NIGERIAN ELECTRICITY REGULATORY COMMISSION

202 Annu Repo Acco

3 al rt & unts

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# 2023 Annual Report

# & Accounts

## Nigerian Electricity Regulatory Commission

## Plot 1387 Cadastral Zone A00

## Central Business District

## PMB 136, Garki Abuja

**[www.nerc.gov.ng](http://www.nerc.gov.ng/)**

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Our Mission

Promote and ensure investor-friendly industry and efficient market structure to meet the needs of Nigeria for safe, adequate, reliable and affordable electricity.

Core Values

Our Vision

"Electricity on demand"

Our Motto "Keeping the lights on"

NIGERIAN ELECTRICITY REGULATORY COMMISSION
NERC

Proficiency, diligence, respect fairness and accountability;

* * *

## Preface and Content NERC Annual Report 2023

**NERC©2024**

## NERC Annual Report & Accounts is prepared in compliance with section 56 (1) of

## the Electricity Act 2023, which mandates the Commission to keep proper accounts

## and other records relating to such accounts in respect of all the Commission’s

## activities, funds and property, including such particular account and records as the

## Minister may require. The report presents the Commission’s regulatory and

## corporate activities, audited financial statements and analyses of the state of the

## Nigerian Electricity Supply Industry (NESI) covering operational, technical and

## commercial performances as well as consumer affairs. The Commission presents this

## report to a wide spectrum of stakeholders including financial and market analysts,

## potential investors, government institutions and the private sector.

## NERC Annual Report & Account is freely available to the Nigerian Electricity Supply

## Industry stakeholders, government agencies and corporations. Individuals, on

## request, can also obtain any particular issue without a charge. Please direct all

## inquiries, comments and suggestions on the report to:

## The Commissioner

## Planning, Research and Strategy

## Nigerian Electricity Regulatory Commission

## Corporate Head Office

## Plot 1387 Cadastral Zone A00

## Central Business District

## P.M.B 136, Garki Abuja

**Nigeria**

## NERC Website: [www.nerc.gov.ng](http://www.nerc.gov.ng/)

## Contact Centre:

## Tel: +234 (09) 462 1400, +234 (09) 462 1410

## Email: [info@nerc.gov.ng](mailto:info@nerc.gov.ng)

## Nigerian Electricity Regulatory Commission i

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Preface and Content

TABLE OF CONTENTS

Executive Summary ..... 1

Chapter One: Legal and Regulatory Framework ..... 20
1.1 Background to the creation of the Commission ..... 22
1.2 Regulatory Functions ..... 24
1.3 Legal Framework ..... 25
1.4 Reporting Obligations ..... 28
1.4.1 Quarterly Reports ..... 28
1.4.2 Financial Reports ..... 28

Chapter Two: Human Resource Management ..... 29
2.1 Board of Commissioners ..... 31
2.2 General Managers ..... 33
2.3 Secretary of the Commission ..... 33
2.4 Management Staff ..... 34
2.5 Forum Office Secretaries ..... 35
2.6 Staff Composition ..... 36
2.6.1 Distribution by Division ..... 36
2.6.2 Distribution by Cadre ..... 36
2.6.3 Distribution by Gender ..... 37
2.7 Capacity Development ..... 38
2.8 Promotion, Awards, Rec

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Preface and Content

5.2 Stakeholder Engagements ..... 85
5.2.1 Nigerian Electricity Supply Industry (NESI) Stakeholder Meetings ..... 85
5.2.2 Stakeholder Workshop on the Electricity Act 2023 ..... 88
5.2.3 Other Stakeholder Engagements ..... 91

Chapter Six: Electricity Tariffs ..... 104
6.1 Introduction ..... 106
6.2 Multi-Year Tariff Order (MYTO) ..... 106
6.2.1 Objectives of the MYTO ..... 106
6.2.2 Types of Tariff Reviews ..... 107
6.3 Tariff setting parameters ..... 108
6.4 Service-Based Tariff Regime (SBT) ..... 109
6.5 Tariff subsidies ..... 110
6.6 End-user Tariffs in Nigeria and Other West African Countries ..... 112
6.7 2023/2024 Extraordinary Tariff Review .....

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## Preface and Content NERC Annual Report 2023

## LIST OF TABLES

**Table 1: General Managers of the Commission as of December 2023 ... 33**

**Table 2: Management Staff of the Commission ... 34**

**Table 3: Distribution of the Commission’s Staff by Divisions in 2023 ... 36**

**Table 4: Distribution of the Commission’s Staff by Cadre in 2023 ... 37**

**Table 5: Details of licenced grid-connected Power Plant ... 63**

**Table 6: Distribution Licensees (DisCos) in the NESI ... 65**

**Table 7: Licenses, Permits and Certifications Issued by the Commission in 2023 ... 67**

**Table 8: Summary of enforcement actions carried out by the Commission in 2023... 69**

**Table 9: Town Hall Meetings held in 2023 ... 74**

**Table 10: Appeals Handled by Forum Offices in 2023 ... 84**

**Table 11: NESI Meetings held in 2023 ... 86**

**Table 12: Thematic working groups for the implementation of the EA 2023 ... 89**

**Table 13: Stakeholder engagements and other activities of the Commission in 2023 91**

**Table 14: Customer cluster and expected service delivery ... 110**

**Table 15: Average Tariff for Non-MD customers Across DisCos in 2023 ... 111**

**Table 16: Average Electricity Tariff in Select African Counties ... 112**

**Table 17: Cost-Reflective and Allowed Tariffs effective 01 January 2024 ... 115**

**Table 18: Plant Availability Factor (%) in 2023 ... 120**

**Table 19: System Collapses in 2019 – 2023 ... 132**

**Table 20: System collapse incidents in 2023 ... 133**

**Table 21: Metering Progress as of 2023 ... 137**

**Table 22: Meter Deployment by DisCos in 2023 ... 136**

**Table 23: Meter installations under the metering frameworks ... 137**

**Table 24: Energy Offtake Performance in 2023 ... 140**

**Table 25: Energy Received and Billed by DisCos in 2023 ... 142**

**Table 26: Revenue Performance of DisCos in 2023 ... 144**

**Table 27: ATC&C Loss of DisCos in 2023 ... 145**

**Table 28: Minimum Remittance Obligation of DisCos to NBET & MO in 2023 ... 147**

**Table 29: Annual Remittance Performance to NBET and MO ... 149**

**Table 30: Bilateral Customers Invoices & Remittances in 2023 ... 151**

## Nigerian Electricity Regulatory Commission iv

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## Preface and Content NERC Annual Report 2023

## LIST OF FIGURES

**Figure 1: Distribution of the Commission’s Staff by Gender in 2023 ... 38**

**Figure 2: Structure of the Commission as of December 2023 ... 44**

**Figure 3: Customer Complaint Flow chart ... 77**

**Figure 4: Category of Complaints Received at the Commission’s CCU in 2023 ... 82**

**Figure 5: Category of Complaints Received by all DisCos in 2023 ... 83**

**Figure 6: Category of Complaints Received by all Forum Offices in 2023 ... 84**

**Figure 7: Average Available Capacity (MW) in 2023 ... 119**

**Figure 8: Average Hourly Generation (MWh/h) in 2023 ... 123**

**Figure 9: Average Share (%) of Generation Output by Power Plants in 2023 ... 124**

**Figure 10: Plant Load Factor (%) in 2023 ... 125**

**Figure 11: Actual TLF (%) vs. MYTO TLF Target (%) in 2023 ... 128**

**Figure 12: Monthly System Frequency (Hz) from Jan – Dec 2023 ... 129**

**Figure 13: Monthly System Voltage (kV) from Jan – Dec 2023 ... 132**

**Figure 14: DisCos’ Remittance Performance to NBET and MO in 2023 ... 148**

## Nigerian Electricity Regulatory Commission v

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LIST OF ABBREVIATIONS

ADR Alternative Dispute Resolution
AEDC Abuja Electricity Distribution Company Plc
ANAN Association of National Accountants of Nigeria
ATC&C Aggregate Technical, Commercial & Collection Losses
BCR Business Continuity Regulations
BEDC Benin Electricity Distribution Company Plc
BPE Bureau of Public Enterprises
CA Consumer Affairs
CAPEX Capital Expenditure
CAPMI Credited Advance Payment for Metering Implementation
CEET Compagnie Energie Electrique du Togo
CPC Consumer Protection Council
DisCos Distribution Companies
DSOs Distribution System Operators
EA Electricity Act
ECN Electricity Corporation of Nigeria
EEDC Enugu Electricity Distribution Company Plc
EKEDP Eko Electricity Distribution Company Plc
EPM Engineering Performance and Monitoring
EPSRA Electric Power Sector Reform Act
FCT Federal Capital Territory
FMS Financial and Management Services
GenCos Generation Companies
GWh Gigawatt hours
IBEDC Ibadan Electricity Distribution Company Plc
ICAN Institute of Chartered Accountants of Nigeria
IEDN Independent Electricity Distribution Network
IE Ikeja Electricity
IPP Independent Power Plant
JEDC Jos Electricity Distribution Company Plc
KAEDC Kaduna Electricity Distribution Company Plc
KEDCO Kano Electricity Distribution Company Plc
LLC Legal Licencing and Compliance
MAN Manufacturers Association of Nigeria
MAP Meter Assets Provider
MCR Market Competition and Rates
MO Market Operator
MW Megawatts
MWh Megawatt hours
MYTO Multi-Year Tariff Order

