295.00 | 297.03 | 298.0 | | | 349.36 | 354.00 | 351.6 | 299.00 | 298.39 | 297.79 | 295.0 | | | 350.23 | 351.23 | 355.3 | 299.03 | 294.03 | 297.45 | 295.7 | | | 360.83 | 355.12 | 355.6 | 290.97 | 299.40 | 295.37 | 295.2 | | | 355.71 | 357.13 | 357.1 | 290.87 | 298.23 | 298.13 | 293.5 | | | 356.13 | 356.73 | 359.9 | 297.50 | 299.03 | 297.47 | 293.8 | | | 354.13 | 353.58 | 359.9 | 296.93 | 299.48 | 297.26 | 296.0 | | | 356.29 | 351.81 | 360.0 | 297.67 | 299.39 | 297.16 | 299.4 | | | 355.03 | 354.67 | 359.5 | 300.97 | 299.20 | 296.30 | 295.5 | | | 357.73 | 353.52 | 355.6 | 296.16 | 299.61 | 295.75 | 295.3 | | | 356.10 | 350.50 | 353.6 | 294.87 | 299.47 | 298.17 | 297.3 | | | 351.47 | 348.81 | 353.0 | 298.61 | 300.58 | 298.00 | 299.8 | | | 354.27 | 353.54 | 355.6 | 296.73 | 298.48 | 297.15 | 295.4 | | * * * C. Commercial Performance Table C.1: Quarterly & Yearly Energy Received & Billed by DisCos, 2018-20 | DisCos | 2020Q | | | --- | --- | --- | | /Q1 | /Q2 | | | 966 | 971 | | | Abuja | 966 | 971 | | Benin | 605 | 611 | | Eko | 864 | 882 | | Enugu | 579 | 496 | | Ibadan | 965 | 969 | | Ikeja | 1,144 | 1,105 | | Jos | 341 | 315 | | Kaduna | 504 | 645 | | Kano | 424 | 500 | | Port Harcourt | 499 | 500 | | Yola | 302 | 308 | | All DisCos Total | 7,195 | 7,303 | | All DisCos Average | 654 | 664 | | | | | | | /Q1 | /Q2 | | Abuja | 635 | 534 | | Benin | 524 | 501 | | Eko | 762 | 762 | | Enugu | 425 | 348 | | Ibadan | 751 | 600 | | Ikeja | 1035 | 1012 | | Jos | 228 | 172 | | Kaduna | 351 | 232 | | Kano | 367 | 354 | | Port Harcourt | 417 | 349 | | Yola | 145 | 130 | | All DisCos Total | 5,639 | 4,993 | | All DisCos Average | 513 | 454 | | | | | | | /Q1 | /Q2 | | Abuja | 65.73 | 54.99 | | Benin | 86.57 | 82.04 | | Eko | 88.11 | 86.32 | | Enugu | 73.40 | 70.16 | | Ibadan | 77.79 | 61.89 | | Ikeja | 90.45 | 91.55 | | Jos | 66.92 | 54.46 | | Kaduna | 69.64 | 35.97 | | Kano | 86.50 | 70.78 | | Port Harcourt | 83.41 | 69.82 | | Yola | 48.01 | 42.21 | | All DisCos Total | 78.38 | 68.37 | | All DisCos Average | 76.05 | 65.47 | | Total Energy Received (GWh) | | | | | | --- | --- | --- | --- | --- | | Quarters | | | Annual | | | /Q3 | /Q4 | 2020 | 2019\* | 2018 | | 882 | 1,057 | 3,876 | 3,794 | 3,621 | | 664 | 699 | 2,579 | 2,332 | 2,519 | | 842 | 969 | 3,558 | 3,358 | 3,214 | | 609 | 742 | 2,426 | 1,179 | 2,252 | | 999 | 1,100 | 4,035 | 3,562 | 3,444 | | 1,134 | 1,198 | 4,581 | 4,248 | 3,510 | | 363 | 359 | 1,378 | 1,241 | 1,245 | | 574 | 572 | 2,295 | 1,963 | 2,133 | | 450 | 501 | 1,875 | 1,776 | 1,938 | | 487 | 541 | 2,027 | 1,981 | 1,941 | | 283 | 296 | 1,189 | 1,050 | 975 | | 7,287 | 8,035 | 29,819 | 26,485 | 26,790 | | 662 | 730 | 2,711 | 2,408 | 2,435 | | Total Energy Billed (GWh) | | | | | | /Q3 | /Q4 | 2020 | 2019\* | 2018 | | 576 | 619 | 2,364 | 2,956 | 2,929 | | 559 | 582 | 2,165 | 2,025 | 2,122 | | 769 | 837 | 3,129 | 2,973 | 2,860 | | 445 | 530 | 1,748 | 1,121 | 1,534 | | 668 | 838 | 2,857 | 2,958 | 2,792 | | 1056 | 1064 | 4,167 | 3,744 | 3,260 | | 176 | 203 | 779 | 890 | 831 | | 381 | 449 | 1,413 | 1,597 | 1,488 | | 333 | 380 | 1,434 | 1,459 | 1,588 | | 361 | 437 | 1,564 | 1,483 | 1,442 | | 125 | 143 | 543 | 715 | 636 | | 5,449 | 6,082 | 22,163 | 21,921 | 21,484 | | 495 | 553 | 2,015 | 1,993 | 1,953 | | Billing Efficiency (%) | | | | | | /Q3 | /Q4 | 2020 | 2019\* | 2018 | | 65.31 | 58.56 | 60.99 | 77.91 | 80.90 | | 84.18 | 83.18 | 83.96 | 86.84 | 84.25 | | 91.32 | 86.38 | 87.96 | 88.53 | 89.01 | | 73.07 | 71.43 | 72.05 | 95.08 | 68.10 | | 66.87 | 76.14 | 70.82 | 83.04 | 81.09 | | 93.14 | 88.82 | 90.95 | 88.14 | 92.89 | | 48.48 | 56.55 | 56.51 | 71.72 | 66.72 | | 66.38 | 78.50 | 61.57 | 81.36 | 69.77 | | 74.00 | 75.83 | 76.46 | 82.15 | 81.96 | Notes of the table: 1. DisCos are the electricity Distribution Companies and GWh is gigawatt-hours; - Indicates the values in the cell for Enugu, Yola and total DisCos are different from those reported in the 2019 report due to adjustment for errors detected * * * Table C.2: Quarterly & Yearly Revenue Performance by DisCos in 2018-20 | DisCos | 2020Q4 | | | --- | --- | --- | | /Q1 | /Q2 | | | 22.38 | 18.53 | | | Abuja | 22.38 | 18.53 | | Benin | 19.40 | 18.82 | | Eko | 23.58 | 23.16 | | Enugu | 16.40 | 13.75 | | Ibadan | 23.95 | 19.13 | | Ikeja | 29.61 | 28.10 | | Jos | 8.51 | 6.18 | | Kaduna | 11.23 | 8.01 | | Kano | 11.96 | 11.41 | | Port Harcourt | 15.59 | 13.00 | | Yola | 4.22 | 4.00 | | All DisCos Total | 186.82 | 164.07 | | All DisCos Average | 16.98 | 14.92 | | | Total | | | /Q1 | /Q2 | | | 18.10 | 17.70 | | | Abuja | 9.53 | 10.64 | | Eko | 16.80 | 19.69 | | Enugu | 9.77 | 10.02 | | Ibadan | 13.33 | 14.01 | | Ikeja | 21.43 | 24.28 | | Jos | 4.03 | 3.93 | | Kaduna | 4.95 | 4.83 | | Kano | 7.32 | 7.06 | | Port Harcourt | 6.76 | 6.91 | | Yola | 2.28 | 2.56 | | All DisCos Total | 114.29 | 121.61 | | All DisCos Average | 10.39 | 11.06 | | | Total | | | /Q1 | /Q2 | | | 80.89 | 95.52 | | | Abuja | 49.13 | 56.52 | | Eko | 71.23 | 85.00 | | Enugu | 59.57 | 72.85 | | Ibadan | 55.66 | 73.20 | | Ikeja | 72.37 | 86.41 | | Jos | 47.40 | 63.70 | | Kaduna | 44.09 | 60.35 | | Kano | 61.18 | 61.85 | | Port Harcourt | 43.36 | 53.18 | | Yola | 54.02 | 64.06 | | All DisCos Total | 61.18 | 74.12 | | All DisCos Average | 58.08 | 70.24 | | Total Billing (¥' Billion) | | | | | | --- | --- | --- | --- | --- | | Quarters | | | Annual | | | /Q3 | /Q4 | 2020 | 2019\* | 2018 | | 22.69 | 29.37 | 92.97 | 99.38 | 95.76 | | 22.72 | 25.04 | 85.97 | 72.30 | 75.33 | | 27.20 | 33.73 | 107.67 | 89.93 | 78.10 | | 19.31 | 25.19 | 74.64 | 5.45 | 64.39 | | 25.03 | 33.05 | 101.16 | 91.20 | 83.77 | | 33.78 | 41.85 | 133.33 | 104.72 | 90.41 | | 6.78 | 9.14 | 30.61 | 31.79 | 29.81 | | 15.52 | 22.39 | 57.14 | 50.48 | 46.03 | | 13.33 | 15.88 | 52.57 | 45.98 | 48.05 | | 14.49 | 18.71 | 61.79 | 53.41 | 51.91 | | 4.54 | 5.56 | 18.32 | 16.86 | 17.05 | | 205.37 | 259.90 | 816.16 | 661.50 | 680.61 | | 18.67 | 23.63 | 74.20 | 60.14 | 61.87 | 1. DisCos are the electricity Distribution Companies and N' Billion is billions of Nigeria Currency; - Indicates the values in the cell for Enugu, Yola and total DisCos are different from those reported in the 2019 report due to adjustment for errors detected * * * Table C.3: Energy Off-take vs. MYTO Load Allocation by DisCos in 2018-20 | | Load Capacity(MW/Year) | | | Total Energy Loaded(TWh) | | | --- | --- | --- | --- | --- | --- | | DisCos | 2020 | 2019 | 2018 | 2020 | 2019 | | Abuja | 4.03 | 5.35 | 4.38 | 3.87 | 3.79 | | Benin | 3.16 | 3.29 | 3.02 | 2.60 | 2.34 | | Eko | 3.86 | 4.56 | 3.91 | 3.56 | 3.36 | | Enugu | 3.16 | 3.22 | 3.08 | 2.45 | 2.28 | | Ibadan | 4.56 | 5.07 | 4.43 | 4.07 | 3.58 | | Ikeja | 5.26 | 5.46 | 3.76 | 4.25 | 3.85 | | Jos | 1.93 | 1.80 | 1.81 | 1.41 | 1.27 | | Kaduna | 2.80 | 2.78 | 2.63 | 2.35 | 1.98 | | Kano | 2.80 | 2.52 | 2.35 | 1.89 | 1.78 | | P/H | 2.28 | 2.79 | 2.72 | 2.00 | 1.97 | | Yola | 1.23 | 1.62 | 1.09 | 1.18 | 1.14 | | All DisCos | 35.06 | 38.45 | 33.17 | 29.63 | 27.35 | | DisCos Ave. | 3.19 | 3.50 | 3.02 | 2.69 | 2.49 | | Paras/SBEE | 0.59 | - | - | 0.55 | - | | Odukpani/CEET | 0.53 | - | - | 0.42 | - | | NIGELEC | 1.13 | 1.37 | 1.10 | 1.12 | 1.06 | | Transcorp/SBEE | 0.06 | - | - | 0.06 | - | | Ajaokuta Steel | 3.31 | 0.05 | 0.07 | 0.04 | 0.04 | | y | Actual Load Allocation(%) | | | MYTO Load Allocation(%) | Load Deviation(%) | | | | --- | --- | --- | --- | --- | --- | --- | --- | | 2020 | 2019 | 2018 | 2020 | 2019 | 2018 | | | | 3.62 | 13.08 | 13.87 | 13.51 | 11.50 | 1.58 | 2.37 | 2.01 | | 2.52 | 8.77 | 8.56 | 9.40 | 9.00 | -0.23 | -0.44 | 0.40 | | 3.22 | 12.01 | 12.28 | 12.00 | 11.00 | 1.01 | 1.28 | 1.00 | | 2.25 | 8.26 | 8.34 | 8.41 | 9.00 | -0.74 | -0.66 | -0.59 | | 3.45 | 13.73 | 13.08 | 12.85 | 13.00 | 0.73 | 0.08 | -0.15 | | 3.51 | 14.35 | 14.08 | 13.10 | 15.00 | -0.65 | -0.92 | -1.90 | | 1.25 | 4.77 | 4.64 | 4.65 | 5.50 | -0.73 | -0.86 | -0.85 | | 2.13 | 7.93 | 7.23 | 7.96 | 8.00 | -0.07 | -0.77 | -0.04 | | 1.94 | 6.38 | 6.52 | 7.23 | 8.00 | -1.62 | -1.48 | -0.77 | | 1.94 | 6.75 | 7.21 | 7.24 | 6.50 | 0.25 | 0.71 | 0.74 | | 0.98 | 3.98 | 4.18 | 3.64 | 3.50 | 0.48 | 0.68 | 0.14 | | 26.81 | 100.0 | 100.0 | 100.0 | 100.0 | 0.00 | 0.00 | 0.00 | | 2.44 | 9.09 | 9.09 | 9.09 | 9.09 | n/a | n/a | n/a | | | | | | | | | | | | | | | | | | | | 0.99 | | | | | | | | | | | | | | | | | | 0.05 | | | | | | | | Notes of the table: DisCos, CEB and NIGELEC and MYTO are electricity Distribution Companies, Beninois Electricity Community and Nigerien Electricity Society respectively; and Multi-Year Tariff Order Table C.4: Historical MYTO Targets and ATC&C Losses 2016-2020 | DisCos | 2020 | | 2019\* | | | --- | --- | --- | --- | --- | | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | | | Abuja | 22.33 | 45.80 | 24.00 | 41.07 | | Benin | 23.91 | 55.41 | 31.00 | 50.52 | | Eko | 11.23 | 30.85 | 14.00 | 26.22 | | Enugu | 20.56 | 53.83 | 29.00 | 30.94 | | Ibadan | 19.67 | 56.74 | 25.00 | 47.74 | | Ikeja | 10.81 | 28.21 | 15.00 | 23.91 | | Jos | 39.12 | 67.79 | 44.00 | 60.40 | | Kaduna | 20.12 | 76.80 | 32.00 | 66.81 | | Kano | 22.06 | 50.78 | 29.00 | 43.72 | | Port Harcourt | 29.70 | 60.80 | 37.00 | 61.62 | | Yola | 23.71 | 73.24 | 28.00 | 65.08 | | Overall DisCos: | | | | | | 2018 | | 2017 | | 2016 | | | --- | --- | --- | --- | --- | --- | | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | | 22.33 | 40.15 | 24.03 | 47.58 | 31.54 | 48.64 | | 23.91 | 53.24 | 30.89 | 55.80 | 38.62 | 55.30 | | 11.23 | 30.56 | 14.20 | 17.95 | 38.43 | 34.26 | | 20.56 | 51.68 | 28.71 | 67.13 | 30.41 | 61.67 | | 19.67 | 49.96 | 24.72 | 54.08 | 48.32 | 50.05 | | 10.81 | 21.82 | 15.22 | 29.07 | 31.93 | 44.38 | | 39.12 | 69.61 | 43.95 | 76.00 | 38.20 | 72.46 | | 12.47 | 69.82 | 20.12 | 74.27 | 19.44 | 72.84 | | 22.06 | 51.47 | 29.41 | 62.32 | 20.82 | 60.61 | | 29.70 | 63.66 | 37.13 | 66.14 | 45.00 | 59.90 | | 23.71 | 68.42 | 27.51 | 66.46 | 32.81 | 63.37 | Overall DisCos: Notes of the table: DisCos are the electricity distribution companies; MYTO is Multi-Year Tariff Order; ATC&C is Aggregate Technical, Commercial and Collection; ATC is aggregate Technical, Commercial and Collection; and C is Collection; $ ^{\*} $ Indicates the values in the cell for Enugu, Yola and total DisCos are different from those reported in 2019 report due to adjustment for errors detected. * * * Key Statistics Table C.5: Annual Invoice from NBET & MO by DisCos, 2016-2020 | | Jan20 | Feb20 | Mar20 | Apr20 | May20 | Jun20 | Jul20 | Aug20 | Sep20 | Oct20 | Nov20 | Dec20 | 2020 | 2019 | 2018 | 2017 | 2016 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | NBET Invoice | | | | | | | | | | | | | | | | | | | Abuja | 6.41 | 6.43 | 6.86 | 8.53 | 8.26 | 6.95 | 7.97 | 7.46 | 7.10 | 7.69 | 7.93 | 8.32 | 89.91 | 87.88 | 76.66 | 65.13 | 49.67 | | Benin | 4.62 | 4.66 | 4.43 | 5.83 | 5.89 | 5.00 | 5.99 | 5.91 | 5.39 | 5.59 | 5.64 | 5.97 | 64.93 | 54.28 | 53.34 | 44.84 | 33.69 | | Eko | 6.11 | 6.13 | 5.91 | 7.82 | 7.90 | 6.40 | 7.51 | 7.21 | 6.78 | 7.33 | 7.17 | 7.85 | 84.12 | 77.99 | 68.08 | 58.17 | 32.11 | | Enugu | 4.52 | 4.54 | 4.35 | 5.33 | 5.30 | 4.56 | 5.49 | 5.76 | 5.29 | 5.60 | 5.81 | 6.33 | 62.88 | 52.94 | 47.69 | 45.76 | 40.56 | | Ibadan | 7.22 | 6.74 | 6.90 | 8.93 | 8.89 | 7.50 | 9.08 | 8.69 | 7.78 | 8.47 | 8.44 | 9.08 | 97.72 | 83.21 | 72.91 | 65.82 | 45.84 | | Ikeja | 7.77 | 7.67 | 8.02 | 10.16 | 10.24 | 8.64 | 10.11 | 9.22 | 8.43 | 8.64 | 8.28 | 10.00 | 107.19 | 89.52 | 74.41 | 55.84 | 46.40 | | Jos | 2.69 | 2.72 | 2.66 | 3.54 | 3.34 | 2.84 | 3.40 | 3.26 | 3.28 | 3.25 | 3.10 | 3.37 | 37.44 | 29.46 | 26.36 | 26.95 | 19.37 | | Kaduna | 3.57 | 3.95 | 4.32 | 5.81 | 5.85 | 4.58 | 5.39 | 5.04 | 4.78 | 5.20 | 4.83 | 5.02 | 58.34 | 45.69 | 44.65 | 39.04 | 31.50 | | Kano | 3.73 | 3.58 | 3.57 | 5.20 | 5.19 | 3.90 | 4.61 | 4.57 | 4.32 | 4.59 | 4.41 | 4.76 | 52.43 | 41.27 | 41.65 | 34.93 | 23.43 | | Port Harcourt | 3.59 | 3.62 | 3.52 | 4.28 | 4.61 | 3.81 | 4.31 | 4.13 | 3.74 | 4.25 | 4.19 | 4.34 | 48.39 | 45.77 | 41.09 | 40.34 | 32.96 | | Yola | 1.91 | 1.95 | 2.08 | 2.66 | 2.61 | 2.09 | 2.46 | 2.38 | 2.22 | 2.33 | 2.21 | 2.45 | 27.37 | 26.49 | 20.68 | 16.19 | 9.86 | Notes of the table: 1. NBET and MOs are Nigeria Bulk Electricity Trader and Market Operators respectively. 2. N' Billion is billions of Nigeria Currency. Source: Nigerian Bulk Electricity Trading Plc, and Market Operator. * * * Key Statistics Table C.6: Annual Remittances to NBET and MO by DisCos, 2016-2020 | | Jan20 | Feb20 | Mar20 | Apr20 | May20 | Jun20 | Jul20 | | --- | --- | --- | --- | --- | --- | --- | --- | | Remittances to NBET | Amount in(N'Billion) | | | | | | | | Abuja | 2.55 | 2.40 | 1.13 | 2.00 | 2.84 | 2.22 | 1.07 | | Benin | 1.23 | 1.32 | 0.42 | 0.73 | 1.06 | 1.20 | 1.56 | | Eko | 2.52 | 2.18 | 0.91 | 2.55 | 2.75 | 2.27 | 2.35 | | Enugu | 1.06 | 0.91 | 0.40 | 0.80 | 0.40 | 0.80 | 1.10 | | Ibadan | 2.01 | 1.71 | 1.04 | 1.34 | 1.69 | 1.90 | 2.45 | | Ikeja | 3.58 | 3.07 | 1.58 | 2.44 | 2.97 | 3.37 | 2.85 | | Jos | 0.24 | 0.20 | 0.15 | 0.16 | 0.20 | 0.23 | 0.27 | | Kaduna | 0.30 | 0.12 | 0.15 | 0.10 | 0.10 | 0.05 | 0.44 | | Kano | 0.70 | 0.50 | 0.00 | 0.00 | 0.35 | 0.35 | 0.30 | | Port Harcourt | 0.53 | 0.54 | 0.25 | 0.30 | 0.21 | 0.32 | 0.26 | | Yola | 0.24 | 0.23 | 0.05 | 0.25 | 0.29 | 0.20 | 0.25 | | All DisCos Total | 14.96 | 13.18 | 6.07 | 10.67 | 12.84 | 12.91 | 12.91 | | All DisCos Ave. | 1.36 | 1.20 | 0.55 | 0.97 | 1.17 | 1.17 | 1.17 | | Remittances to MOs | Amount in(N'Billion) | | | | | | | | Abuja | 1.23 | 1.19 | 1.11 | 1.47 | 1.32 | 1.39 | 1.22 | | Benin | 0.83 | 0.81 | 0.70 | 0.89 | 0.87 | 0.76 | 0.90 | | Eko | 1.18 | 1.13 | 1.12 | 1.30 | 1.26 | 1.01 | 1.11 | | Enugu | 0.79 | 0.77 | 0.76 | 0.73 | 0.70 | 0.63 | 0.76 | | Ibadan | 1.39 | 1.17 | 1.04 | 1.16 | 1.37 | 1.20 | 1.41 | | Ikeja | 1.42 | 1.31 | 1.20 | 1.29 | 1.56 | 1.78 | 1.70 | | Jos | 0.46 | 0.45 | 0.46 | 0.29 | 0.30 | 0.57 | 0.00 | | Kaduna | 0.56 | 0.33 | 0.66 | 0.36 | 0.00 | 0.36 | 0.20 | | Kano | 0.61 | 0.53 | 0.46 | 0.63 | 0.45 | 0.52 | 0.00 | | Port Harcourt | 0.69 | 0.67 | 0.56 | 0.33 | 0.73 | 0.61 | 0.69 | | Yola | 0.36 | 0.18 | 0.24 | 0.07 | 0.05 | 0.00 | 0.51 | | All DisCos Total | 9.52 | 8.54 | 8.30 | 8.53 | 8.60 | 8.83 | 8.50 | | Aug20 | Sep20 | Oct20 | Nov20 | Dec20 | 2020 | 2019 | 2018 | 2017 | 2016 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2.80 | 4.97 | 3.22 | 3.67 | 5.35 | 34.23 | 34.98 | 26.03 | 22.14 | 15.16 | | 1.59 | 2.94 | 1.99 | 2.75 | 2.90 | 19.70 | 14.10 | 16.15 | 13.72 | 8.25 | | 2.52 | 5.10 | 3.15 | 4.43 | 4.86 | 35.60 | 31.92 | 26.30 | 22.79 | 14.75 | | 1.20 | 3.60 | 2.80 | 3.96 | 2.72 | 19.74 | 12.45 | 16.53 | 14.65 | 11.03 | | 2.08 | 4.65 | 2.37 | 4.43 | 4.66 | 30.31 | 22.74 | 23.95 | 21.06 | 14.47 | | 3.50 | 6.99 | 4.23 | 6.08 | 7.34 | 47.99 | 34.37 | 31.15 | 19.78 | 16.28 | | 0.28 | 0.99 | 0.28 | 0.80 | 0.87 | 4.66 | 2.12 | 2.38 | 3.56 | 3.80 | | 0.40 | 3.28 | 1.51 | 2.93 | 3.04 | 12.42 | 6.92 | 6.20 | 5.89 | 5.70 | | 0.00 | 3.16 | 1.74 | 2.85 | 3.07 | 13.02 | 10.20 | 6.66 | 4.40 | 3.88 | | 0.36 | 1.63 | 1.19 | 1.64 | 1.70 | 8.93 | 8.55 | 7.61 | 6.87 | 5.29 | | 0.25 | 0.26 | 0.00 | 0.36 | 0.38 | 2.76 | 2.99 | 2.44 | 2.48 | 1.35 | | 14.99 | 37.57 | 22.47 | 33.89 | 36.90 | 229.36 | 181.34 | 165.40 | 137.33 | 99.95 | | 1.36 | 3.42 | 2.04 | 3.08 | 3.35 | 20.85 | 16.49 | 15.04 | 12.49 | 9.09 | | | | | | | | | | | | | 1.18 | 0.33 | 1.30 | 2.07 | 2.87 | 16.68 | 11.08 | 4.50 | 3.47 | 3.79 | | 0.95 | 1.93 | 0.90 | 2.04 | 2.06 | 13.64 | 7.09 | 5.09 | 4.71 | 4.13 | | 1.15 | 2.25 | 1.24 | 2.50 | 2.74 | 17.99 | 12.02 | 8.78 | 10.12 | 6.12 | | 0.90 | 1.93 | 0.90 | 2.02 | 2.17 | 13.07 | 6.76 | 2.65 | 2.70 | 2.18 | | 1.42 | 2.65 | 1.41 | 2.94 | 3.11 | 20.27 | 11.24 | 4.32 | 3.98 | 4.46 | | 1.38 | 2.83 | 1.28 | 2.57 | 3.28 | 21.61 | 13.35 | 8.07 | 6.72 | 5.59 | Notes of the table: 1. NBET and MOs are Nigeria Bulk Electricity Trader and Market Operators respectively. 2. N' Billion is billions of Nigeria Currency. Source: Nigerian Bulk Electricity Trading Plc, and Market Operator. * * * Key Statistics Table C.7: Annual Shortfalls to NBET & MO by DisCos, 2016-2020 | | Jan20 | Feb20 | Mar20 | Apr20 | May20 | Jun20 | Jul20 | | --- | --- | --- | --- | --- | --- | --- | --- | | Shortfalls to NBETAmount in(N'Billion) | | | | | | | | | Abuja | 3.86 | 4.03 | 5.73 | 6.53 | 5.43 | 4.73 | 6.89 | | Benin | 3.39 | 3.35 | 4.01 | 5.10 | 4.83 | 3.80 | 4.44 | | Eko | 3.58 | 3.95 | 5.00 | 5.26 | 5.15 | 4.14 | 5.16 | | Enugu | 3.47 | 3.64 | 3.95 | 4.53 | 4.90 | 3.76 | 4.39 | | Ibadan | 5.21 | 5.03 | 5.87 | 7.59 | 7.20 | 5.60 | 6.62 | | Ikeja | 4.20 | 4.60 | 6.44 | 7.72 | 7.28 | 5.27 | 7.26 | | Jos | 2.44 | 2.52 | 2.51 | 3.38 | 3.14 | 2.61 | 3.12 | | Kaduna | 3.27 | 3.83 | 4.17 | 5.71 | 5.75 | 4.53 | 4.95 | | Kano | 3.03 | 3.08 | 3.57 | 5.20 | 4.84 | 3.55 | 4.31 | | Port Harcourt | 3.06 | 3.08 | 3.27 | 3.98 | 4.40 | 3.49 | 4.05 | | Yola | 1.67 | 1.72 | 2.03 | 2.41 | 2.32 | 1.89 | 2.21 | | All DisCos Total | 37.17 | 38.82 | 46.55 | 57.40 | 55.25 | 43.36 | 53.42 | | All DisCos Ave. | 3.38 | 3.53 | 4.23 | 5.22 | 5.02 | 3.94 | 4.86 | | Shortfalls to MOsAmount in(N'Billion) | | | | | | | | | Abuja | 0.00 | 0.00 | 0.28 | 0.00 | 0.01 | -0.26 | 0.00 | | Benin | -0.01 | 0.00 | 0.08 | 0.00 | 0.01 | 0.00 | 0.00 | | Eko | -0.01 | 0.00 | 0.00 | 0.00 | 0.01 | 0.00 | 0.03 | | Enugu | 0.00 | 0.00 | 0.00 | 0.00 | 0.01 | 0.00 | 0.00 | | Ibadan | 0.00 | 0.00 | 0.26 | 0.29 | 0.02 | -0.02 | 0.00 | | Ikeja | -0.02 | 0.00 | 0.30 | 0.32 | 0.02 | -0.43 | -0.18 | | Jos | 0.00 | 0.00 | 0.00 | 0.24 | 0.16 | -0.16 | 0.48 | | Kaduna | 0.00 | 0.33 | 0.16 | 0.63 | 0.96 | 0.36 | 0.61 | | Kano | 0.00 | 0.00 | 0.11 | 0.16 | 0.31 | 0.00 | 0.60 | | Port Harcourt | 0.00 | 0.00 | 0.11 | 0.33 | 0.01 | 0.00 | -0.05 | | Yola | 0.00 | 0.18 | 0.18 | 0.40 | 0.38 | 0.34 | -0.13 | | All DisCos Total | -0.03 | 0.51 | 1.48 | 2.37 | 1.91 | -0.17 | 1.35 | | Aug20 | Sep20 | Oct20 | Nov20 | Dec20 | 2020 | 2019 | 2018 | 2017 | 2016 | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 4.66 | 2.13 | 4.46 | 4.25 | 2.98 | 55.68 | 52.89 | 50.6 | 43.00 | 34.51 | | 4.31 | 2.45 | 3.60 | 2.89 | 3.06 | 45.22 | 40.18 | 37.20 | 31.12 | 25.43 | | 4.69 | 1.67 | 4.18 | 2.73 | 3.00 | 48.52 | 46.07 | 41.78 | 35.38 | 17.36 | | 4.56 | 1.69 | 2.80 | 1.85 | 3.61 | 43.14 | 40.49 | 31.16 | 31.11 | 29.53 | | 6.61 | 3.14 | 6.10 | 4.02 | 4.42 | 67.41 | 60.47 | 48.95 | 44.76 | 31.37 | | 5.72 | 1.43 | 4.41 | 2.21 | 2.66 | 59.20 | 55.14 | 43.26 | 36.06 | 30.12 | | 2.98 | 2.29 | 2.98 | 2.30 | 2.51 | 32.78 | 27.34 | 23.99 | 23.39 | 15.57 | | 4.64 | 1.50 | 3.69 | 1.90 | 1.98 | 45.92 | 38.77 | 38.45 | 33.16 | 25.80 | | 4.57 | 1.17 | 2.85 | 1.56 | 1.68 | 39.41 | 31.07 | 34.98 | 