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NACCIMA Nigerian Association of Chambers of Commerce Industry, Mines and
Agriculture
NAEE Nigerian Association for Energy Economics

| NACCIMA | Nigerian Association of Chambers of Commerce Industry, Mines and Agriculture |
| --- | --- |
| NAEE | Nigerian Association for Energy Economics |
| NBA | Nigerian Bar Association |
| NBET | Nigerian Bulk Electricity Trading plc |
| NDA | Niger Dams Authority |
| NEPA | National Electric Power Authority |
| NEPP | Nigerian Electric Power Policy |
| NERC | Nigerian Electricity Regulatory Commission |
| NESCO | Nigerian Electricity Supply Company Limited |
| NESI | Nigerian Electricity Supply Industry |
| NICE | Notices of Intention to Commence Enforcement |
| NIGELEC | Nigerien Electricity Society |
| NIM | Nigerian Institute of Management |
| NIPP | National Integrated Power Project |
| NSE | Nigerian Society of Engineers |
| PP | Percentage Points |
| PHCN | Power Holding Company of Nigeria |
| PHEDC | Port Harcourt Electricity Distribution Company Plc |
| PRS | Planning Research and Strategy |
| REC | Regulation on Eligible Customers |
| SBEE | Société Béninoise d'Energie Electrique |
| TCN | Transmission Company of Nigeria Plc |
| TLF | Transmission Loss Factor |
| YEDC | Yola Electricity Distribution Company Plc |

NAEE Nigerian Association for Energy Economics

NBA Nigerian Bar Association

NBET Nigerian Bulk Electricity Trading plc
NDA Niger Dams Authority

NEPA National Electric Power Authority
NEPP Nigerian Electric Power Policy

NEPP Nigerian Electric Power Policy

NERC Nigerian Electricity Regulatory Commission
NESCO Nigerian Electricity Supply Company Limited

NESCO Nigerian Electricity Supply Company Limited

NESI Nigerian Electricity Supply Industry
NICE Notices of Intention to Commence Enforcement

NICE Notices of Intention to Commence Enforcement
NIGELEC Nigerien Electricity Society

NIGELEC Nigerien Electricity Society
NIM Nigerian Institute of Management

NIM Nigerian Institute of Management
NIPP National Integrated Power Project

NIPP National Integrated Power Project
NSE Nigerian Society of Engineers

PP Percentage Points

NSE Nigerian Society of Engineers
PP Percentage Points

PHCN Power Holding Company of Nigeria
PHEDC Port Harcourt Electricity Distribution Company Plc

PHEDC Port Harcourt Electricity Distribution Company Plc
PRS Planning Research and Strategy

PRS Planning Research and Strategy
REC Regulation on Eligible Customers

SBEE Société Béninoise d'Energie Electrique
TCN Transmission Company of Nigeria Plc

TCN Transmission Company of Nigeria Plc
TLF Transmission Loss Factor

TLF Transmission Loss Factor

YEDC Yola Electricity Distribution Company Plc

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# Executive Summary

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# A. Legal and Regulatory Framework

# B. Human Resource Management

# C. Corporate Governance

# D. Regulation, Licensing & Compliance

# E. Consumer Affairs

# F. Electricity Tariffs

# G. State of the Nigerian Electricity Supply Industry (NESI)

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## Executive Summary NERC Annual Report 2023

## Legal and In 2023, the Electricity Act (“EA”) was enacted, repealing the

## Regulatory Electric Power Sector Reform Act (“EPSRA”) of 2004 and other

**Framework** **acts related to the Nigerian electricity market. The EA aims to** **create a more efficient, competitive, and liberalised market with** **private sector participation, and ensure legislative consistency** **across various segments and stakeholders in the sector. It also** **recognises the Nigerian Electricity Regulatory Commission** **(“NERC” or the “Commission”) as the apex regulator for the** **Nigerian power sector and further reinforces NERC’s role in** **driving competition and accountability in the electricity market.**

## NERC continues to fulfil its principal functions as outlined in

## Sections 34(1) and 34(2) of the EA, positioning itself to provide

## robust regulatory interventions as the power sector transitions

## from a state-owned monopoly to a more competitive market

**structure.**

## Reporting Obligations: In compliance with Section 34(1)(g) of the

## EA, the Commission published four quarterly reports (Q1-Q4) of

## its activities for 2023. The reports analysed the state of the

## Nigerian electricity industry, covering operational and

## commercial performances, regulatory functions and consumer

## affairs. Each quarterly report also provided a summary of the

## Commission’s financial position, in compliance with Section 56(1)

## of the EA, which mandates proper accounts and record-keeping

## of all activities, funds, and properties of the Commission.

## Furthermore, in compliance with Section 56(2) of the EA which

## mandates the Commission to, no later than three months after the

## end of the financial year, prepare audited financial statements, the

## Commission engaged PricewaterhouseCoopers (PwC) to audit the

**st** **Commission’s accounts for the year ended 31 December 2023.**

## Staff Composition: In 2023, the count of the Commission’s total

## Human Resource

## Management manpower was two hundred and fifty-two (252) broken down as

## follows –

- **Seven (7) Commissioners**
- **Thirty-seven (37) Management staff**

## Nigerian Electricity Regulatory Commission

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• One Hundred and Eighty-seven (187) Mid-management
staff, and

• Twenty-one (21) junior staff

The members of staff are a mix of experienced professionals from
diverse disciplines including Engineering, Economics, Sciences,
Finance, Accounting, Social Sciences, Law and other fields relevant
to the needs of the Commission.

The Commission’s workforce cadre in 2023 is contained in Table
A. It also shows the gender split of the Commission’s workforce
with women representing 31% of the total. In line with the
provisions of the EA 2023, the Commission continues to promote
equitable female representation within the Commission and the
wider NESI.

Table A: Cadre and Gender Distribution of the Commission’s Staff in
2023

| No | Position | Cadre |  |  | Gender representation |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Male | Female | Total |  |  |  |  |  |  |
| 1 | General Manager |  |  |  | 5 | 1 | 6 |  |
| 2 | Deputy General Manager | Mgt. Cadre | 15% |  | 5 | 3 | 8 |  |
| 3 | Assistant General Manager |  |  |  | 17 | 7 | 24 |  |
| 4 | Principal Manager |  |  |  | 16 | 16 | 32 |  |
| 5 | Senior Manager | Senior Cadre | 42% |  | 24 | 13 | 37 |  |
| 6 | Manager |  |  |  | 30 | 4 | 34 |  |
| 7 | Assistant Manager | Middle Cadre | 34% |  | 21 | 11 | 32 |  |
| 8 | Analysts |  |  |  | 31 | 21 | 52 |  |
| 9 | Junior Staff | Junior Cadre | 9% |  | 19 | 1 | 20 |  |
|  | Total |  |  |  | 168 | 77 | 245 |  |

Note: The staff’s distribution in this table excludes the Commissioners and their Aides

Capacity Development: The Commission places a premium on staff
capacity development, and on account of this, members of staff
attended the required in-person and remote regulatory,
management and leadership courses in 2023.

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## Executive Summary NERC Annual Report 2023

## Corporate Structure of the Commission: In 2023, the Commission maintained

## Governance the same core organisational structure it operated in 2022 with its

## activities being split across seven (7) Divisions which are listed

**below:**

- **Chairman’s Office (CO)** **The** • **Consumer Affairs (CA)** **Commission**

- **Engineering Performance & Monitoring (EPM)**


## has 7

## Divisions sub-

- **Finance & Management Services (FMS)** **divided into** • **Legal, Licensing & Compliance (LLC)** **24 units.**

- **Market Competition & Rates (MCR)**

- **Planning, Research & Strategy (PRS)**


## The seven (7) Divisions of the Commission are further subdivided

## into twenty-four (24) Units. Each Division is headed by a

## Commissioner who is responsible for overseeing the affairs of the

## Division. A management staff not lower than the rank of Assistant

## General Manager (AGM) coordinates the day-to-day activities of

## each Division and reports to the Commissioner.

## In line with its condition of service, the Commission conducted the

## promotion exercise for eligible staff in 2023. Participants who were

## adjudged to have satisfied the stipulated requirements were duly

**promoted.**

## Strategic Goals: The 2021–2023 strategic plan of the Commission

## is intended to drive continued growth and consolidate the

## Commission’s oversight functions in the NESI. Specifically, the plan

## provides for the realisation of the ten (10) goals listed below:

## 1\. Creation of a financially viable electricity market;

## 2\. Metering for all customers;

## 3\. Effective compliance monitoring & enforcement;

## 4\. Institutionalise code of corporate governance;

## 5\. Recapitalisation of licensees in the sector;

## 6\. Sustained growth in availability & quality of supply;

## 7\. Enhancement of the nation’s security of supply for

**electricity;**

## Nigerian Electricity Regulatory Commission

* * *

## Executive Summary NERC Annual Report 2023

## 8\. Promotion of local content and manpower development

## in NESI;

## 9\. Enforcement of safety standards;

## 10\. Review and enforcement of standards for customer care.

## These goals were crafted to align with the overall objectives of the

## Commission as outlined in Section (34) of the EA, while also being

## consistent with the overarching policy directives issued by the

## Federal Government of Nigeria.

## Highlights of the Commission’s activities in 2023: The Commission’s

## activities are guided by its strategic goals as well as overarching

## government policy and macroeconomic trends. The highlights of

## some of the Commission’s activities for the year 2023 are

## summarised below –

## A. Upholding customer care standards: In 2023, the

## Commission launched several critical activities towards the

## enforcement of customer care standards in the NESI; these

**include:**

**i. Issuance of the Customer Protection Regulation** **(NERC-R-001-2023).** **ii. The launch of the NESI call centre which provides a** **centralised portal for customers to pass complaints** **directly to their service providers.**

## iii. The launch of the Power Outage Reporting System

## (PORS) which is a mobile application for real-time

## reporting of electricity outages by consumers.

## iv. The Commission opened an additional Forum Office

## in Ado Ekiti on 29 September 2023 to enhance the

## timely resolution of customer complaints that are not

## satisfactorily resolved at the DisCo customer

## complaints units.

## v. The Commission facilitated nine (9) compensation

## meetings between licensees and victims of accidents

## recorded in 2023

## Nigerian Electricity Regulatory Commission

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vi. The Commission also issued the Order on
compensation for SBT service failure
(NERC/2023/003).

B. Improving health/safety and technical robustness of the grid
system: Some of the key activities implemented under this
scheme include –

i. Establishment of a comprehensive scope for
Supervisory Control and Data Acquisition
(SCADA)/Energy Management System (EMS)

ii. Conduction of technical studies on the integration of
Variable Renewable Energy (VRE) into the national
grid.

iii. Review of operating codes (Health & Safety Codes,
Metering Code) & NESIS Regulations

iv. Review of TCN’s Performance Improvement Plan

C. Enhanced transparency and stakeholder involvement in tariff
reviews: Pursuant to the provisions of the EA 2023 and
NERC Regulations on the Procedure of Electricity Tariff
Reviews in the NESI 2014, in evaluating the tariff review
applications made by DisCos, the Commission conducted the
rate-case hearings as part of the evaluation process of the
extraordinary tariff review filed by DisCos in July 2023. This
is consistent with international best practice in rate-setting
and provides a platform for customers, customer advocacy
groups and intervenors (industry experts and representatives
of established organisations related to the power sector) to
interrogate the submissions made by the DisCos in support
of their applications.

Regulation,
Licensing and
Compliance

• Customer Protection Regulation (NERC-R-001-2023): The
Customer Protection Regulations (CPR) was issued in March
2023 and aligns the Commission’s customer service
standards with international best practices.

Regulations: The Commission issued the two (2) underlisted
regulations in 2023.

* * *

The Commission
issued two (2) new
Regulations and
sixteen (16) new
Orders in 2023.

• Mini-grid Regulations (NERC-R-117-2023): The Mini-grid
Regulation was issued in December 2023 as a replacement
of the Mini-grid Regulations of 2016 following a series of
public and stakeholder consultations. In addition to
stakeholder inputs, the new Regulation incorporates the
changes and new provisions of the EA 2023.

Orders: The Commission issued sixteen (16) Orders to licensees in
2023\. The Orders are listed in Table B below:

Table B: Orders issued by the Commission in 2023

| S/N | Order No | Title of Order | Effective Date |
| --- | --- | --- | --- |
| 1-11 | NERC/001-012/2023 | Orders on Reimbursement of Meter Costs for Meters procured under the Meter Asset Provider and National Mass Metering Frameworks | 20th March 2023 |
| 12 | NERC/2023/002 | Order on the Mandatory Filing of Annual OpEx, Capital Investment Plans and Outcomes of Procurements Conducted by the TCN | 1st July 2023 |
| 13 | NERC/2023/003 | Order on Migration of Customers and Compensation for Service Failure under Service-Based Tariff Framework | 1st June 2023 |
| 14 | NERC/2023/005 | Order on Migration of Token Identifier of Standard Transfer Specification Meters from Key Revision 1 to Key Revision 2 | 6th July 2023 |
| 15 | NERC/2023/006 | Order on Deployment of Customer Engagement Platforms | 1st September 2023 |
| 16 | NERC/2023/020 | Order on the Price Review of MAP Meters | 6th September 2023 |

* * *

The Commission
issued 118
licenses, permits
and certifications
in 2023.

Licensing and Permits: Following the satisfactory evaluation of
applications, the Commission issued 118 licenses, permits and
certifications in 2023 as contained in Table C.

Table C: Licenses, Permits and Certifications Issued by
the Commission in 2023

| SN | License/Permit | Number |
| --- | --- | --- |
| 1 | On-grid generation | 1 |
| 2 | Off-grid generation | 8 |
| 3 | IEDN | 7 |
| 4 | Trading Licence | 5 |
| 5 | Embedded generation | 3 |
| 6 | Captive power | 15 |
| 7 | Mini-grid registration | 28 |
| 8 | Mini-grid permit | 18 |
| 9 | Meter service providers permit | 24 |
| 10 | MAP permit | 9 |
|  | Total | 118 |

Compliance Monitoring and Enforcement: In 2023, the
Commission issued twelve (12) Rectification Directives (RD) and
four (4) Notices of Intention to Commence Enforcement Actions
(NICE) against licensees for violations of rules and infractions.
These include non-compliance with the Commission’s orders,
directives and rulings as well as failure to comply with forum panel
decisions without filing appeals within the stipulated timeframe.

Litigation and Alternative Dispute Resolution: Pursuant to Section
42.3 of the market rules, the Commission has maintained a Dispute
Resolution Panel (DRP) which is an Alternative Dispute Resolution
(ADR) system of resolving disputes between market participants. In
2023, the DRP did not handle any case which continues a trend of
limited utilisation of the DRP by market participants. In an attempt
to correct this and in compliance with the Market Rules, the
Commission has tasked the Dispute Resolution Councillor (DRC)
with developing a strategy to drive the uptake of the DRP by market
participants.

* * *

Consumer
Affairs and
Stakeholder
Engagements

Consumer Affairs: The Commission conducted five (5) town
hall/customer complaints resolution meetings in 2023. The
meetings were conducted as detailed below:

• Jos, Plateau State; 18-20 April 2023

• Yola, Adamawa State; 09-11 May 2023

• Asaba, Delta State; 23-25 May 2023

• Makurdi, Benue State; 07-09 November 2023

The Commission
conducted town
hall meetings with
electricity
consumers in Jos,
Adamawa, Asaba,
Makurdi and Ikeja
in 2023.

• Ikeja, Lagos State; 22-23 November 2023

Metering, billing,
and service
interruptions
were the top
categories of
customer
complaints in
2023.

Customer Complaints: The Customer Protection Regulation issued
by the Commission during the year enumerates the standards and
procedures for handling customer complaints in line with
international best practices. The Commission provides various
channels for customers to lodge complaints against their service
providers. The complaints reporting channels include the NERC
Customer Complaints Unit (NERC-CCU), DisCo Customer
Complaint Unit (DisCo-CCU) and the NERC Forum Office. The
Commission also launched the Power Outage Reporting System
(PORS) during the year for customers to report outages in realtime.

In 2023, the NERC-CCU received 7,207 complaints and 5,067
were resolved corresponding to a 70.31% resolution rate. A
review of the customer complaints data presented in Figure A
indicates that metering, billing, and service interruption issues were
the most common customer complaints, accounting for 82.82%
(5,969) of the total complaints at the NERC-CCU in 2023.

In 2023, the NERC-CCU received 7,207 complaints and 5,067
were resolved corresponding to a 70.31% resolution rate. A
review of the customer complaints data presented in Figure A
indicates that metering, billing, and service interruption issues were
the most common customer complaints, accounting for 82.82%
(5,969) of the total complaints at the NERC-CCU in 2023.

* * *

Figure A: Category of Complaints Received at the NERC-CCU
in 2023

The total number of complaints received across all DisCos-CCU in
2023 was 1,220,245 out of which, 1,156,553 were resolved
(resolution rate – 94.78%). Like the complaints received at the
NERC-CCU, metering, billing, and service interruption were the
most common complaints issues accounting for 77.55% of the total
(Figure B).