30.53 | 19.54 | | 3.77 | 2.11 | 3.06 | 2.55 | 2.64 | 39.46 | 37.22 | 33.48 | 33.47 | 27.67 | | 2.13 | 1.96 | 2.33 | 1.85 | 2.07 | 24.60 | 23.50 | 18.25 | 13.72 | 8.51 | | 48.63 | 21.54 | 40.48 | 28.12 | 30.60 | 501.35 | 453.13 | 402.13 | 355.68 | 265.41 | | 4.42 | 1.96 | 3.68 | 2.56 | 2.78 | 45.58 | 41.19 | 36.56 | 32.34 | 24.13 | | | | | | | | | | | | | 0.00 | 2.08 | 0.00 | 0.80 | 0.06 | 2.97 | 4.03 | 9.46 | 9.30 | 7.58 | | 0.00 | 0.00 | 0.00 | 0.00 | -0.21 | -0.13 | 2.24 | 4.63 | 4.08 | 3.46 | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.04 | 1.36 | 3.62 | 1.29 | 2.50 | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.01 | 2.34 | 6.04 | 6.28 | 7.07 | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.55 | 3.05 | 9.01 | 8.97 | 5.93 | | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.01 | 1.95 | 5.44 | 4.20 | 5.98 | 1. NBET and MOs are Nigeria Bulk Electricity Trader and Market Operators respectively. Source: Nigerian Bulk Electricity Trading Plc, and Market Operator. * * * Table C.8: Total Market Invoice, Remittance & Shortfall by DisCos, 2016-20 \| DisCos \| Invoice (# Billion) \| \| \| \| \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \| 2020 \| 2019 \| 2018 \| 2017 \| \| \| Abuja \| 109.57 \| 102.99 \| 90.62 \| 77.91 \| \| Benin \| 78.44 \| 63.61 \| 63.06 \| 53.63 \| \| Eko \| 102.14 \| 91.37 \| 80.49 \| 69.57 \| \| Enugu \| 75.96 \| 62.03 \| 56.39 \| 54.74 \| \| Ibadan \| 118.53 \| 97.50 \| 86.24 \| 78.77 \| \| Ikeja \| 128.80 \| 104.82 \| 87.92 \| 66.76 \| \| Jos \| 44.84 \| 34.52 \| 31.18 \| 32.25 \| \| Kaduna \| 70.20 \| 53.58 \| 52.91 \| 46.73 \| \| Kano \| 62.52 \| 48.38 \| 49.13 \| 41.77 \| \| Port Harcourt \| 58.53 \| 53.63 \| 48.59 \| 48.25 \| \| Yola \| 33.20 \| 31.07 \| 24.47 \| 19.38 \| \| All DisCos Total \| 882.73 \| 743.50 \| 670.98 \| 589.75 \| \| All DisCos Ave. \| 80.25 \| 67.59 \| 61.00 \| 53.61 \| \| Remittances | (#’ Billion) | | | | | | | --- | --- | --- | --- | --- | --- | | 2016 | 2020 | 2019 | 2018 | 2017 | 2016 | | 61.03 | 50.91 | 46.07 | 30.53 | 25.61 | 18.95 | | 41.28 | 33.34 | 21.19 | 21.23 | 18.43 | 12.39 | | 40.72 | 53.58 | 43.94 | 35.09 | 32.91 | 20.87 | | 49.81 | 32.81 | 19.21 | 19.18 | 17.35 | 13.21 | | 56.23 | 50.58 | 33.98 | 28.28 | 25.04 | 18.93 | | 57.97 | 69.60 | 47.72 | 39.22 | 26.50 | 21.87 | | 23.89 | 11.70 | 5.70 | 3.13 | 4.36 | 4.05 | | 38.69 | 21.64 | 12.62 | 7.69 | 7.31 | 6.64 | | 28.69 | 22.21 | 15.12 | 7.96 | 5.48 | 4.63 | | 40.45 | 18.39 | 14.28 | 9.36 | 8.68 | 6.44 | | 12.11 | 5.59 | 6.88 | 5.03 | 5.54 | 2.59 | | 450.87 | 370.34 | 266.71 | 206.68 | 177.20 | 130.56 | | 40.99 | 33.67 | 24.25 | 18.79 | 16.11 | 11.87 | | | Shorttalls(N' Billion) | | | | | --- | --- | --- | --- | --- | | DisCos | 2020 | 2019 | 2018 | 2017 | | Abuja | 58.66 | 56.92 | 60.10 | 52.30 | | Benin | 45.10 | 42.42 | 41.83 | 35.20 | | Eko | 48.56 | 47.43 | 45.40 | 36.66 | | Enugu | 43.15 | 42.82 | 37.21 | 37.39 | | Ibadan | 67.96 | 63.52 | 57.96 | 53.73 | | Ikeja | 59.21 | 57.10 | 48.70 | 40.26 | | Jos | 33.14 | 28.82 | 28.05 | 27.88 | | Kaduna | 48.57 | 40.96 | 45.22 | 39.43 | | Kano | 40.31 | 33.25 | 41.17 | 36.29 | | Port Harcourt | 40.14 | 39.35 | 39.23 | 39.57 | | Yola | 27.61 | 24.19 | 19.43 | 13.84 | | All DisCos Total | 512.39 | 476.79 | 464.30 | 412.55 | | All DisCos Ave. | 46.58 | 43.34 | 42.21 | 37.50 | | | | Remittance Performance(%) | | | | | --- | --- | --- | --- | --- | --- | | 2016 | 2020 | 2019 | 2018 | 2017 | 2016 | | 42.09 | 46.46 | 44.73 | 33.67 | 32.87 | 31.04 | | 28.89 | 42.51 | 33.31 | 33.67 | 34.37 | 30.01 | | 19.86 | 52.46 | 48.09 | 43.59 | 47.30 | 51.24 | | 36.60 | 43.20 | 30.96 | 34.01 | 31.69 | 26.52 | | 37.30 | 42.67 | 34.85 | 32.79 | 31.79 | 33.67 | | 36.11 | 54.03 | 45.52 | 44.61 | 39.70 | 37.72 | | 19.84 | 26.09 | 16.50 | 10.04 | 13.53 | 16.94 | | 32.04 | 30.82 | 23.56 | 14.53 | 15.63 | 17.17 | | 24.05 | 35.52 | 31.26 | 16.19 | 13.12 | 16.15 | | 34.01 | 31.42 | 26.63 | 19.26 | 17.99 | 15.91 | | 9.52 | 16.83 | 22.14 | 20.56 | 28.59 | 21.37 | | 320.31 | 41.95 | 35.87 | 30.80 | 30.05 | 28.96 | | 29.12 | 38.36 | 32.51 | 27.54 | 27.87 | 27.07 | Notes of the table: 1. NBET and MOs are Nigeria Bulk Electricity Trader and Market Operators respectively; 2. N' Billion is billions of Nigeria Currency. Source: Nigerian Bulk Electricity Trading Plc, and Market Operator. * * * Key Statistics Table C.9: Summary of Collection and Remittance Performance by DisCos, 2017-20 | | Collection Efficiency(%) | | | | Percentage in Collection | | | --- | --- | --- | --- | --- | --- | --- | | DisCos | 2020 | 2019\* | 2018 | 2017 | 2020-19 | 2021 | | Abuja | 88.86 | 75.64 | 73.98 | 65.46 | 13.23 | | | Benin | 53.11 | 56.99 | 55.50 | 56.42 | -3.88 | | | Eko | 78.62 | 83.33 | 78.01 | 78.61 | -4.71 | | | Enugu | 64.08 | 72.63 | 70.95 | 57.79 | -8.55 | | | Ibadan | 61.09 | 62.93 | 61.71 | 64.94 | -1.84 | | | Ikeja | 78.92 | 86.33 | 84.16 | 82.13 | -7.41 | | | Jos | 56.99 | 55.21 | 45.55 | 35.18 | 1.78 | | | Kaduna | 37.69 | 40.80 | 43.25 | 36.67 | -3.11 | | | Kano | 64.37 | 68.51 | 59.22 | 47.51 | -4.14 | | | PH | 50.81 | 51.27 | 48.89 | 45.47 | -0.47 | | | Yola | 58.61 | 51.29 | 48.45 | 50.60 | 7.32 | | | All DisCos Total | 66.50 | 67.84 | 65.03 | 60.20 | -1.34 | | | All DisCos Average | 63.01 | 64.08 | 60.88 | 56.43 | -1.07 | | | The Point Change on Efficiency(%) | | Remittance Performance(%) | | | | Percentage point Change in Remittance Performance(%) | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | 2019-18\* | 2018-17 | 2020 | 2019 | 2018 | 2017 | 2020-19 | 2019-18 | 2018-17 | | 1.66 | 8.52 | 46.46 | 44.73 | 33.67 | 32.87 | 1.73 | 11.06 | 0.80 | | 1.49 | -0.92 | 42.51 | 33.31 | 33.67 | 34.37 | 9.20 | -0.36 | -0.70 | | 5.32 | -0.6 | 52.46 | 48.09 | 43.59 | 47.30 | 4.37 | 4.5 | -3.71 | | 1.68 | 13.16 | 43.20 | 30.96 | 34.01 | 31.69 | 12.24 | -3.05 | 2.32 | | 1.22 | -3.23 | 42.67 | 34.85 | 32.79 | 31.79 | 7.82 | 2.06 | 1.00 | | 2.17 | 2.03 | 54.03 | 45.52 | 44.61 | 39.69 | 8.51 | 0.91 | 4.92 | | 9.66 | 10.37 | 26.09 | 16.50 | 10.04 | 13.53 | 9.59 | 6.46 | -3.49 | | -2.45 | 6.58 | 30.82 | 23.56 | 14.53 | 15.63 | 7.26 | 9.03 | -1.10 | | 9.29 | 11.71 | 35.52 | 31.26 | 16.19 | 13.12 | 4.26 | 15.07 | 3.07 | | 2.38 | 3.42 | 31.42 | 26.63 | 19.26 | 17.99 | 4.79 | 7.37 | 1.27 | | 2.84 | -2.15 | 16.83 | 22.14 | 20.56 | 28.59 | -5.31 | 1.58 | -8.03 | | 2.81 | 4.83 | 41.95 | 35.87 | 30.80 | 30.05 | 6.08 | 5.07 | 0.75 | | 3.20 | 4.45 | 38.36 | 32.51 | 27.54 | 27.87 | 5.85 | 4.97 | -0.33 | Notes of the table: DisCos are the electricity distribution companies; - Indicates the values in the cell for Enugu, Yola and total DisCos are different from those reported in the 2019 report due to adjustment for errors detected. * * * D. Licence, Permit and Certification Table D.1: Generation Licences Issued and Renewed in 2020 | S/N | Applicants | Period of Approval | Licence Type | Location | Capacity (MW) | | --- | --- | --- | --- | --- | --- | | A. | Licence Issued | | | | | | 1 | LBL Power and gas Company Ltd | 2020/Q4 | Embedded | Ogun | 25.00 | | 2 | Kano Hydro & Energy | " | Embedded | Kano | 10.00 | | 3 | Constant Independent Power | 2020/Q4 | IEDN | Ogun | n/a | | 4 | Distribution Company Ltd | " | IEDN | Kano | n/a | | 5 | Central Electric & Utilities Ltd | 2020/Q4 | Off-grid | Ogun | 200.00 | | | Total Licence Issued | in 2020 | | | 235.00 | | B. | Licence Renewed | | | | | | 6 | Paras Energy and Natural | 2020/Q4 | On-grid | Ogun | 96.00 | | 7 | Resources Ltd(10-year Renewal) | " | On-grid | Abuja,FCT | 100.00 | | 8 | Enerlog Ltd(5-year Renewal) | " | On-grid | Delta | 150.00 | | | Total Licence Renewed | in 2019 | | | 346.00 | | C. | Licence Transferred | | | | | | 9 | Cummins Power Generation(Nig) Ltd | 2020/Q4 | Off-grid | CPGNL Ltd | 1 | | 10 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 11 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 12 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 13 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 14 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 15 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 16 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 17 | Cummins Power Generation(Nig) Ltd | " | Off-grid | CPGNL Ltd | 1 | | 18 | Coronation Utility Iganmu Ltd | " | Off-grid | CPGNL Ltd | 1 | | 19 | Shares of Aura Energy Ltd(in Jos DisCo) | " | Distribution | Highland Disco Acquisition Ltd | N/A | | | Total Licence Transferred | in 2020 | | | 10 | | | Grand Total Licence Granted&Renewed | in 2020 | | | 581MW | Notes of the table: IEDN is an acronym for an Independent Electricity Distribution Network Source: Nigerian Electricity Regulatory Commission * * * Key Statistics Table D.2: Grant of Permit for Captive Power Generation Issued in 2020 | S/N | Applicants | | --- | --- | | A. | Permit Issued | | 1 | Uraga Power Solutions Limited | | 2 | Uraga Power Solutions Limited | | 3 | African Fertilizer & Chemicals Nigeria Ltd | | 4 | Ashtavinayak Hydrocarbon Ltd | | 5 | CEPLAS Industries FZE | | 6 | UMZA International Farms Ltd | | 7 | Vinylon Footwear Industry Ltd | | 8 | Viva Metal Ltd | | 9 | Palladium Mining Ltd | | | Total Permit Issued | | | | Licence Type | Location | Capacity (MW) | | --- | --- | --- | --- | --- | | United | 2020/Q1 | CPG | Lagos | 30.00 | | " | CPG | Lagos | 5.00 | | | " | CPG | Ogun | 10.00 | | | 2020/Q3 | CPG | Delta | 7.50 | | | " | CPG | Ogun | 6.00 | | | " | CPG | Kano | 1.50 | | | 2020/Q4 | CPG | Jigawa | 6.00 | | | " | CPG | Kano | 18.00 | | | " | CPG | Ebonyi | 2.70 | | | in 2020 | | | 86.70 | | Notes of the table: CPG is an acronym for Captive Power Generation Source: Nigerian Electricity Regulatory Commission Table D.3: Mini-Grid Registrations and Permits Approved in 2020 | S/N | Applicants | Location(State) | Mini Type | Period ofApproval | Grant | | --- | --- | --- | --- | --- | --- | | 1. | AY Global IntegratedServices | Paikoro LGA,Niger State | Isolated | 2020/Q2 | Registration | | 2. | GVE Projects Limited | AMAC,FCT Abuja | Interconnected | “ | Permit | | 3. | Renewvia Solar Nigeria Limited | | Isolated | 2020/Q3 | Registration | | 4. | Renewvia Solar Nigeria Limited | | interconnected | “ | Permit | Source: Nigerian Electricity Regulatory Commission * * * Table D.4: Certification of Meter Assets Providers as at 2020 | S/N | Name of Applicants | | --- | --- | | 1. | Turbo Energy Limited | | 2. | Mojec Asset Management Company | | 3. | Meron Nigeria Limited | | 4. | Sabrud Consortium Nigeria Limited | | 5. | Inlaks Power Solution | | 6. | FLT Energy Systems Limited | | 7. | G-Unit Engineering Limited | | 8. | Turbo Energy Limited | | 9. | Bendoricks International Limited | | 10. | Gospell Digital Technology Limited | | 11. | Integrated Resources Limited | | 12. | Mojec Asset Management Company | | 13. | Protogy Global Services Limited | | 14. | Mojec Asset Management Company | | 15. | Protogy Global Services Limited | | 16. | MOMAS Meters Manufacturing Com | | 17. | Tinuten Nigeria Limited | | 18. | Mojec Asset Management Company | | 19. | CWG Plc. | | 20. | CIG Metering Assets Nigeria Limited | | 21. | New Hampshire Capital Limited | | 22. | Triple Seventh Nigeria Limited & Mojec International Limited | | 23. | Cresthill Engineering Limited | | 24. | Holley Metering Limited | | 25. | Integrated Power Limited | | 26. | Ziklagsis Networks Limited | | 27. | Turbo Energy Limited | | 28. | Cresthill Engineering Limited | | 29. | Tis&P Dynamics Solution Limited | | 30. | Armese Consulting Limited | | 31. | Holley Metering Limited | | 32. | Chris Ejik International Agencies Limit | | 33. | Ziklagsis Networks Limited | | | DisCo Serving | Date of Issue | | --- | --- | --- | | Limited | Abuja | 5/7/2019 | | Abuja | 21/10/2019 | | | Abuja | 21/10/2019 | | | Benin | 5/7/2019 | | | Benin | 5/7/2019 | | | Benin | 5/7/2019 | | | Benin | 15/7/2019 | | | Eko | 5/7/2019 | | | Eko | 9/7/2019 | | | Eko | 9/7/2019 | | | Eko | 10/7/2019 | | | Limited | Eko | 21/10/2019 | | Enugu | 15/7/2019 | | | Limited | Enugu | 21/10/2019 | | Ibadan | 9/7/2019 | | | Oany Limited | Ibadan | 10/7/2019 | | Ibadan | 12/7/2019 | | | Limited | Ibadan | 21/10/2019 | | Ibadan | 7/1/2020 | | | Ikeja | 5/7/2019 | | | Ikeja | 10/7/2019 | | | Jos | 17/7/2019 | | | | Kaduna | 21/10/2019 | | Kaduna | 10/2/2020 | | | Kaduna | 10/2/2020 | | | Kaduna | 14/12/2020 | | | Kaduna | 24/12/2020 | | | Kano | 10/2/2020 | | | Kano | 29/01/2021 | | | P/Harcourt | 5/7/2019 | | | P/Harcourt | 9/7/2019 | | | ed | Yola | 19/8/2019 | | Yola | 7/6/2020 | | Source: Nigerian Electricity Regulatory Commission * * * Key Statistics Table D.5: Certification of Meter Service Providers in 2020 | S/N | Applicant | | --- | --- | | A. | Meter Importers | | 1 | Tripple Seventh Nigeria Limited | | 2 | AR-Rahman Technical Service Nigeria | | 3 | Tradark Electric Nigeria Limited | | 4 | MBH Power Limited | | 5 | Bendoricks International Limited | | B. | Meter Vendors | | 6 | Chris Ejik International Limited | | C. | Meter Installers | | 7 | A1 Power Technologies Limited | | 8 | Tripple Seventh Nigeria Limited | | 9 | Saleswaya Nigeria Limited | | 10 | Omelus Integrated Solutions Limited | | 11 | EEL-ESS Global Resources Nigeria Lin | | 12 | Goldengate Options Nigeria Limited | | 13 | Willares Engineering Certificate | | 14 | Cenave Integrated Services Limited | | D. | Meter Manufacturers | | 15 | Metering Solutions Manufacturing Se | | 16 | Smart Meter Company Limited | | 17 | Turbo Energy Limited | | | Total MSP Certified in Nigeria | | | Period of Application | Certification Class | | --- | --- | --- | | Ria Ltd | 2020/Q1 | Meter Importer | | 2020/Q1 | Meter Importer | | | 2020/Q1 | Meter Importer | | | 2020/Q3 | Meter Importer | | | 2020/Q4 | Meter Importer | | | | | | | | 2020/Q4 | Meter Vendor | | United | 2020/Q1 | Meter Installer(B1) | | 2020/Q1 | Meter Installer(A1) | | | 2020/Q1 | Meter Installer(C1) | | | 2020/Q3 | Meter Installer(A1) | | | 2020/Q3 | Meter Installer(A1) | | | 2020/Q4 | Meter Installer(A1) | | | 2020/Q4 | Meter Installer(A1) | | | Services Ltd | 2020/Q1 | Meter Manufacturer | | 2020/Q4 | Meter Manufacturer | | | 2020/Q4 | Meter Manufacturer | | | in 2020 | Importers:5Vendor:1Installer:8Manufacturer:3 | | Source: Nigerian Electricity Regulatory Commission Table D.6: Renewal of Meter Service Providers Certifications in 2020 | S/N | Applicants | Period of Renewal | Certification Class | | --- | --- | --- | --- | | 1. | Armese Consulting Limited (Renewal) | 2020/Q4 | Meter Installer | | 2. | Helbon Associates Limited (Renewal) | " | Meter Installer | Source: Nigerian Electricity Regulatory Commission * * * E. Consumer Enlightenment, Metering and Complaints Table E.1: Registered, Metered & Unmetered Customers by DisCos, 2017-20 | | I | | | | --- | --- | --- | --- | | DisCos | 2020Q1:As at 31 March | | 2020Q2As at 31 J | | Registered customers | % Share | Registered Customers | | | Abuja | 1,271,563 | 12.14 | 1,277,921 | | Benin | 1,022,458 | 9.76 | 1,027,570 | | Eko | 518,192 | 4.95 | 520,783 | | Enugu | 1,100,292 | 10.50 | 1,105,793 | | Ibadan | 2,139,741 | 20.42 | 2,150,440 | | Ikeja | 1,145,622 | 10.93 | 1,145,622 | | Jos | 537,726 | 5.13 | 540,415 | | Kaduna | 675,059 | 6.44 | 678,434 | | Kano | 699,618 | 6.68 | 699,618 | | Port Harcourt | 985,782 | 9.41 | 985,782 | | Yola | 381,803 | 3.64 | 383,712 | | Total DisCos | 10,477,856 | 100.00 | 10,516,090 | | Registered Customers(RC)byDisCos | | | | | | --- | --- | --- | --- | --- | | June | 2020Q3: | | 2020Q4: | | | As at 31September | | As at 31December | | | | %Share | Registered customers | %Share | Registered customers | %Share | | 12.15 | 1,468,404 | 12.40 | 1,468,404 | 12.40 | | 9.77 | 1,180,650 | 9.97 | 1,180,650 | 9.97 | | 4.95 | 541,560 | 4.57 | 541,560 | 4.57 | | 10.52 | 1,183,093 | 9.99 | 1,183,093 | 9.99 | | 20.45 | 2,907,214 | 24.55 | 2,907,214 | 24.55 | | 10.89 | 1,145,622 | 9.67 | 1,145,622 | 9.67 | | 5.14 | 598,430 | 5.05 | 598,430 | 5.05 | | 6.45 | 721,436 | 6.09 | 721,436 | 6.09 | | 6.65 | 699,618 | 5.91 | 699,618 | 5.91 | | 9.37 | 985,782 | 8.32 | 985,782 | 8.32 | | 3.65 | 410,010 | 3.46 | 410,010 | 3.46 | | 100.00 | 11,841,819 | 100.00 | 11,841,819 | 100.00 | | DisCos | 2020Q1:As at 31 March | | 2020Q1As at 31 | | --- | --- | --- | --- | | Metered customers | As % of RC | Metered Customers | | | 670,485 | 52.73 | 671,822 | | | Abuja | 670,485 | 52.73 | 671,822 | | Benin | 554,443 | 54.23 | 555,174 | | Eko | 262,752 | 50.71 | 263,503 | | Enugu | 493,509 | 44.85 | 493,509 | | Ibadan | 794,136 | 37.11 | 794,136 | | Ikeja | 520,859 | 45.47 | 520,859 | | Jos | 170,989 | 31.80 | 170,989 | | Kaduna | 159,322 | 23.60 | 159,322 | | Kano | 147,682 | 21.11 | 147,682 | | Port Harcourt | 379,729 | 38.52 | 379,729 | | Yola | 78,034 | 20.44 | 78,034 | | Total DisCos | 4,231,940 | 40.39 | 4,234,759 | | June | 2020Q3：As at 31 September | | 2020Q4：As at 31 December | | | --- | --- | --- | --- | --- | | Metered customers | As % of RC | Metered customers | As % of RC | | | 52.57 | 707,534 | 48.18 | 707,534 | 48.18 | | 54.03 | 571,600 | 48.41 | 571,600 | 48.41 | | 50.60 | 286,847 | 52.97 | 286,847 | 52.97 | | 44.63 | 505,136 | 42.70 | 505,136 | 42.70 | | 36.93 | 807,573 | 27.78 | 807,573 | 27.78 | | 45.47 | 562,837 | 49.13 | 562,837 | 49.13 | | 31.64 | 172,627 | 28.85 | 172,627 | 28.85 | | 23.48 | 232,405 | 32.21 | 232,405 | 32.21 | | 21.11 | 352,493 | 50.38 | 352,493 | 50.38 | | 38.52 | 387,025 | 39.26 | 387,025 | 39.26 | | 20.34 | 80,114 | 19.54 | 80,114 | 19.54 | | 40.27 | 4,666,191 | 39.40 | 4,666,191 | 39.40 | Notes of the table: | DisCos | 2020Q1:As at 31 March | | 2020Q1:As at 31 | | --- | --- | --- | --- | | Unmetered customers | As % of RC | Unmetered Customers | | | Abuja | 601,078 | 47.27 | 606,099 | | Benin | 468,015 | 45.77 | 472,396 | | Eko | 255,440 | 49.29 | 257,280 | | Enugu | 606,783 | 55.15 | 612,284 | | Ibadan | 1,345,605 | 62.89 | 1,356,304 | | Ikeja | 624,763 | 54.53 | 624,763 | | Jos | 366,737 | 68.20 | 369,426 | | Kaduna | 515,737 | 76.40 | 519,112 | | Kano | 551,936 | 78.89 | 551,936 | | Port Harcourt | 606,053 | 61.48 | 606,053 | | Yola | 303,769 | 79.56 | 305,678 | | Total DisCos | 6,245,916 | 59.61 | 6,281,331 | | June | 2020Q3： | | 2020Q4： | | | --- | --- | --- | --- | --- | | As at 31 September | | As at 31 December | | | | As % of RC | Unmetered customers | As % of RC | Unmetered customers | As % of RC | | 47.43 | 760,870 | 51.82 | 760,870 | 51.82 | | 45.97 | 609,050 | 51.59 | 609,050 | 51.59 | | 49.40 | 254,713 | 47.03 | 254,713 | 47.03 | | 55.37 | 677,957 | 57.30 | 677,957 | 57.30 | | 63.07 | 2,099,641 | 72.22 | 2,099,641 | 72.22 | | 54.53 | 582,785 | 