Figure B. Category of Complaints Received at DisCos-CCU in 2023

* * *

The Forum Offices
had 359 sittings in
2023 and
resolved 60.93%
of the total active
appeals.

There was a total of 10,144 active appeals (6,387 new appeals
The Forum Offices
had 359 sittings in and 3,757 pending appeals from 2022) across all Forum Offices
2023 and
in 2023. The Forum Offices held 359 sittings in 2023 and resolved
resolved 60.93%
of the total active 60.93% of the total active appeals. Billing, metering and
appeals.
disconnection were the most prevalent complaints within the year,
accounting for 61.41%, 23.90% and 5.28% of the total
respectively (Figure C).

Stakeholder
consultation
workshop was
organised to
facilitate capacity
building and
adoption of the EA
2023.

Figure C: Category of Complaints Received by all Forum Offices
in 2023

• Electricity consumers enlightenment and protection
workshop for staff of the Federal Competition and Consumer

Stakeholder Engagements: The Commission held three (3) NESI
stakeholder consultation meetings during the year to discuss
important industry issues and to review compliance and
performance. The Commission also organised a two-day workshop
to engage stakeholders on the implementation of the new
Electricity Act 2023. The workshop was to facilitate a deep dive
into the provisions of the Act and effective collaboration among all
stakeholders.

* * *

Protection Commission (FCCPC) and National Orientation
Agency (NOA)

• Workshop for NESI stakeholders on feeder naming and
other asset nomenclature for the NESI

• Workshop for Civil Society Organisations (CSOs) and
consumer advocacy groups

• Workshop organised by the African Forum for Utility
Regulators (AFUR) on mini-grid tariff tools and
methodologies

• Capacity strengthening workshop for DisCo’s Heads of
Corporate Communication

• Public hearing for the strategic review of the Performance
Improvement Plan (PIP) of the Transmission Company of
Nigeria (TCN).

Electricity Tariffs

Multi-Year Tariff Order (MYTO): Pursuant to Section 76 of the now
repealed EPSR Act 2004 and Section 116 of the EA 2023, the
Commission established the Multi-Year Tariff Order (MYTO) as a
regulatory methodology for determining electricity tariffs. The
MYTO provides a 15-year tariff path for the NESI and ensures the
financial viability of the power sector by setting cost-reflective
tariffs.

The MYTO methodology offers a transparent framework for
determining electricity tariff that provides for the clear disaggregation and determination of necessary operating costs and
overheads and reasonable Return on Investment.

Tariff setting parameters: The MYTO methodology uses a building
blocks approach in setting Transmission and Distribution tariffs
which provides the joint benefit of price cap and incentive-based
regulation. The generation tariff is determined using a benchmark
Long Run Marginal Cost (LRMC) of the most economically efficient
new entrant. The group of parameters which the Commission
considers in determining or reviewing DisCos’ tariffs include:

• Macroeconomic indices

* * *

## Executive Summary NERC Annual Report 2023

- **Aggregate Technical and Commercial Losses (ATC&C)** **targets and trajectories**
- **Capital Expenditure (CAPEX)**
- **Operational Expenditure (OPEX)**
- **Energy Offtake**

## 2023/2024 Extraordinary Tariff Review: The FGN policy to unify

## exchange rates had a consequential impact on the wider

## macroeconomic environment including inflation rate, etc. In a bid

## to ensure that these changes did not negatively impact their ability

## to deliver service to customers and pursuant to the provisions of the

## 2014 Regulations on Procedure for Electricity Tariff Reviews in the

## NESI, all DisCos filed applications for extra-ordinary tariff reviews

## with the Commission in June 2023.

## In compliance with the Business Rules of the Commission, the

## Commission conducted rate case hearings from July 24 to August

## 8, 2023, at its headquarters in Abuja. A panel of three

## Commissioners presided over the hearing in compliance with the

## Business Rules of the Commission, while invitations were extended

**1** **to critical sector stakeholders including consumer groups to** **interrogate the submissions of the DisCos.**

## The Commission duly considered all the comments by the

## stakeholders and intervenors as well as the impact of changes in

## macroeconomic variables, prudence in expenditure, and

## operational efficiency parameters provided in the DisCos revenue

## requirement and resultant end-user tariffs. Pursuant to section 116

## of the EA 2023 and extant regulations, the Commission considered

## and approved cost-reflective tariffs for the DisCos with effect from

## 01 January 2024. Notwithstanding, in line with the policy direction

## of the FGN on electricity subsidy, the allowed end-user tariffs to be

## charged by DisCos were frozen at the rates which became effective

## in January 2023 (Table D).

**1** **Federal Competition and Consumer Protection Commission (FCCPC), Nigerian Society of Engineers (NSE),** **National Union of Electricity Employees (NUEE), Manufacturers Association of Nigeria (MAN), Nigerian** **Association of Chambers of Commerce, Industry, Mines and Agriculture (NACCIMA), the Bureau of Public** **Enterprise (BPE), Transmission Company of Nigeria Plc (TCN), registered intervenors (Appendix D.2).** **Nigerian Electricity Regulatory Commission**

* * *

Table D: Cost-Reflective and Allowed Tariffs effective 01 January 2024

| DisCo | CRT(№/kWh) | Allowed Tariff (№/kWh) | Subsidy (№/kWh) |
| --- | --- | --- | --- |
| Abuja | 120.88 | 63.24 | 57.64 |
| Benin | 126.00 | 60.10 | 65.90 |
| Eko | 114.80 | 59.50 | 55.30 |
| Enugu | 127.70 | 59.00 | 68.70 |
| Ibadan | 126.10 | 62.50 | 63.60 |
| Ikeja | 112.10 | 56.60 | 55.50 |
| Jos | 138.90 | 60.60 | 78.30 |
| Kaduna | 129.40 | 57.50 | 71.90 |
| Kano | 128.20 | 58.80 | 69.40 |
| PH | 127.00 | 61.40 | 65.60 |
| Yola | 214.10 | 66.00 | 148.10 |

State of the
Industry

Average
Available
Capacity in 2023
was
4,544.13MW

Operational report: Pursuant to the regulatory authority vested in
the Commission in the EA 2023, the Commission continued
overseeing the operational activities of the NESI. The summary of
the NESI’s operational performance report for 2023 is provided
below.

Available Capacity and Generation: In 2023, the average daily
available capacity of the twenty-seven (27) grid-connected power
plants was 4,544.13MW. The total generation during the year was
36,710.38GWh which translates to an average hourly generation
of 4,190.68MWh/h. The overall availability factor for all gridconnected plants was 35.90%, which indicates that more than 64%
of the installed capacity in the NESI was not available in 2023.
Hydropower plants contributed 9,086.90 GWh (24.75%) to the
total generation in 2023.

* * *

Table E: System Collapses in 2020 - 2023

|  | No. of Collapses |  |  |  |
| --- | --- | --- | --- | --- |
| Category of Collapse | 2020 | 2021 | 2022 | 2023 |
| Partial Collapses | 0 | 2 | 2 | 0 |
| Total Collapses | 4 | 2 | 4 | 3 |

In 2023,
672,539 end-use
customers meters
were installed by
the DisCos

st
Metering: As of 31 December 2023, only 5,842,726 (44.39%)
of the registered 13,162,572 customers in the NESI were metered.
DisCos installed 672,539 end-use customer meters in 2023.
25,847 meters were installed under the National Mass Metering
Program (NMMP) framework while 585,265 meters were installed
under the Meter Asset Provider (MAP) framework. Furthermore,
6,912 meters were installed through the Vendor Finance Metering
framework while 53 end-use customer meters were installed
through the DisCo Financed framework. The summary of customer
metering by DisCos is contained in Figure D.

31^{\\mathfrak{s t}}

Commercial report: The commercial performance of the NESI is a
measure of the flow of funds from customers to upstream electricity
industry players. The key parameters that are used in evaluating
commercial performance include:

Figure D: Metering Status in 2023

* * *

## Executive Summary NERC Annual Report 2023

- **Energy billed and billing efficiency**
- **Revenue and collection efficiency**
- **Remittances by downstream market participants to the** **Market Operator (MO) and the Nigerian Bulk Electricity** **Trading Company (NBET)**

## Energy offtake performance: In 2023, the total energy received by

## DisCos at their trading points was 29,979.46GWh. With the

## Commission’s effort to achieve market maturity and improved

## upstream payments, energy offtake by DisCos transited from

**2** **MYTO allocation to the Partial Activation of Contract (PAC)** **regime in July 2022 which enabled the DisCos to determine their** **unconstrained power requirements in absolute Megawatts (MW)** **known as their Partially Contracted Capacity (PCC).**

## The DisCos energy offtake performance in 2023 was 95.50%. Ten

## (10) DisCos took less energy than their PCC with only Eko DisCo

## taking up to 100% of its available PCC (offtake - 433.90MWh/h

## vs available PCC -402.93MWh/h). Yola (92.77%), Enugu

## (89.91%) and Jos (87.19%) DisCos recorded the lowest energy

## offtake performances.

## Billing and Collection efficiencies: Figure E shows the billing and

## collection efficiencies by all DisCos in 2023. Out of the

## 29,979.46GWh total energy received by all DisCos,

## 23,747.75GWh was billed to the end-users, resulting in a gross

## billing efficiency of 79.21%.

**2** **Under the MYTO allocation regime, the allocation of energy to DisCos was based solely on the ratios contained** **in the vesting contracts signed upon privatisation. Also, there was limited enforcement of PPA contracts which** **led to the non-recognition of capacity (and it associated payments) for most of the grid-connected power plants.** **Nigerian Electricity Regulatory Commission**

* * *

The overall
remittance in
2023 was
82.37%

Figure E: DisCos Billing and Collection Efficiencies in 2023

The total billings to electricity consumers by the DisCos was
₦1,463.24 billion of which only ₦1,077.51 billion was collected,
leaving a total outstanding of ₦385.73 billion and corresponding
to a collection efficiency of 73.64%.

Market Remittances by DisCos: In 2023, a total invoice of
3
₦858.03 billion was issued to all the DisCos for energy received
from NBET and for service charges by the MO, out of which a sum
of ₦706.73 billion was settled by DisCos, leaving a total deficit of
₦151.30 billion in the market. This payment translates to an overall
remittance performance of 82.37%

The disaggregated DisCo’s remittance performances to NBET and
MO in 2023 are presented in Figure F.

3
The NBET portion of the total invoice issued to DisCos has been adjusted for the Minimum Remittance
Obligation (MRO) of the DisCos.

* * *

Figure F: DisCos’ Remittance Performance in 2023

Eko and Yola DisCos had high remittance performances of
4
105.76% and 105.14% respectively to NBET in 2023 while
aduna achieved the lowest remittance performance to NBET
(17.59%). The highest remittance performances to the MO were
recorded by Yola, Eko and Ikeja at 90.91%, 90.85% and 90.38%
respectively while aduna recorded the lowest MO remittance
performance of 10.75% in 2023.

Market Remittances by Special and Bilateral Customers: In 2023,
the NESI continued to provide electricity to 3 international bilateral
customers - i) Societe Beninoise d’Energie Electrique; ii) Compagnie
Energie Electrique du Togo; iii) Societe Nigerienne d’electricite.
Cumulatively, these 3 customers received an invoice of $53.55
million from MO and made a payment of $50.36 million. This
corresponds to a remittance performance of 94.04%. There were
nineteen (19) active domestic bilateral customers in 2023.
Cumulatively, these customers received a total invoice of
₦10,320.84 million from MO and made a payment of ₦8,766.15
million corresponding to a remittance performance of 84.94%.

The
International
Customers made
a total payment
of $50.36
million out of a
total invoice of
$53.55 million
issued to them
by the MO.

4
Remittance performance above 100% is due to payment of outstanding invoices.

* * *

# Chapter One: Legal and Regulatory

# Framework

* * *

# 1.1 Background to the creation of the Commission

# 1.2 Legal Framework

# 1.3 Regulatory Functions

# 1.4 Reporting Obligations

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## 1.1 Background to the creation of the Commission

## In March 2001, the Federal Government of Nigeria (FGN) released the

## Nigerian Electric Power Policy (NEPP) in an attempt to arrest the challenges

## that had plagued electricity supply in Nigeria over the prior decades and

## heralded the prevalence of rolling blackouts to electricity consumers. These

## problems were caused by several factors including –

- **Gross inadequacy of available generation due to lack of investments in** **new generation plants and poor maintenance of installed plants;**
- **Poor and aged transmission and distribution infrastructure arising from** **limited investments and consequentially driving high technical losses** **along the network;**
- **Overall financial unsustainability and illiquidity of the electricity market** **caused by a combination of non-cost reflectiveness of tariffs and extreme** **levels of commercial losses.**

## The NEPP was adopted in 2002 and kickstarted the reform efforts of the FGN

## in the power sector which were ultimately geared towards transitioning the

## electricity market from a state-owned vertically integrated monopoly into a

## competitive, liberalised market with significant private sector participation at all

## steps of the value chain.

## One of the critical milestones under the reform program of the power sector

## was the enactment of the Electric Power Sector Reform Act (EPSRA) in 2004.

## The EPSRA gave legal authority and support to the reforms and repealed the

## National Electric Power Authority (NEPA) Act of 1972.

## The National Electric Power Authority (NEPA) was transitioned to the Power

## Holding Company of Nigeria (PHCN) which was subsequently unbundled into

## 18 separate companies consisting of six (6) Generation, one (1) Transmission

## Nigerian Electricity Regulatory Commission

* * *

and eleven (11) Distribution companies; thereby opening the market for private
sector investment/participation.

Furthermore, section (31) of the EPSRA provided for the establishment of the
Nigerian Electricity Regulatory Commission (“NERC” or the “Commission”)
which was mandated to serve as an independent regulatory body to drive the
power sector reform by ensuring fairness, transparency and a level playing
st
field for all stakeholders. The Commission was officially inaugurated on the 31
of October 2005 with its headquarters in Abuja.

In recognition of the evolution of the Nigerian electricity market following
almost a decade of privatisation of the generation and distribution segments of
the market as well as the need to push the market towards more efficient
competition, the Electricity Act 2023 was enacted in June 2023. The EA 2023
repealed the EPSRA 2004 and the four listed Acts related to the Nigerian
electricity market:

• The Hydroelectric Power Producing Areas Development Commission Act,
No. 7, 2010

• The Hydroelectric Power Producing Areas Development Commission Act,
2010 (Amendment) Act, 2013

• The Hydroelectric Power Producing Areas Development Commission Act,
2010 (Amendment) Act, 2018

By consolidating the various Acts that previously governed the sector, the EA
2023 seeks to ensure legislative consistency across the various segments and
stakeholders in the sector. In addition to recognising NERC as the apex
regulator for the Nigerian power sector, the EA 2023 has given the Commission
significantly increased enforcement powers. This is essential for allowing the

• The Nigerian Electricity Management Service Agency Act (NEMSA Act)
2015

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## Commission to put in place a robust accountability framework with adequate

## deterrence for all market participants.

## Since its inception, the Commission has continued to position itself to give robust

## regulatory interventions as the power sector transitions from a state-owned

## monopoly to a more competitive market structure.

## 1.2 Regulatory Functions

## The principal functions of the Commission as outlined under section 34(1) of the

## EA are as follows -

## A. To create, promote, and preserve efficient electricity industry and market

## structures, and ensure the optimal utilisation of resources for the

## provision of electricity services;

## B. To maximise access to electricity services, by promoting and facilitating

## consumer connections to distribution systems in both rural and urban

**areas;**

**C. To ensure that an adequate supply of electricity is available to** **consumers;**

## D. To ensure that the prices charged by licensees are fair to consumers and

## are sufficient to allow the licensees to finance their activities and to allow

## for reasonable earnings for efficient operation;

## E. To ensure the safety, security, reliability, and quality of service in the

## production and delivery of electricity to consumers;

## F. To ensure that regulation is fair and balanced for licensees, consumers,

## investors, and other stakeholders;

## G. To present quarterly reports to the President and National Assembly on

## its activities;

## Nigerian Electricity Regulatory Commission

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## H. To issue directives and carryout such measures to ensure the gradual

## development and smooth operation of the various stages of the market;

## I. To promote the development and utilisation of renewable energy

## services and increase the contribution of renewable energy in Nigeria’s

## energy mix;

## J. To promote cost-reflective and service-reflective tariffs and ensure

## gradual elimination of cross subsidies within a specified timeframe; and

## K. To promote gender mainstreaming and local content requirements within

## the NESI

## 1.3 Legal Framework

## The legislative bases for the powers conferred on the Commission in the EA

## 2023 are summarised below:

## A. Licensing: Section 34(2)(d) of the EA empowers the Commission to

## licence and regulate persons engaged in the generation, transmission,

## system operation, distribution, supply and trading of electricity.

## B. Enforcement and Sanctioning: Sections (63 and 64) of the EA describe

## the conditions of licences and the Commission's power to regulate the

## activities of licensees. The Commission is empowered with the legal

## authority to inquire into the activities of a person engaging or seeking to

## engage in any of the activities requiring a licence as defined in the EA,

## probe violations and impose penalties (including fines and imprisonment,

## forfeiture of undertakings) as well as licence cancellation to any person

## who contravenes the terms and conditions of licenses issued pursuant to

## the provisions of the Act.

## C. Generation of Electricity: The Commission is obligated to promote

## electricity generation from renewable energy sources, as enshrined in

## Nigerian Electricity Regulatory Commission

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## Section (80) of the EA 2023. In granting licences, the Commission is