50.87 | 582,785 | 50.87 | | 68.36 | 425,803 | 71.15 | 425,803 | 71.15 | | 76.52 | 489,031 | 67.79 | 489,031 | 67.79 | | 78.89 | 347,125 | 49.62 | 347,125 | 49.62 | | 61.48 | 598,757 | 60.74 | 598,757 | 60.74 | | 79.66 | 329,896 | 80.46 | 329,896 | 80.46 | | 59.73 | 7,175,628 | 60.60 | 7,175,628 | 60.60 | 1. RC denotes registered customers; Total DisCos is the eleven (11) electricity distribution companies altogether 2. % Share is the ratio of the registered customer in a month by a DisCo to the registered customers by all DisCos Source: Computed by the Nigerian Electricity Regulatory Commission based on data sourced from the DisCos * * * Table E.1: Cont'd: Registered, Metered & Unmetered Customers by DisCos | DisCos | 2019Q1:As at 31 March | | 2019Q1:As at 31 March | | --- | --- | --- | --- | | Registered customers | % Share | Registered customers | | | Abuja | 1,080,637 | 12.22 | 1,097,279 | | Benin | 970,000 | 10.97 | 970,000 | | Eko | 493,639 | 5.58 | 493,639 | | Enugu | 985,112 | 11.14 | 985,112 | | Ibadan | 1,779,751 | 20.13 | 1,779,751 | | Ikeja | 972,589 | 11.00 | 972,589 | | Jos | 486,198 | 5.50 | 510,198 | | Kaduna | 673,848 | 7.62 | 673,848 | | Kano | 529,114 | 5.98 | 529,114 | | Port Harcourt | 523,693 | 5.92 | 523,693 | | Yola | 346,220 | 3.92 | 346,220 | | Total DisCos | 8,840,801 | 100.00 | 8,881,443 | | DisCos | Met | | | | 2019Q1:As at 31 March | | 2019Q1:As at 31 March | | | DisCos | Metered customers | As % of RC | Metered customers | | Abuja | 568,180 | 52.58 | 574,743 | | Benin | 548,261 | 56.52 | 548,261 | | Eko | 239,559 | 48.53 | 239,559 | | Enugu | 429,623 | 43.61 | 438,471 | | Ibadan | 687,652 | 38.64 | 687,652 | | Ikeja | 447,299 | 45.99 | 449,639 | | Jos | 170,409 | 35.05 | 170,492 | | Kaduna | 149,588 | 22.20 | 149,588 | | Kano | 126,539 | 23.92 | 126,539 | | Port Harcourt | 355,205 | 67.83 | 355,205 | | Yola | 71,580 | 20.67 | 71,580 | | Total DisCos | 3,793,895 | 42.91 | 3,811,729 | | DisCos | Unmetered | | | | Unmetered customers | As % of RC | Unmetered customers | | | Abuja | 512,457 | 47.42 | 522,536 | | Benin | 421,739 | 43.48 | 421,739 | | Eko | 254,080 | 51.47 | 254,080 | | Enugu | 555,489 | 56.39 | 546,641 | | Ibadan | 1,092,099 | 61.36 | 1,092,099 | | Ikeja | 525,290 | 54.01 | 522,950 | | Jos | 315,789 | 64.95 | 339,706 | | Kaduna | 524,260 | 77.80 | 524,260 | | Kano | 402,575 | 76.08 | 402,575 | | Port Harcourt | 168,488 | 32.17 | 168,488 | | Yola | 274,640 | 79.33 | 274,640 | | Total DisCos | 5,046,906 | 57.09 | 5,069,714 | | Registered Customers (RC) by DisCos | | | | | | | --- | --- | --- | --- | --- | --- | | June | 2019Q3:As at 31 September | | 2019Q4:As at 31 December | | | | % Share | Registered customers | % Share | Registered customers | % Share | | | 12.35 | 1,164,748 | 12.04 | 1,228,288 | 11.84 | | | 10.92 | 1,001,821 | 10.36 | 1,022,458 | 9.86 | | | 5.56 | 504,225 | 5.21 | 518,192 | 4.99 | | | 11.09 | 1,075,626 | 11.12 | 1,100,292 | 10.61 | | | 20.04 | 2,090,781 | 21.61 | 2,139,741 | 20.62 | | | 10.95 | 996,769 | 10.30 | 1,145,622 | 11.04 | | | 5.74 | 512,108 | 5.29 | 537,726 | 5.18 | | | 7.59 | 673,848 | 6.97 | 673,848 | 6.50 | | | 5.96 | 516,947 | 5.34 | 689,304 | 6.64 | | | 5.90 | 761,105 | 7.87 | 937,305 | 9.03 | | | 3.90 | 376,751 | 3.89 | 381,803 | 3.68 | | | 100.00 | 9,674,729 | 100.00 | 10,374,579 | 100.00 | | 1. RC denotes registered customers; Total DisCos is the eleven (11) electricity distribution companies altogether 2. % Share is the ratio of the registered customer in a month by a DisCo to the registered customers by all DisCos Source: Computed by the Nigerian Electricity Regulatory Commission based on data sourced from the DisCos * * * Table E.1: Cont'd: Registered, Metered & Unmetered Customers by DisCos | DisCos | 2018Q1:As at 31 March | | | 2018GAs at 31 | | --- | --- | --- | --- | --- | | Registered customers | % Share | Registered customers | | | | 1,129,521 | 13.88 | 967,667 | | | | 856,292 | 10.53 | 856,292 | | | | 470,766 | 5.79 | 470,766 | | | | 884,992 | 10.88 | 884,992 | | | | 1,613,635 | 19.83 | 1,613,635 | | | | 910,338 | 11.19 | 910,338 | | | | Jos | 486,198 | 5.98 | 486,198 | | | Kaduna | 484,310 | 5.95 | 484,310 | | | Kano | 508,640 | 6.25 | 508,640 | | | Port Harcourt | 453,818 | 5.58 | 453,818 | | | Yola | 337,220 | 4.14 | 337,220 | | | Total DisCos | 8,135,730 | 100.00 | 7,973,876 | | | DisCos | Metere | | | Metere | | 2018Q1:As at 31 March | | | 2018GAs at 31 | | | Metered customers | As % of RC | Metered customers | | | | 430,098 | 38.08 | 526,120 | | | | 544,828 | 63.63 | 548,261 | | | | 215,987 | 45.88 | 235,038 | | | | 409,748 | 46.30 | 312,385\* | | | | 665,609 | 41.25 | 687,652 | | | | 311,332 | 34.20 | 447,299 | | | | Jos | 170,409 | 35.05 | 170,409 | | | Kaduna | 136,037 | 28.09 | 136,037 | | | Kano | 126,539 | 24.88 | 101,732\* | | | Port Harcourt | 352,533 | 77.68 | 310,616\* | | | Yola | 70,883 | 21.02 | 71,580 | | | Total DisCos | 3,434,003 | 42.21 | 3,547,129 | | | DisCos | Unmeter | | | Unmeter | | 2018Q1:As at 31 March | | | 2018GAs at 31 | | | Unmetered customers | As % of RC | Unmetered customers | | | | 699,423 | 61.92 | 1,361,248 | | | | 311,464 | 36.37 | 308,031 | | | | 254,779 | 54.12 | 235,728 | | | | 475,244 | 53.70 | 572,607 | | | | 948,026 | 58.75 | 925,983 | | | | Ikeja | 599,006 | 65.80 | 463,039 | | | Jos | 315,789 | 64.95 | 315,789 | | | Kaduna | 348,273 | 71.91 | 348,273 | | | Kano | 382,101 | 75.12 | 406,908 | | | Port Harcourt | 101,285 | 22.32 | 143,202 | | | Yola | 266,337 | 78.98 | 265,640 | | | Total DisCos | 4,701,727 | 57.79 | 5,346,448 | | | Customers (RC) by DisCos | | | | | | | --- | --- | --- | --- | --- | --- | | June | 2018Q3: | | 2018Q4: | | | | As at 31 September | % Share | Registered customers | % Share | | | | % Share | Registered customers | % Share | Registered customers | % Share | | | 12.14 | 973,926 | 11.72 | 983,496 | 11.40 | | | 10.74 | 888,143 | 10.69 | 920,190 | 10.66 | | | 5.90 | 496,442 | 5.97 | 494,888 | 5.73 | | | 11.10 | 938,311 | 11.29 | 982,155 | 11.38 | | | 20.24 | 1,693,346 | 20.38 | 1,779,751 | 20.62 | | | 11.42 | 910,465 | 10.96 | 998,673 | 11.57 | | | 6.10 | 486,580 | 5.86 | 520,585 | 6.03 | | | 6.07 | 543,654 | 6.54 | 589,810 | 6.83 | | | 6.38 | 508,943 | 6.12 | 495,522 | 5.74 | | | 5.69 | 524,255 | 6.31 | 506,488 | 5.87 | | | 4.23 | 346,342 | 4.17 | 358,982 | 4.16 | | | 100.00 | 8,310,408 | 100.00 | 8,630,540 | 100.00 | | Notes of the table: 1. RC denotes registered customers; Total DisCos is the eleven (11) electricity distribution companies altogether 2. % Share is the ratio of the registered customer in a month by a DisCo to the registered customers by all DisCos - Indicates that the number of metered customers is less than the number recorded in the preceding quarter due to the decommissioning of faulty, outdated and tempered meters. Source: Computed by the Nigerian Electricity Regulatory Commission based on data sourced from the DisCos * * * Table E.1: Cont'd: Registered, Metered & Unmetered Customers by DisCos | DisCos | Registered | | | | --- | --- | --- | --- | | 2017Q1:As at 31 March | | 2017Q1As at 31 | | | Registered customers | % Share | Registered Customers | | | 913,507 | 12.10 | 930,004 | | | 789,287 | 10.45 | 809,937 | | | 447,748 | 5.93 | 452,251 | | | 834,908 | 11.06 | 825,050 | | | 1,512,764 | 20.03 | 1,546,170 | | | Abuja | 913,507 | 12.10 | 930,004 | | Benin | 789,287 | 10.45 | 809,937 | | Eko | 447,748 | 5.93 | 452,251 | | Enugu | 834,908 | 11.06 | 825,050 | | Ibadan | 1,512,764 | 20.03 | 1,546,170 | | Ikeja | 863,408 | 11.43 | 885,721 | | Jos | 446,994 | 5.92 | 466,044 | | Kaduna | 462,923 | 6.13 | 472,827 | | Kano | 492,783 | 6.53 | 503,915 | | Port Harcourt | 476,893 | 6.32 | 429,576 | | Yola | 309,645 | 4.10 | 319,217 | | Total DisCos | 7,550,860 | 100.00 | 7,640,712 | | DisCos | Meteor | | | | 2017Q1:As at 31 March | | 2017Q1As at 31 | | | Metered customers | As % of RC | Metered Customers | | | 386,588 | 42.32 | 397,307 | | | 476,558 | 60.38 | 476,952 | | | 234,972 | 52.48 | 236,983 | | | 387,928 | 46.46 | 389,484 | | | 608,671 | 40.24 | 619,163 | | | Ikeja | 446,616 | 51.73 | 447,019 | | Jos | 126,703 | 28.35 | 126,703 | | Kaduna | 271,428 | 58.63 | 277,949 | | Kano | 114,041 | 23.14 | 119,147 | | Port Harcourt | 196,465 | 41.20 | 195,243 | | Yola | 68,530 | 22.13 | 68,636 | | Total DisCos | 3,318,500 | 43.95 | 3,354,586 | | DisCos | Unmeteor | | | | 2017Q1:As at 31 March | | 2017Q1As at 31 | | | Unmetered customers | As % of RC | Unmetered Customers | | | 526,919 | 57.68 | 532,697 | | | 312,729 | 39.62 | 332,985 | | | 212,776 | 47.52 | 215,268 | | | 446,980 | 53.54 | 435,566 | | | 904,093 | 59.76 | 927,007 | | | Ikeja | 416,792 | 48.27 | 438,702 | | Jos | 320,291 | 71.65 | 339,341 | | Kaduna | 191,495 | 41.37 | 194,878 | | Kano | 378,742 | 76.86 | 384,768 | | Port Harcourt | 280,428 | 58.80 | 234,333 | | Yola | 241,115 | 77.87 | 250,581 | | Red Customers (RC) by DisCos | | | | | | | --- | --- | --- | --- | --- | --- | | June | | 2017Q3: As at 31 September | | 2017Q4: As at 31 December | | | % Share | Registered customers | % Share | Registered customers | % Share | | | 12.17 | 928,393 | 11.99 | 966,192 | 12.16 | | | 10.60 | 831,943 | 10.74 | 853,587 | 10.74 | | | 5.92 | 461,183 | 5.96 | 471,013 | 5.93 | | | 10.80 | 837,559 | 10.82 | 