## mandated to promote embedded generation, hybridised generation, co-

## generation, and electricity generation from renewable sources such as

## solar energy, wind, small hydro, biomass and other renewable sources

## as defined by the Act or may be developed.

## D. Transmission of Electricity: Sections (108 - 112) of the Act mandate the

## Commission to oversee electricity transmission in the NESI. In addition to

## specifying the demarcation of the National Control Centre, the Act also

## specifies the Commission’s powers with respect to third-party investment

## in the national grid as well as independent transmission network

## operators. The Commission is granted clear powers with respect to its

## role in ensuring the economic viability of investments while actively

## supervising and controlling the stability and efficiency of the national

**grid.**

**E. Distribution and Supply of Electricity: Sections (113 – 115) of the Act** **mandate the Commission to oversee the Distribution and Supply of** **Electricity in the NESI. Section 113(2) empowers the Commission to** **conduct biennial reviews of distribution licensees, ensuring power source** **adequacy, distribution system maintenance, and effective consumer** **complaint resolution. Section (114) emphasises the need to ensure the** **installation of proper meters for accounting and audit purposes, while** **Section (115) empowers the Commission to issue regulations to ensure** **the recovery of arrears for electricity supplied while specifying conditions** **for enforcing outstanding bills against new occupants.**

## F. Tariffs and Subsidies: The Commission is mandated to oversee tariff

## regulation and subsidy management in accordance with Sections (116)

## and (117) of the Act, ensuring that licensees operate efficiently and

## recover their full costs with a reasonable return on investment. The

## Nigerian Electricity Regulatory Commission

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## activities subject to tariff regulation as enshrined in the Act include

## generation, trading, transmission, distribution, supply, and system

**operations.**

**G. Consumer Protection and Licensee Performance Standards: Sections** **(119 -120) of the Act mandate the Commission to develop various** **consumer standards and procedures, in collaboration with licensees.** **These include customer service standards, quality of service and supply** **standards, customer complaint handling procedures, assistance** **procedures for customers facing bill payment difficulties, application** **procedures for electricity service, procedures for disconnecting non-** **paying customers, dissemination methods for consumer information, and** **procedures for responding to emergencies.**

## H. Competition and Market Power: The Commission plays a pivotal role in

## overseeing competition and market power within the NESI, as outlined

## in Section (121) of the Act. The Commission is mandated to report to the

## Minister of Power, on an annual basis, on the industry's potential for

## additional competition. The Commission is also mandated to prevent

## abuse of market power through various decision-making processes such

## as the grant of licences, pricing, and approval of mergers or affiliations.

## In case of identified market power abuses, the Commission is empowered

## to undertake enforcement actions such as issuing cease orders and

## levying fines as it deems appropriate.

## I. Renewable Energy and Energy Efficiency: Sections (164 - 171) of the

## Act empower the Commission to actively support and regulate the

## development and utilisation of renewable energy through measures

## including the simplification of licensing procedures, issuance of

## regulations, and establishment of technical standards.

## Nigerian Electricity Regulatory Commission

* * *

## Legal and Regulatory Framework NERC Annual Report 2023

## 1.4 Reporting Obligations

## 1.4.1 Quarterly Reports

## Pursuant to Section 34(1)(g) of the EA which states that - “the Commission shall

## present quarterly reports to the President and the National Assembly on its

## activities”, the Commission has published its four (4) quarterly reports for 2023.

## The reports contain analyses of the state of the Nigerian electricity industry

## (covering both the operational and commercial indices), regulatory functions,

## consumer affairs, the Commission’s finances, and staff development during

## each quarter.

## 1.4.2. Financial Reports

## The financial activities of the Commission and the associated reporting

## requirements are governed by sections 56(1) and 56 (2) of the EA 2023.

## Section 56(1) stipulates that “the Commission shall ensure that proper accounts

## and other records relating to such accounts are kept in respect of all the

## Commission's activities, funds and property, including such particular accounts

## and records as the Minister may require”. Section 56(2) of the EA states that

## “The Commission shall, not later than three months, after the end of the financial

## year, prepare and submit to the Auditor General of the Federation and

## National Assembly, a statement of accounts in respect of that financial year.”

## In compliance with the above, the Commission engaged Messrs

## PricewaterhouseCoopers (PwC) to audit the Commission's account for the year

## that ended 31st December 2023. A summarised report of the audited

## statements is contained in Chapter 8. Furthermore, each quarterly report for

## 2023 included a summary of the Commission’s financial position for the

**quarter.**

## Nigerian Electricity Regulatory Commission

* * *

# Chapter Two: Human Resource

# Management

* * *

2.1 Board of Commissioners
2.2 General Managers

2.3 Secretary of the Commission
2.4 Management Staff
2.5 Forum Office Secretaries
2.6 Staff Composition

* * *

2.1 Board of Commissioners

Engr. Sanusi Garba
Chairman/CEO

Musiliu O. Oseni, PhD
Vice Chairman
Commissioner Market Competition & Rates

* * *

## Human Resource Management NERC Annual Report 2023

**Chidi Ike** **Dafe C. Akpeneye** **Commissioner Engineering Performance &** **Monitoring** **Commissioner Legal, Licensing &** **Compliance**

**Aisha Mahmud Mrs.** **Commissioner Consumer Affairs**

**Nathan R. Shatti Yusuf Ali, PhD** **Commissioner Finance & Management Services Commissioner Planning Research & Strategy**

## Nigerian Electricity Regulatory Commission

* * *

2.2 General Managers

The General Manager (GM) is the pinnacle that any staff can attain over the course
of their career in service of the Commission. GMs (or the most senior staff) usually
act as the administrative heads of the division and work closely with the
Commissioners who provide executive oversight to the division. In a Commissioner’s
absence, the GM may take over some of the executive responsibilities of the
Commissioner. As of 31 December 2023, the Commission had six (6) GMs who are
listed in Table 1.

Table 1: General Managers of the Commission as of December 2023

| Name | Designation | Date Appointed |
| --- | --- | --- |
| Sharfuddeen Mahmud | GM, Finance & Management Services(FMS) | 01 January 2018 |
| Bassey N. Ayambem | GM, Planning, Research&Strategy(PRS) | 01 January 2018 |
| Dr Usman Abba-Arabi mni | GM, Public Affairs, Chairman's Office(CO) | 01 January 2018 |
| Abdulkadir Babakura Shettima | GM, Finance&ManagementServices(FMS) | 01 January 2018 |
| Zubairu T.Ahmadu | GM, Legal Licencing&Compliance(LLC) | 01 January 2021 |
| Maryam Y. Abubakar(Mrs) | GM, Procurement(CO) | 01 January 2021 |

2.3 Secretary of the Commission

The Secretary of the Commission heads the secretariat unit which is responsible for
providing administrative support to the Commission as well as the coordination and
preparation of the minutes of the meeting of the Board of Commissioners. As of 31
December 2023, the Commission’s Secretary was –

Ada Ozoemena (Mrs)

* * *

2.4 Management Staff

The management staff cadre is composed of GMs, DGMs and AGMs. The
Commission’s management staff as of 31 December 2023 are listed below (total
number – 37) except staff listed in sections 2.2 and 2.3 of this report.

Table 2: Management Staff of the Commission

| S/N | Name | Position | Unit and Division |
| --- | --- | --- | --- |
| 1 | Shittu Shaibu | DGM | Customer Service Standards, CA |
| 2 | Abba I. Terab | DGM | Tariff & Rates, MCR |
| 3 | Abdussalam Yusuf | DGM | Research, PRS |
| 4 | Abdullah Adamu | DGM | ICT, FMS |
| 5 | Sule Friday E. | DGM | Market Analysis, MCR |
| 6 | Hafsat Abdullahi Mustafa | DGM | Public Affairs, CO |
| 7 | Hauwa Yakubu | DGM | Compliance, LLC |
| 8 | Arit Uya | AGM | Consumer Complaints, CA |
| 9 | Michael Faloseyi | AGM | Public Affairs, CO |
| 10 | Kanneng Gwon | AGM | Customer Service Standards, CA |
| 11 | Zubair B. Zubair | AGM | Consumer Affairs, CA |
| 12 | Ene Effiom | AGM | Consumer Complaints, CA |
| 13 | John D. Joseph | AGM | Engineering&Standards,EPM |
| 14 | Jonathan Okoronkwo | AGM | Corporate Planning&Strategy,PRS |
| 15 | Abu Kadiri | AGM | Networks,EPM |
| 16 | Mary Anahve | AGM | Public Affairs,CO |
| 17 | Rasheed Busari | AGM | General Administration,FMS |
| 18 | Habib Kidaji | AGM | Human Resources Development,FMS |
| 19 | Saidu Lawal | AGM | ICT,FMS |
| 20 | Regina Osuagwu | AGM | Consumer Affairs,CA |
| 21 | Umar Mohammed | AGM | Research,PRS |
| 22 | Emeka Onyegbule | AGM | Market Competition and Rates,MCR |
| 23 | Ahmed Ndanusa | AGM | Chairman's Office,CO |
| 24 | Anthony Essien | AGM | Consumer Affairs,CA |
| 25 | Okpale Daisy | AGM | Licensing,LLC |
| 26 | Imam Mohammed | AGM | Health Safety and Environment,EPM |
| 27 | Bala Ado Shehu | AGM | Finance and Accounts,FMS |
| 28 | Iloeje Chukwuemeka | AGM | ICT,FMS |
| 29 | Azikiwe Chigozie V | AGM | Market Analysis,MCR |
| 30 | Ebehijele Edeh | AGM | RFRA,MCR |

* * *

2.5 Forum Office Secretaries

Section 44(1) of the 2023 Customer Protection Regulation (CPR 2023) states that
“The Commission shall establish Forum Offices across the country for the purpose of
hearing and resolving customer complaints in the operational area of every
Distribution Company”. Forum offices are designed to provide a touch point for
customers to file complaints against the Commission’s licensees. Therefore, a critical
aspect of the work of the forum office is the coordination of quasi-judicial hearings
of disputes between customers and licensees (mainly Distribution Companies –
“DisCos”).

Section 44(1) of the 2023 Customer Protection Regulation (CPR 2023) states that
“The Commission shall establish Forum Offices across the country for the purpose of
hearing and resolving customer complaints in the operational area of every
Distribution Company”. Forum offices are designed to provide a touch point for
customers to file complaints against the Commission’s licensees. Therefore, a critical
aspect of the work of the forum office is the coordination of quasi-judicial hearings
of disputes between customers and licensees (mainly Distribution Companies –

Section 43(9) of the CPR provides that if a customer is not satisfied with the resolution
of any complaints filed at the DisCos’ Customer Complaints Units (DisCos-CCU), such
customer may file a case to be adjudicated by the forum panel at the Forum Office.
The Forum Office is managed by the forum secretary while the hearings are
conducted by five (5) forum panel members
pursuant to the provisions of the CPR 2023. The list of the Commission’s forum
secretaries as of 31 December 2023 is contained in Appendix A.1.

Section 43(9) of the CPR provides that if a customer is not satisfied with the resolution
of any complaints filed at the DisCos’ Customer Complaints Units (DisCos-CCU), such
customer may file a case to be adjudicated by the forum panel at the Forum Office.
The Forum Office is managed by the forum secretary while the hearings are
5
conducted by five (5) forum panel members who are not staff of the Commission,
pursuant to the provisions of the CPR 2023. The list of the Commission’s forum
secretaries as of 31 December 2023 is contained in Appendix A.1.

1. A legal practitioner with experience in alternative dispute resolution nominated by the Nigerian Bar
   Association (NBA).
2. A financial expert nominated by either the Manufacturers Association of Nigeria, Nigerian Association

Association (NBA).
2\. A financial expert nominated by either the Manufacturers Association of Nigeria, Nigerian Association
of Chambers of Commerce, Industry, Mines and Agriculture (NACCIMA) or any other reputable
organisation.

3. A qualified electrical engineer nominated by either the Council for Regulation of Engineering in Nigeria
   (COREN) or the Nigerian Society of Engineers (NSE).

4. A nominee of the Federal Competition and Consumer Protection Commission (FCCPC).

5. A representative of an NGO based in the distribution company’s operating area nominated by the
   Commission.


* * *

2.6 Staff Composition

The total manpower of the Commission in 2023 was two hundred and fifty-two (252)
persons inclusive of the seven (7) commissioners. The Commissioners and members
of staff are experienced professionals from diverse backgrounds and disciplines
ranging from Engineering, Law, Sciences, Economics, Accounting and Finance,
amongst others. The detailed distribution of staff by division, cadre and gender is
presented in the sections below:

2.6.1 Distribution by Division

The distribution of staff in the year, across the different Divisions, is presented in
Table 3. The Finance & Management Services Division had the highest number of
staff; sixty-six (66), representing 27% of the total Commission’s staff, while the
Planning, Research & Strategy Division had the least manpower with sixteen (16)
staff, representing 7% of the staff in the Commission.

Table 3: Distribution of the Commission’s Staff by Divisions in 2023

| S/N | Divisions | Number of Staff | Percentage Share |
| --- | --- | --- | --- |
| 1 | Chairman's Office | 28 | 11% |
| 2 | Consumer Affairs (excluding Forum Offices) | 64 | 26% |
| 3 | Engineering, Performance & Monitoring | 19 | 8% |
| 4 | Finance&Management Services | 66 | 27% |
| 5 | Legal,Licensing&Compliance | 27 | 11% |
| 6 | Market,Competition&Rates | 25 | 10% |
| 7 | Planning,Research&Strategy | 16 | 7% |
|  | Total | 245 | 100% |

The distribution of staff by cadre as of 31 December 2023, is presented in Table 4.
The Commission had thirty-seven (37) senior management staff, one hundred and
four (104) mid-management staff, eighty-three (83) lower-level staff and twenty-one

Note: 1. The staff distribution excludes the seven Commissioners and their seven aides

* * *

(21) junior staff representing 15%, 42%, 34% and 9% respectively of the total
Commission’s staff.

Table 4: Distribution of the Commission’s Staff by Cadre in 2023

| S/N | Position | Number of Staff | Cadre | Total Number of Staff | Percentage Share |
| --- | --- | --- | --- | --- | --- |
| 1 | General Manager | 5 | Mgt Cadre | 37 | 15% |
| 2 | Deputy General Manager | 8 |  |  |  |
| 3 | Assistant General Manager | 24 |  |  |  |
| 4 | Principal Manager | 32 |  |  |  |
| 5 | Senior Manager | 38 | Senior Cadre | 104 | 42% |
| 6 | Manager | 34 |  |  |  |
| 7 | Assistant Manager | 31 |  |  |  |
| 8 | Analyst I | 34 | Middle Cadre | 83 | 34% |
| 9 | Analyst II | 18 |  |  |  |
| 10 | Junior Staff | 21 | Junior Cadre | 21 | 9% |
|  | Total | 245 | All Cadre | 245 | 100% |

2.6.3 Distribution by Gender

The distribution of staff by gender as of 31 December 2023 as illustrated in Figure
1 shows that approximately 31% of the professional workforce of the Commission
was female, which aligns with the Commission’s commitment to gender balance.

* * *

## Human Resource Management NERC Annual Report 2023

**31%**

**69%**

**Figure 1: Distribution of the Commission’s Staff by Gender in 2023**

## 2.7 Capacity Development

## The Commission places a high premium on capacity development of its staff as it

## recognises that the quality of personnel impacts significantly on the quality of its

## operations and activities. In 2023, the Commission continued the implementation of

## its capacity-building strategy by providing training to staff based on skill gaps. Staff

## were also sponsored to attend workshops, conferences, and meetings on issues

## pertinent to the discharge of the Commission’s functions.

## Members of staff of the Commission were sponsored to attend annual conferences

## of their respective professional bodies among which included the CIPM- Chartered

## Institute of Personnel Management of Nigeria, NIPR- Nigerian Institute of Public

## Relations, NIM-Nigerian Institute of Management, ICAN-Institute of Chartered

## Accountants of Nigeria, ANAN- Association of National Accountants of Nigeria,

## NSE- Nigerian Society of Engineers and the NBA- Nigerian Bar Association.

## Nigerian Electricity Regulatory Commission

* * *

## Human Resource Management NERC Annual Report 2023

## 2.8 Promotion, Awards, Recruitment and Retirement

## In pursuit of a merit-based work environment that incentivises excellence among its

## staff, the Commission conducts transparent promotion exercises annually for eligible

**staff based on the provisions of the “Conditions of Service”. At the end of the 2023** **exercise, staff who satisfied the stipulated requirements were duly promoted.**

## The Commission also held an award ceremony to recognise staff who had exhibited

## excellence in the delivery of their duties. Long-service awards were also presented

## to staff who had achieved notable milestones in the number of years of meritorious

## service they have delivered to the Commission.

## Furthermore, the Commission concluded its recruitment process which commenced

## in 2022 to employ suitably qualified Nigerians to join its workforce. The newly

## employed staff cut across the various cadres and divisions of the Commission and

## were successfully onboarded into their respective roles.

## In 2023, the total number of staff that exited the services of the Commission was

## twelve (12) – seven (7) resignations, four (4) retirements and one (1) death.

## Nigerian Electricity Regulatory Commission

* * *

# Chapter Three: Corporate Governance

* * *

# 3.1 Structure of the Commission

# 3.2 Strategic Goals (2021-2023)

# 3.3 Highlights of the Commission’s activities in 2023

* * *

## Corporate Governance NERC Annual Report 2023

## 3.1 Structure of the Commission

## The Commission maintained the same core organisational structure as of 2022

## with seven (7) divisions –

## Nigerian Electricity Regulatory Commission

* * *

## Corporate Governance NERC Annual Report 2023

## As part of its consistent efforts to improve the operational efficiency of the

## Commission, some intra-divisional changes were approved by the Commission;

## three (3) new units were created and three (3) units were collapsed into other

## functions within the Commission thereby maintaining the total number of units

## at twenty-four (24).

## This structure is expected to enhance the adequate flow of responsibility and

## authority along functional lines and staffing with professionally qualified

## personnel with the requisite skills and experiences to carry out their functions

**appropriately.**

## The current organisational structure of the Commission is represented in Figure

## 2\. Each unit is tasked with unique roles and responsibilities that culminate into

## divisional functions to drive the actualisation of the Commission’s goals.

## Nigerian Electricity Regulatory Commission

* * *

Figure 2: Structure of the Commission as of December 2023
Figure 2: Organisational Structure of NERC as of December 2023