840,208 | 10.57 | | | 20.24 | 1,581,767 | 20.43 | 1,613,635 | 20.30 | | | 11.59 | 906,480 | 11.71 | 927,672 | 11.67 | | | 6.10 | 472,266 | 6.10 | 478,698 | 6.02 | | | 6.19 | 466,122 | 6.02 | 500,476 | 6.30 | | | 6.60 | 487,898 | 6.30 | 506,638 | 6.38 | | | 5.62 | 440,542 | 5.69 | 453,818 | 5.71 | | | 4.18 | 328,920 | 4.25 | 335,184 | 4.22 | | | 100.00 | 7,743,073 | 100.00 | 7,947,121 | 100.00 | | Notes of the table: 1. RC denotes registered customers; Total DisCos is the eleven (11) electricity distribution companies altogether 2. % Share is the ratio of the registered customer in a month by a DisCo to the registered customers by all DisCos - Indicates that the number of metered customers is less than the number recorded in the preceding quarter due to the decommissioning of faulty, outdated and tempered meters. Source: Computed by the Nigerian Electricity Regulatory Commission based on data sourced from the DisCos * * * Table E.2: Summary of Customers Metering Status by DisCos, 2018-20 | DisCos | Registered Customer As at December 2020 | Registered Customer As at December 2019 | Registered Customer As at December 2018 | Metered Customer As at December 2020 | Metered Customer As at December 2019 | Metered Customer As at December 2018 | | --- | --- | --- | --- | --- | --- | --- | | Abuja | 1,468,404 | 1,228,288 | 1,097,279 | 707,534 | 641,738 | 568,180 | | Benin | 1,180,650 | 1,022,458 | 970,000 | 571,600 | 553,394 | 548,261 | | Eko | 541,560 | 518,192 | 496,442 | 286,847 | 255,880 | 239,559 | | Enugu | 1,183,093 | 1,100,292 | 985,112 | 505,136 | 476,955 | 429,623 | | Ibadan | 2,907,214 | 2,139,741 | 1,779,751 | 807,573 | 783,878 | 687,652 | | Ikeja | 1,145,622 | 1,145,622 | 972,589 | 562,837 | 488,917 | 447,299\* | | Jos | 598,430 | 537,726 | 486,580 | 172,627 | 170,522 | 170,409 | | Kaduna | 721,436 | 673,848 | 543,654 | 232,405 | 157,576 | 149,588\* | | Kano | 699,618 | 689,304 | 529,114 | 352,493 | 147,104 | 126,539\* | | Port Harcourt | 985,782 | 937,305 | 524,255 | 387,025 | 374,793 | 355,205 | | Yola | 410,010 | 381,803 | 346,342 | 80,114 | 78,034 | 71,580 | | Total | 11,841,819 | 10,374,579 | 8,731,118 | 4,666,191 | 4,128,791 | 3,793,895 | | Metered Customer Pre-privatization Policy | DisCos/BPE Pledge on Metering per Annum | Metering Pledge Gaps in 2020 | Metering Pledge Gaps in 2019 | Metering Pledge Gaps in 2018 | Total Metering Gap as at December 2020 | | --- | --- | --- | --- | --- | --- | | 392,488 | 150,000 | 84,204 | 76,442 | 43,868 | 760,870 | | 425,308 | 264,000 | 245,794 | 258,867 | 194,057 | 609,050 | | 189,542 | 204,000 | 173,033 | 187,679 | 197,293 | 254,713 | | 218,718 | 48,000 | 19,819 | 668 | 12,874 | 677,957 | | 413,297 | 217,611 | 193,916 | 121,385 | 206,519 | 2,099,641 | | 391,724 | 120,000 | 46,080 | 78,382 | 126,083 | 582,785 | | 168,046 | 100,000 | 97,895 | 99,887 | 71,363 | 425,803 | | 175,275 | 187,200 | 112,371 | 179,212 | 329,204 | 489,031 | | 146,329 | 100,000 | (105,389) | 79,435 | 106,776 | 347,125 | | 199,501 | 252,000 | 239,768 | 232,412 | 136,666 | 598,757 | | 61,599 | 51,600 | 49,520 | 45,146 | 49,470 | 329,896 | | 2,781,827 | 1,694,411 | 1,157,011 | 1,359,515 | 1,474,173 | 7,175,628 | Notes of the table: 1. DisCos are Electricity Distribution Companies 2. Total DisCos is the eleven (11) electricity distribution companies altogether 3. BPE is the Bureau of Public Enterprise - indicates a decline from the preceding year due to decommissioning of faulty and expired meters Source: Nigerian Electricity Regulatory Commission and Electricity Distribution Companies * * * Table E.3: Quarterly Complaints Received & Resolved by DisCos, 2016-20 | | 2020/Q1 | | | 2020/Q2 | | | | --- | --- | --- | --- | --- | --- | --- | | | Customers' Complaints: | | | Customers' Complaints: | | | | DisCos | Received | Resolved | Pending | Received | Resolved | Pending | | Abuja | 27,519 | 26,860 | 659 | 20,109 | 19,761 | 348 | | Benin | 11,604 | 9,966 | 1,638 | 9,282 | 7,751 | 1,531 | | Eko | 25,560 | 22,198 | 3,362 | 25,441 | 22,148 | 3,293 | | Enugu | 57,835 | 55,690 | 2,145 | 63,230 | 61,460 | 1,770 | | Ibadan | 9,021 | 6,927 | 2,094 | 7,818 | 6,324 | 1,494 | | Ikeja | 39,415 | 35,930 | 3,485 | 37,830 | 34,471 | 3,359 | | Jos | 5,270 | 4,816 | 454 | 4,460 | 4,222 | 238 | | Kaduna | 8,078 | 7,655 | 423 | 7,529 | 7,003 | 526 | | Kano | 6,899 | 6,711 | 188 | 6,456 | 6,333 | 123 | | P/H | 11,370 | 10,062 | 1,308 | 18,606 | 17,883 | 723 | | Yola | 1,935 | 1,934 | 1 | 2,355 | 2,328 | 27 | | DisCos Average | 18,591 | 17,159 | 1,432 | 18,465 | 17,244 | 1,221 | | DisCos Total | 204,506 | 188,749 | 15757 | 203,116 | 189,684 | 13432 | | 2020/Q3 | | | | 2020/Q4 | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | | Customers' Complaints: | | | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | 23,531 | 23,035 | 496 | 41,841 | 39,806 | 2,035 | 113,000 | 109,462 | 3,538 | | 14,929 | 12,665 | 2,264 | 15,140 | 12,907 | 2,233 | 50,955 | 43,289 | 7,666 | | 26,032 | 23,300 | 2,732 | 27,177 | 25,244 | 1,933 | 104,210 | 92,890 | 11,320 | | 54,223 | 53,446 | 777 | 52,966 | 52,056 | 910 | 228,254 | 222,652 | 5,602 | | 9,717 | 7,526 | 2,191 | 7,708 | 6,435 | 1,273 | 34,264 | 27,212 | 7,052 | | 39,831 | 36,248 | 3,583 | 35,741 | 32,100 | 3,641 | 152,817 | 138,749 | 14,068 | | 5,936 | 5,717 | 219 | 11,530 | 10,635 | 895 | 27,196 | 25,390 | 1,806 | | 8,329 | 7,803 | 526 | 6,422 | 5,493 | 929 | 30,358 | 27,954 | 2,404 | | 7,437 | 7,279 | 158 | 8,305 | 8,152 | 153 | 29,097 | 28,475 | 622 | | 26,848 | 25,699 | 1,149 | 22,224 | 21,706 | 518 | 79,048 | 75,350 | 3,698 | | 2,176 | 2,145 | 31 | 1,443 | 1,406 | 37 | 7,909 | 7,813 | 96 | | 19,908 | 18,624 | 1,284 | 20,954 | 19,631 | 1,323 | 77,919 | 72,658 | 5,261 | | 218,989 | 204,863 | 14126 | 230,497 | 215,940 | 14,557 | 857,108 | 799,236 | 57,872 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies (DisCos) altogether Source: DisCos. * * * Table E.3 Cont'd: Quarterly Complaints Received and Resolved by DisCos in 2016-2020 | DisCos | 2019/Q1 | | | 2019/Q2 | | | | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | | | Received | Resolved | Pending | Received | Resolved | Pending | | | 14,168 | 11,444 | 2,724 | 11,959 | 9,682 | 2,277 | | | Abuja | 14,168 | 11,444 | 2,724 | 11,959 | 9,682 | 2,277 | | Benin | 15,404 | 11,970 | 3,434 | 13,673 | 11,598 | 2,075 | | Eko | 26,442 | 26,333 | 109 | 17,722 | 15,821 | 1,901 | | Enugu | 21,317 | 18,832 | 2,485 | 30,104 | 28,989 | 1,115 | | Ibadan | 9,893 | 6,564 | 3,329 | 9,067 | 6,948 | 2,119 | | Ikeja | 30,171 | 26,475 | 3,696 | 29,778 | 25,462 | 4,316 | | Jos | 5,464 | 5,150 | 314 | 5,378 | 4,841 | 537 | | Kaduna | 11,862 | 9,630 | 2,232 | 9,486 | 7,790 | 1,696 | | Kano | 5,965 | 5,681 | 284 | 6,065 | 5,667 | 398 | | P/H | 9,135 | 8,082 | 1,053 | 10,415 | 8,941 | 1,474 | | Yola | 2,117 | 2,098 | 19 | 2,312 | 2,286 | 26 | | DisCos Average | 13,813 | 12,024 | 1,789 | 13,269 | 11,639 | 1,630 | | DisCos Total | 151,938 | 132,259 | 19,679 | 145,959 | 128,025 | 17,934 | | 2019/Q3 | | | 2019/Q4 | | | 2019 | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | Customers' Complaints: | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | 16,354 | 12,165 | 4,189 | 19,631 | 17,106 | 2,525 | 62,112 | 50,397 | 11,715 | | 10,517 | 9,754 | 766 | 10,665 | 9,322 | 1,343 | 50,259 | 42,644 | 7,618 | | 16,223 | 13,977 | 2,193 | 17,713 | 14,797 | 2,916 | 78,100 | 70,928 | 7,119 | | 56,249 | 45,879 | 10,370 | 47,209 | 45,672 | 1,537 | 154,879 | 139,372 | 15,507 | | 8,657 | 6,006 | 2,651 | 7,772 | 5,757 | 2,098 | 35,389 | 25,275 | 10,197 | | 27,853 | 24,138 | 3,715 | 35,256 | 31,804 | 3,405 | 123,058 | 107,879 | 15,132 | | 4,624 | 4,294 | 330 | 5,852 | 5,337 | 515 | 21,318 | 19,622 | 1,696 | | 9,364 | 9,008 | 356 | 9,662 | 9,340 | 322 | 40,374 | 35,768 | 4,606 | | 4,988 | 4,684 | 304 | 6,481 | 6,242 | 239 | 23,499 | 22,274 | 1,225 | | 15,688 | 14,116 | 1,572 | 15,603 | 13,535 | 2,068 | 50,841 | 44,674 | 6,167 | | 2,316 | 2,305 | 14 | 1,963 | 1,930 | 33 | 8,708 | 8,619 | 92 | | 15,712 | 13,302 | 2,405 | 16,164 | 14,622 | 1,546 | 58,958 | 51,587 | 7,370 | | 172,833 | 146,326 | 26,460 | 177,807 | 160,842 | 17,001 | 648,537 | 567,452 | 81,074 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies (DisCos) altogether Source: DisCos. * * * Table E.3 Cont'd: Quarterly Complaints Received and Resolved by DisCos in 2016-2020 | DisCos | 2018/Q1 | | | 2018/Q2 | | | | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | | | Received | Resolved | Pending | Received | Resolved | Pending | | | 11,525 | 10,468 | 1,057 | 12,486 | 11,319 | 1,167 | | | Abuja | 11,525 | 10,468 | 1,057 | 12,486 | 11,319 | 1,167 | | Benin | 30,680 | 7,857 | 22,823 | 42,948 | 11,533 | 31,415 | | Eko | 11,084 | 8,431 | 2,653 | 11,063 | 9,118 | 1,945 | | Enugu | 9,191 | 6,689 | 2,502 | 23,610 | 6,685 | 16,925 | | Ibadan | 11,619 | 10,089 | 1,530 | 9,236 | 7,840 | 1,396 | | Ikeja | 12,288 | 9,654 | 2,634 | 26,537 | 22,117 | 4,420 | | Jos | 1,617 | 1,492 | 125 | 3,519 | 3,245 | 274 | | Kaduna | 10,315 | 8,507 | 1,808 | 10,001 | 8,823 | 1,178 | | Kano | 4,662 | 4,514 | 148 | 5,326 | 5,168 | 158 | | P/H | 4,143 | 3,412 | 731 | 5,519 | 4,950 | 569 | | Yola | 1,747 | 1,733 | 14 | 2,982 | 2,899 | 83 | | DisCos Average | 9,897 | 6,622 | 3,275 | 13,930 | 8,518 | 5,412 | | DisCos Total | 108,871 | 72,846 | 36,025 | 153,227 | 93,697 | 59,530 | | 2018/Q3 | | | 2018/Q4 | | | 2018 | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | Customers' Complaints: | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | 16,371 | 14,552 | 1,819 | 14,036 | 12,999 | 1,037 | 54,418 | 49,338 | 5,080 | | 33,682 | 15,942 | 17,740 | 12,437 | 7,226 | 5,211 | 119,747 | 42,558 | 77,189 | | 3,881 | 3,837 | 44 | 30,531 | 30,436 | 95 | 56,559 | 51,822 | 4,737 | | 15,548 | 11,613 | 3,935 | 22,608 | 20,352 | 2,256 | 70,957 | 45,339 | 25,618 | | 8,222 | 7,370 | 852 | 7,154 | 6,139 | 1,015 | 36,231 | 31,438 | 4,793 | | 27,485 | 24,270 | 3,215 | 24,943 | 21,199 | 3,744 | 91,253 | 77,240 | 14,013 | | 3,680 | 3,315 | 365 | 5,401 | 4,923 | 478 | 14,217 | 12,975 | 1,242 | | 7,838 | 5,891 | 1,947 | 8,615 | 6,576 | 2,039 | 36,769 | 29,797 | 6,972 | | 5,507 | 4,731 | 776 | 4,802 | 4,080 | 722 | 20,297 | 18,493 | 1,804 | | 4,116 | 3,414 | 702 | 3,405 | 2,225 | 1,180 | 17,183 | 14,001 | 3,182 | | 2,461 | 2,408 | 53 | 2,461 | 2,408 | 53 | 9,651 | 9,448 | 203 | | 11,708 | 8,849 | 2,859 | 12,399 | 10,778 | 1,621 | 47,935 | 34,768 | 13,167 | | 28,791 | 97,343 | 31,448 | 136,393 | 118,563 | 17,830 | 527,282 | 382,449 | 144,833 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies (DisCos) altogether Source: DisCos. * * * Table E.3 Cont'd: Quarterly Complaints Received and Resolved by DisCos in 2016-2020 | DisCos | 2017/Q1 | | | 2017/Q2 | | | | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | | | Received | Resolved | Pending | Received | Resolved | Pending | | | Abuja | 6,944 | 6,280 | 664 | 10,044 | 8,775 | 1,269 | | Benin | 23,611 | 17,327 | 6,284 | 36,420 | 14,489 | 21,931 | | Eko | 4,443 | 3,723 | 720 | 20,692 | 3,783 | 16,909 | | Enugu | 3,370 | 3,345 | 25 | 4,191 | 4,140 | 51 | | Ibadan | 6,787 | 6,116 | 671 | 6,651 | 5,638 | 1,013 | | Ikeja | 23,187 | 21,238 | 1,949 | 22,868 | 19,674 | 3,194 | | Jos | 3,467 | 3,265 | 202 | 2,268 | 2,213 | 55 | | Kaduna | 7,561 | 6,564 | 997 | 5,488 | 4,928 | 560 | | Kano | 1,154 | 1,146 | 8 | 2,050 | 1,992 | 58 | | P/H | 6,210 | 5,777 | 433 | 4,461 | 4,180 | 281 | | Yola | 1,428 | 1,405 | 23 | 1,628 | 1,508 | 120 | | DisCos Average | 8,015 | 6,926 | 1,089 | 10,615 | 6,484 | 4,131 | | DisCos Total | 88,162 | 76,186 | 11,976 | 116,761 | 71,320 | 45,441 | | 2017/Q3 | | | 2017/Q4 | | | 2017 | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | Customers' Complaints: | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | 13,221 | 11,504 | 1,717 | 17,749 | 15,409 | 2,340 | 47,958 | 41,968 | 5,990 | | 34,238 | 20,553 | 13,685 | 35,380 | 20,183 | 15,197 | 129,649 | 72,552 | 57,097 | | 9,117 | 6,700 | 2,417 | 12,495 | 8,747 | 3,748 | 46,747 | 22,953 | 23,794 | | 4,723 | 4,666 | 57 | 6,621 | 6,375 | 246 | 18,905 | 18,526 | 379 | | 6,925 | 5,797 | 1,128 | 9,233 | 7,887 | 1,346 | 29,596 | 25,438 | 4,158 | | 21,082 | 17,383 | 3,699 | 27,617 | 23,909 | 3,708 | 94,754 | 82,204 | 12,550 | | 3,060 | 2,875 | 185 | 3,291 | 3,040 | 251 | 12,086 | 11,393 | 693 | | 6,333 | 5,561 | 772 | 8,615 | 6,576 | 2,039 | 27,997 | 23,629 | 4,368 | | 3,745 | 2,829 | 916 | 4,802 | 4,080 | 722 | 11,751 | 10,047 | 1,704 | | 3,443 | 2,870 | 573 | 3,405 | 2,225 | 1,180 | 17,519 | 15,052 | 2,467 | | 3,161 | 3,046 | 115 | 2,461 | 2,408 | 53 | 8,678 | 8,367 | 311 | | 9,913 | 7,617 | 2,297 | 11,970 | 9,167 | 2,803 | 40,513 | 30,194 | 10,319 | | 09,048 | 83,784 | 25,264 | 131,669 | 100,839 | 30,830 | 445,640 | 332,129 | 113,511 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies (DisCos) altogether Source: DisCos. * * * Table E.3 Cont'd: Quarterly Complaints Received and Resolved by DisCos in 2016-2020 | DisCos | 2016/Q1 | | | 2016/Q2 | | | | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | | | Received | Resolved | Pending | Received | Resolved | Pending | | | 3,027 | 2,787 | 240 | 6,756 | 6,417 | 339 | | | Abuja | 6,516 | 4,419 | 2,097 | 9,144 | 4,931 | 4,213 | | Benin | 916 | 907 | 9 | 1,738 | 1,711 | 27 | | Eko | 916 | 907 | 9 | 1,738 | 1,711 | 27 | | Enugu | 7,521 | 6,429 | 1,092 | 2,038 | 1,781 | 257 | | Ibadan | 6,198 | 5,730 | 468 | 4,217 | 3,851 | 366 | | Ikeja | 18,137 | 16,781 | 1,356 | 14,327 | 12,379 | 1,948 | | Jos | 3,542 | 3,346 | 196 | 1,680 | 1,545 | 135 | | Kaduna | 638 | 635 | 3 | 3,619 | 3,219 | 400 | | Kano | 1,177 | 1,128 | 49 | 1,039 | 980 | 59 | | P/H | 2,966 | 2,798 | 168 | 3,111 | 2,991 | 120 | | Yola | 331 | 324 | 7 | 0 | 0 | 0 | | DisCos Average | 4,634 | 4,117 | 517 | 4,334 | 3,619 | 715 | | DisCos Total | 50,969 | 45,284 | 5,685 | 47,669 | 39,805 | 7,864 | | 2016/Q3 | | | 2016/Q4 | | | 2016 | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | Customers' Complaints: | | | | Received | Resolved | Pending | Received | Resolved | Pending | Received | Resolved | Pending | | 6,556 | 6,404 | 152 | 9,698 | 9,107 | 591 | 26,037 | 24,715 | 1,322 | | 10,332 | 5,672 | 4,660 | 19,377 | 12,319 | 7,058 | 45,369 | 27,341 | 18,028 | | 2,012 | 1,917 | 95 | 0 | 0 | 0 | 4,666 | 4,535 | 131 | | 1,809 | 692 | 1,117 | 2,859 | 2,838 | 21 | 14,227 | 11,740 | 2,487 | | 4,347 | 4,053 | 294 | 4,592 | 4,170 | 422 | 19,354 | 17,804 | 1,550 | | 23,289 | 20,572 | 2,717 | 20,278 | 16,512 | 3,766 | 76,031 | 66,244 | 9,787 | | 5,058 | 4,757 | 301 | 0 | 0 | 0 | 10,280 | 9,648 | 632 | | 4,619 | 4,131 | 488 | 0 | 0 | 0 | 8,876 | 7,985 | 891 | | 1,837 | 1,812 | 25 | 1,077 | 1,017 | 60 | 5,130 | 4,937 | 193 | | 2,820 | 2,806 | 14 | 5,338 | 5,127 | 211 | 14,235 | 13,722 | 513 | | 713 | 709 | 4 | 1,099 | 1,079 | 20 | 2,143 | 2,112 | 31 | | 5,763 | 4,866 | 897 | 5,847 | 4,743 | 1,104 | 20,577 | 17,344 | 3,233 | | 63,392 | 53,525 | 9,867 | 64,318 | 52,169 | 12,149 | 226,348 | 190,783 | 35,565 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies (DisCos) altogether Source: DisCos. * * * Table E.4: DisCos' Performance on Complaints Resolved in 2016-20 | DisCos | 2020: | | | | | --- | --- | --- | --- | --- | | /Q1 | /Q2 | /Q3 | /Q4 | | | Abuja | 97.61 | 98.27 | 97.89 | 95.14 | | Benin | 85.88 | 83.51 | 84.83 | 85.25 | | Eko | 86.85 | 87.06 | 89.51 | 92.89 | | Enugu | 96.29 | 97.20 | 98.57 | 98.28 | | Ibadan | 76.79 | 80.89 | 77.45 | 83.48 | | Ikeja | 91.16 | 91.12 | 91.00 | 89.81 | | Jos | 91.39 | 94.66 | 96.31 | 92.24 | | Kaduna | 94.76 | 93.01 | 93.68 | 85.53 | | Kano | 97.27 | 98.09 | 97.88 | 98.16 | | Port Harcourt | 88.50 | 96.11 | 95.72 | 97.67 | | Yola | 99.95 | 98.85 | 98.58 | 97.44 | | All DisCos | 92.30 | 93.39 | 93.55 | 93.68 | | DisCos Average | 91.49 | 92.62 | 92.86 | 92.35 | | 2019: | | | | | | | --- | --- | --- | --- | --- | --- | | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | 96.87 | 80.77 | 80.96 | 74.39 | 87.14 | 81.14 | | 84.96 | 77.71 | 84.82 | 92.75 | 87.41 | 84.85 | | 89.14 | 99.59 | 89.27 | 86.16 | 83.54 | 90.82 | | 97.55 | 88.34 | 96.30 | 81.56 | 96.74 | 89.99 | | 79.42 | 66.35 | 76.63 | 69.38 | 74.07 | 71.42 | | 90.79 | 87.75 | 85.51 | 86.66 | 90.21 | 87.67 | | 93.36 | 94.25 | 90.01 | 92.86 | 91.20 | 92.04 | | 92.08 | 81.18 | 82.12 | 96.20 | 96.67 | 88.59 | | 97.86 | 95.24 | 93.44 | 93.91 | 96.31 | 94.79 | | 95.32 | 88.47 | 85.85 | 89.98 | 86.75 | 87.87 | | 98.79 | 99.10 | 98.88 | 99.53 | 98.32 | 98.98 | | 93.25 | 87.05 | 87.71 | 84.66 | 90.46 | 87.50 | | 92.38 | 87.16 | 87.62 | 87.58 | 89.85 | 88.01 | | | 2018: | | | | | --- | --- | --- | --- | --- | | DisCos | /Q1 | /Q2 | /Q3 | /Q4 | | Abuja | 90.83 | 90.65 | 88.89 | 92.61 | | Benin | 25.61 | 26.85 | 47.33 | 58.10 | | Eko | 76.06 | 82.42 | 98.87 | 99.69 | | Enugu | 72.78 | 28.31 | 74.69 | 90.02 | | Ibadan | 86.83 | 84.89 | 89.64 | 85.81 | | Ikeja | 78.56 | 83.34 | 88.30 | 84.99 | | Jos | 92.27 | 92.21 | 90.08 | 91.15 | | Kaduna | 82.47 | 88.22 | 75.16 | 76.33 | | Kano | 96.83 | 97.03 | 85.91 | 84.96 | | Port Harcourt | 82.36 | 89.69 | 82.94 | 65.35 | | Yola | 99.20 | 97.22 | 97.85 | 97.85 | | DisCos Average | 66.91 | 61.15 | 75.58 | 86.93 | | All DisCos | 80.35 | 78.26 | 83.61 | 84.26 | | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | --- | --- | --- | --- | --- | --- | | 90.66 | 90.4 | 87.4 | 87.0 | 86.8 | 87.5 | | 35.54 | 73.4 | 39.8 | 60.0 | 57.0 | 56.0 | | 91.62 | 83.8 | 18.3 | 73.5 | 70.0 | 49.1 | | 63.90 | 99.3 | 98.8 | 98.8 | 96.3 | 98.0 | | 86.77 | 90.1 | 84.8 | 83.7 | 85.4 | 86.0 | | 84.64 | 91.6 | 86.0 | 82.5 | 86.6 | 86.8 | | 91.26 | 94.2 | 97.6 | 94.0 | 92.4 | 94.3 | | 81.04 | 86.8 | 89.8 | 87.8 | 76.3 | 84.4 | | 91.11 | 99.3 | 97.2 | 75.5 | 85.0 | 85.5 | | 81.48 | 93.0 | 93.7 | 83.4 | 65.3 | 85.9 | | 97.90 | 98.4 | 92.6 | 96.4 | 97.8 | 96.4 | | 72.53 | 90.9 | 80.5 | 83.9 | 81.7 | 82.7 | | 81.45 | 86.4 | 61.1 | 76.8 | 76.6 | 74.5 | | | /Q1 | | --- | --- | | Abuja | 92.1 | | Benin | 67.8 | | Eko | 99.0 | | Enugu | 85.5 | | Ibadan | 92.4 | | Ikeja | 92.5 | | Jos | 94.5 | | Kaduna | 99.5 | | Kano | 95.8 | | Port Harcourt | 94.3 | | Yola | 97.9 | | DisCos Average | 91.9 | | All DisCos | 88.8 | | Notes of the table: Total | | | /Q2 | /Q3 | /Q4 | Annual | | --- | --- | --- | --- | | 95.0 | 97.7 | 93.9 | 94.9 | | 53.9 | 54.9 | 63.6 | 60.3 | | 98.4 | 95.3 | - | 97.2 | | 87.4 | 38.3 | 99.3 | 82.5 | | 91.3 | 93.2 | 90.8 | 92.0 | | 86.4 | 88.3 | 81.4 | 87.1 | | 92.0 | 94.0 | - | 93.9 | | 88.9 | 89.4 | - | 90.0 | | 94.3 | 98.6 | 94.4 | 96.2 | | 96.1 | 99.5 | 96.0 | 96.4 | | - | 99.4 | 98.2 | 98.6 | | 88.4 | 86.2 | 89.7 | 89.9 | | 83.5 | 84.4 | 81.1 | 84.3 | Notes of the table: Total DisCos is the eleven (11) electricity distribution companies altogether Source: Computed by the Commission. * * * Key Statistics Table E.5: Customer Complaints by Categories in 2016-20 | ComplaintCategories | 2019: | | | | | | 2018 | | | | | 2018 | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | | | Metering | 41,455 | 44,662 | 48,019 | 71,897 | 206,033 | 37123 | 46435 | 38,837 | 41,547 | 163,942 | 18,201 | 43,891 | 35,873 | 32,674 | 130,639 | | | Interruption | 37,631 | 41,381 | 39,869 | 34,199 | 153,080 | 14396 | 12920 | 22,097 | 24,920 | 74,333 | 13,659 | 21,976 | 28,567 | 23,603 | 87,805 | | | Voltage | 14,899 | 15,216 | 17,583 | 17,623 | 65,321 | 7118 | 6483 | 7,835 | 10,091 | 31,527 | 6,621 | 7,084 | 4,763 | 4,545 | 23,013 | | | Load Shedding | 16,680 | 16,056 | 20,342 | 16,498 | 69,576 | 1374 | 8339 | 21,622 | 7,746 | 39,081 | 1,386 | 1,168 | 1,955 | 813 | 5,322 | | | Billing | 46,399 | 45,746 | 45,895 | 40,489 | 178,529 | 39940 | 46191 | 47,053 | 48,235 | 181,419 | 45,996 | 59,745 | 32,876 | 31,117 | 169,734 | | | Disconnection | 24,666 | 21,427 | 22,856 | 20,414 | 89,363 | 7791 | 9326 | 18,061 | 17,694 | 52,872 | 6,081 | 8,203 | 7,146 | 4,813 | 26,243 | | | Connection Delay | 13,386 | 10,309 | 14,495 | 12,401 | 50,591 | 516 | 5878 | 7,235 | 9,150 | 22,779 | 97 | 229 | 2,267 | 2,109 | 4,703 | | | Others | 9,390 | 8,319 | 9,930 | 16,976 | 44,615 | 37701 | 16366 | 10,093 | 18,424 | 82,584 | 16,830 | 10,931 | 15,344 | 36,719 | 79,824 | | | Total | 204,506 | 203,116 | 218,989 | 230,497 | 857,108 | 145959 | 151938 | 172,833 | 177,807 | 648,537 | 108,874 | 153,227 | 128,791 | 136,393 | 527,282 | | | ComplaintCategories | 2017: | | | | | | 2016: | | | | | | | | | | | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | | | | | | | | | Metering | 15,275 | 46,462 | 36,198 | 50,628 | 148,563 | 12,967 | 8,664 | 12,866 | 25,823 | 60,320 | | | | | | | Notes of the table: Q1, Q2, Q3 and Q4 denote the first, second, third and fourth quarters of the year Source: DisCos. * * * Key Statistics Table E.6: Quarterly Complaints Received and Resolved by Forum Offices in 2018-20 | S/N | Forum Offices | 2020/Q1 | | | | 2020/Q2 | | | | 2020/Q3 | | | | 2020/Q4 | | | | 2020 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | | Customers' Complaints: | | | | Customers' Complaints: | | | | Customers' Complaints: | | | | Customers' Complaints: | | | | | | | $Received^{1}$ | Resolved | Pendring^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pendring^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pendring^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pendring^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pendring^{2}$ | 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 | 55 | 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 | 14 | 0 | 8 | 0% | 10 | 5 | 5 | 50% | 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 | 46% | 64 | 27 | 35 | 42% | 89 | 52 | 35 | 58% | | 9 | Dutse | 1 | 1 | 0 | 100% | 4 | 4 | 0 | 100% | 2 | 0 | 2 | 0% | 5 | 1 | 2 | 20% | 9 | 5 | 2 | 56% | | 10 | Eko | 252 | 137 | 115 | 54% | 152 | 120 | 32 | 79% | 132 | 108 | 24 | 82% | 143 | 119 | 24 | 83% | 508 | 484 | 24 | 95% | Note of the table: e: $ ^{1} $ Reported value includes complaints carried forward from the preceding quarter; $ ^{2} $ Reported value excludes complaints withdrawn during the quarter for private settlement; $ ^{3} $ Reported values are actual complaints received in the current year plus complaints carried forward from the preceding year, and $ ^{4} $ Indicates that the reported value excludes complaints withdrawn for out of Forum settlement during the year. * * * Key Statistics Table E.6: Cont'd Quarterly Complaints Received and Resolved by Forum Offices in 2018-20 | S/N | Forum Offices | 2019/Q1 | | | | 2019/Q2 | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | Customers' Complaints: | | | Customers' Complaints: | | | | | | $Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | Received^{1}$ | | | | 1 | Abakaliki | 37 | 22 | 15 | 59% | 48 | 31 | 17 | 65% | 33 | | 2 | Abuja | 438 | 214 | 224 | 49% | 261 | 148 | 110 | 57% | 197 | | 3 | Asaba | 126 | 80 | 46 | 63% | 62 | 55 | 7 | 89% | 88 | | 4 | Awka | 86 | 41 | 45 | 48% | 84 | 33 | 51 | 39% | 92 | | 5 | Bauchi | 11 | 8 | 2 | 73% | 5 | 2 | 3 | 40% | 6 | | 6 | Benin | 52 | 16 | 36 | 31% | 84 | 59 | 25 | 70% | 97 | | 7 | Birnin Kebbi | 10 | 6 | 4 | 60% | 9 | 5 | 4 | 56% | 11 | | 8 | Calabar | 15 | 12 | 3 | 80% | 8 | 1 | 7 | 13% | 9 | | 9 | Dutse | 6 | 0 | 6 | 0% | 0 | 0 | 0 | 0% | 2 | | 10 | Eko | 333 | 70 | 263 | 21% | 332 | 115 | 217 | 35% | 194 | | 11 | Enugu | 67 | 52 | 15 | 78% | 48 | 30 | 18 | 63% | 35 | | 12 | Gombe | 10 | 1 | 9 | 10% | 10 | 5 | 5 | 50% | 8 | | 13 | Gusau | 21 | 3 | 18 | 14% | 20 | 9 | 11 | 45% | 14 | | 14 | Ibadan | 223 | 72 | 151 | 32% | 301 | 205 | 96 | 68% | 236 | | 15 | Ikeja | 456 | 153 | 298 | 34% | 637 | 269 | 368 | 42% | 1193 | | 16 | Ilorin | 45 | 11 | 34 | 24% | 58 | 14 | 42 | 24% | 137 | | 17 | Jos | 12 | 2 | 10 | 17% | 5 | 0 | 5 | 0% | 14 | | 18 | Kaduna | 43 | 23 | 16 | 53% | 39 | 11 | 25 | 28% | 65 | | 19 | Kano | 87 | 8 | 74 | 9% | 82 | 68 | 13 | 83% | 18 | | 20 | Katsina | 7 | 1 | 6 | 14% | 12 | 10 | 0 | 83% | 1 | | 24 | Lafia | 42 | 22 | 10 | 52% | 77 | 50 | 20 | 65% | 94 | | 21 | Lokoja | 23 | 13 | 10 | 57% | 57 | 14 | 43 | 25% | 41 | | 2019/Q3 | | | 2019/Q4 | | | | 2019 | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | ResolvedPending$ ^{2}$Resolution Rate | | | Customers' Complaints: | | | | Customers' Complaints: | | | | | 28 | 5 | 85% | 37 | 32 | 5 | 86% | 117 | 113 | 5 | 97% | | 162 | 35 | 82% | 98 | 80 | 18 | 82% | 625 | 604 | 18 | 97% | | 67 | 21 | 76% | 77 | 69 | 8 | 90% | 265 | 271 | 8 | 102% | | 54 | 38 | 59% | 35 | 16 | 19 | 46% | 203 | 144 | 19 | 71% | | 5 | 1 | 83% | 7 | 5 | 2 | 71% | 24 | 20 | 2 | 83% | | 84 | 12 | 87% | 30 | 18 | 12 | 60% | 173 | 177 | 12 | 102% | | 4 | 7 | 36% | 9 | 1 | 8 | 11% | 32 | 16 | 8 | 50% | | 0 | 9 | 0% | 16 | 2 | 14 | 13% | 40 | 15 | 14 | 38% | | 0 | 2 | 0% | 2 | 1 | 1 | 50% | 4 | 1 | 1 | 25% | | 162 | 32 | 84% | 171 | 121 | 50 | 71% | 734 | 468 | 50 | 64% | | 14 | 21 | 40% | 56 | 47 | 9 | 84% | 144 | 143 | 9 | 99% | | 1 | 7 | 13% | 16 | 16 | 0 | 100% | 23 | 23 | 0 | 100% | | 7 | 7 | 50% | 19 | 4 | 15 | 21% | 49 | 23 | 15 | 47% | | 19 | 213 | 8% | 263 | 122 | 141 | 46% | 599 | 418 | 141 | 70% | | 802 | 386 | 67% | 799 | 398 | 401 | 50% | 2307 | 1622 | 401 | 70% | | 93 | 40 | 68% | 92 | 52 | 39 | 57% | 215 | 170 | 39 | 79% | | 0 | 14 | 0% | 24 | 16 | 8 | 67% | 25 | 18 | 8 | 72% | | 10 | 51 | 15% | 96 | 31 | 59 | 32% | 151 | 75 | 59 | 50% | | 9 | 4 | 50% | 85 | 43 | 42 | 51% | 153 | 128 | 42 | 84% | | 1 | 0 | 100% | 3 | 3 | 0 | 100% | 17 | 15 | 0 | 88% | | 49 | 39 | 52% | 23 | 5 | 13 | 22% | 132 | 126 | 13 | 95% | | 2 | 39 | 5% | 27 | 7 | 20 | 26% | 115 | 36 | 20 | 31% | | 0 | 7 | 0% | 46 | 23 | 11 | 50% | 67 | 23 | 11 | 34% | | 505 | 125 | 80% | 290 | 0 | 290 | 0% | 1049 | 763 | 290 | 73% | Note of the table: e: $ ^{1} $ Reported value includes complaints carried forward from the preceding quarter; $ ^{2} $ Reported value excludes complaints withdrawn during the quarter for private settlement; $ ^{3} $ Reported values are actual complaints received in the current year plus complaints carried forward from the preceding year, and $ ^{4} $ Indicates that the reported value excludes complaints withdrawn for out of Forum settlement during the year. * * * Key Statistics Table E.6: Cont'd Quarterly Complaints Received and Resolved by Forum Offices in 2018-20 | S/N | Forum Offices | 2018/Q1 | | | | 2018/Q2 | | | | 2018/Q3 | | | | 2018/Q4 | | | | | | | | | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | | Customers' Complaints: | | | | Customers' Complaints: | | | | Customers' Complaints: | | | | Customers' Complaints: | | | | | | | | | | | $Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | Received^{1}$ | Resolved | Pending^{2}$ | Resolution Rate | | | | | | | | 1 | Abakaliki | 17 | 0 | 17 | 0% | 15 | 4 | 9 | 27% | 45 | 30 | 15 | 67% | 49 | 44 | 5 | 90% | 85 | 85 | 5 | 92% | | 2 | Abuja | 101 | 0 | 101 | 0% | 170 | 91 | 79 | 54% | 214 | 106 | 108 | 50% | 267 | 105 | 162 | 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 | - | - | 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% | 4 | 543 | 174 | 361 | 32% | 718 | 349 | 361 | 49% | | 10 | Enugu | 170 | 0 | 170 | 0% | 111 | 97 | 14 | 87% | 86 | 38 | 48 | 44% | 73 | 37 | 36 | 51% | 208 | 172 | 36 | 83% | | 11 | Gombe | 22 | 3 | 19 | 14% | 9 | 3 | 6 | 33% | 12 | 4 | 8 | 33% | 9 | 8 | 1 | 89% | 19 | 18 | 1 | 95% | Note of the table: $ ^{1} $ Reported value includes complaints carried forward from the preceding quarter; $ ^{2} $ Reported value excludes complaints withdrawn during the quarter for private settlement; $ ^{3} $ Reported values are actual complaints received in the current year plus complaints carried forward from the preceding year, and $ ^{4} $ Indicates that the reported value excludes complaints withdrawn for out of Forum settlement during the year * * * NIGERIAN ELECTRICITY REGULATORY COMMISSION ERC NIGERIAN ELECTRICITY R PLOT 1387 \| CADASTRAL ZON REGULATORY COMMISSION A00\| CENTRAL BUSINESS DISTRICT P.M.B. 136\| GARKI\| ABUJA [www.nerc.gov.ng](http://www.nerc.gov.ng/)