Nigerian Electricity Regulatory Commission

* * *

## Corporate Governance NERC Annual Report 2023

## Nigerian Electricity Regulatory Commission

* * *

3.3 Highlights of the Commission’s activities in 2023

At all times, the Commission’s activities are guided by its strategic goals as well as
overarching government policy and macroeconomic trends. To this end, highlights
of some of the Commission’s activities for the year 2023 are summarised below -

A. External stakeholder engagement: The Commission is committed to ensuring
that stakeholders of the NESI are kept abreast of key initiatives of the
Commission as well as performance standards for licensees in the NESI. In
2023, the Commission undertook targeted campaigns through traditional and
social media channels covering pertinent industry issues including capping of
estimated bills, power sector recovery program, metering, health & safety as
well as consumer rights and obligations. The Commission also engaged
power sector policymakers and relevant civil society organisations in capacity
development. Key events held during the year include:

i. Biannual Health & Safety licensees managers meeting

ii. Quarterly NESI meetings

iii. Stakeholder workshop on the constitution amendment and new
Electricity Act 2023

iv. Capacity building workshop with the staff of FCCPC and NOA

v. Peer review meetings with regulatory compliance officers of
licensees

vi. Town hall meetings/Customer complaint resolution meetings across
different states in the country

vii. Radio jingles and social media campaigns

* * *

## Corporate Governance NERC Annual Report 2023

## i. Issuance of the Customer Protection Regulation (NERC-R-001-

## 2023). Some of the key highlights of this regulation include –

o **The definition of customer complaints has been revised to** **include any expression of dissatisfaction with a DisCo’s** **services or actions** o **The period allowed for DisCos to handle customer** **complaints has been shortened from 3 weeks to 2 weeks** o **The composition of NERC forum members has been revised** **to conform with the provisions of the Federal Competition** **and Consumer Protection Act 2019** o **Introduction of new connection options including overhead** **and underground networks of different phases, extra service** **for distant locations, and high-tension supply links** o **Improvement and updates to consumer service standards in** **the NESI to ensure that DisCos are held accountable for** **meeting the needs and resolving issues faced by consumers** **on time** **ii. Launch of the NESI call centre to provide a centralised portal for** **customers to pass complaints directly to their service providers and** **provide the Commission with near-real-time monitoring of customer** **complaint resolution by DisCos.** **iii. The Commission also launched its Power Outage Reporting System** **(PORS), a mobile application for real-time reporting of electricity** **outages by consumers.** **iv. The Commission opened an additional Forum Office in Ado Ekiti on** **29 September 2023 to enhance the timely resolution of customer** **complaints that were not satisfactorily resolved at the DisCo** **customer complaints units.** **Nigerian Electricity Regulatory Commission** v. The Commission facilitated nine (9) compensation meetings
between licensees and victims of accidents recorded in 2023

vi. The Commission issued the Order on compensation for SBT service
failure (NERC/2023/003). A key highlight of the Order is that it
provides for customers to be compensated in instances of service
failure where the service level on a feeder fails to meet 90% of the
committed service levels. Prepaid customers shall be compensated
with energy units while postpaid customers shall be billed based on
the actual service experienced during the period.

C. Improving health/safety and technical robustness of the grid system: Some of
the key activities implemented under this scheme include –

i. Establishment of a comprehensive scope for Supervisory Control
and Data Acquisition (SCADA)/Energy Management System
(EMS)

ii. Conduction of technical studies on the integration of Variable
Renewable Energy (VRE) into the national grid.

iii. Review of operating codes (Health & Safety Codes, Metering
Code) & NESIS Regulations

iv. Review of TCN’s Performance Improvement Plan

D. Enhanced transparency and stakeholder involvement in tariff reviews:
Pursuant to the provisions of the EA 2023 and NERC Regulations on the

Other key achievements during the year include:

o The study of harmonics and its effects on ATC&C losses,
power quality and system reliability

o The development of operational guidelines for Transmission
System Operator (TSO) and Distribution System Operator
(DSO)

* * *

## Corporate Governance NERC Annual Report 2023

## Procedure of Electricity Tariff Reviews in the NESI 2014, in evaluating the

## tariff review applications made by DisCos, the Commission introduced the

## rate-case hearings. This is consistent with international best practice in rate-

## setting and provides a platform for customers, customer advocacy groups and

## intervenors (industry experts and representatives of established organisations

## related to the power sector) to interrogate the submissions made by the

## DisCos in support of their applications. The Commission completed the review

## of applications by DisCos for extraordinary tariff review and conducted rate

## case hearings in July 2023.

## Nigerian Electricity Regulatory Commission

* * *

# Chapter Four: Regulation, Licensing &

# Compliance

* * *

4.1 Regulations, Orders and Guidelines
4.2 Regulations
4.3 Orders
4.4 Licensing
4.5 Permits and Authorisations
4.6 Compliance Monitoring and
Enforcement
4.7 Alternative Dispute Resolution among
market participants

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## 4.1 Regulations, Orders and Guidelines

## Section 34 of the Electricity Act 2023 (EA 2023, the Act) provides that the

## Commission is empowered to “licence and regulate persons engaged in the

## generation, transmission, system operation, distribution, supply and trading of

## electricity” in the NESI. In exercising the powers conferred on it by the Electricity

## Act 2023, the Commission primarily engages with participants in the Nigerian

## Electricity Supply Industry (NESI) through selected regulatory instruments as

## prescribed by law. The regulatory instruments utilised by the Commission include –

## A. Regulations: Regulations are detailed legal rules, and bye-laws formulated by

## the Commission pursuant to sections 46(2), 64, 215 and 226 of the Electricity

## Act, to govern and conduct operations within the electricity sector, ensure

## adherence to statutory requirements, and give effect to the implementation of

## the Act.

## B. Orders: Orders are authoritative commands, legally binding instructions, and

## directions issued by the Commission pursuant to sections 47, 64 and 215 of

## the Electricity Act, requiring licensees to perform certain actions, cease, desist

## from specific activities, or act in a particular way.

## C. Licences: Licences are authorisations granted by the Commission pursuant to

## sections 34(2)(d), 63(1), 64, and 215 of the Electricity Act, that allow entities

## to operate in activities such as the generation, transmission, trading and

## distribution of electricity under specified terms and conditions.

## D. Permits: Permits are authorisations issued by the Commission pursuant to

## sections 63(2), 64 and 215 of the Electricity Act, for specific activities, such

## as the generation of electricity for own use or authorisation to participate as

## a meter service provider.

## Nigerian Electricity Regulatory Commission

* * *

E. Guidelines: Guidelines are advisory documents, instructions, or rules issued
by the Commission pursuant to sections 64 and 215 of the Electricity Act, that
recommend practices and standards to sector participants, and licensees on
the procedure or process for a thing or an activity to be done or carried out
to achieve best practices and maintain consistency in operations.

F. Directives: Directives are enforceable orders issued by the Commission
pursuant to sections 64 and 215 of the Electricity Act, to address specific
issues, implement policies, or ensure compliance with regulatory objectives.

G. Rules: Rules are binding principles, instructions, and directives issued by the
Commission pursuant to sections 10, 64, and 215 of the Electricity Act, that
outline mandatory procedures, requirements, and standards for sector
participants and or licensees which must be adhered to.

H. Codes: Codes are comprehensive sets of rules, principles, guidelines and
technical standards issued or approved by the Commission pursuant to
sections 10, 34(2)(b), 64 and 215 of the Electricity Act, governing various
aspects of the electricity sector, including safety, reliability, and performance,
ensuring uniformity and high standards in technical and operational practices
across the sector.

Section 227 of the Act empowers the Commission to “make regulations prescribing
all matters which by this Act are required or permitted to be prescribed or which, in
the opinion of the Commission, are necessary or convenient to be prescribed for

4.2 Regulations carrying out or giving effect to this Act”. Regulations are a set of rules that the
Commission may issue periodically to optimise the performance of licensees to give
effect to the object of the EA 2023. The summary of the two (2) regulations issued
by the Commission in 2023 is contained below;

A. Customer Protection Regulations (CPR)

B. Mini-grid Regulations

A. NERC-R-001-2023: The Customer Protection Regulations (CPR) was issued in
March 2023 with the following objectives:

i. The consolidation of existing regulatory instruments of the Commission on
the protection of customers in the NESI into one regulatory instrument.

ii. The reinforcement of frameworks for the protection of end-use customers
in the NESI.

iii. The promotion of electricity access in the NESI.

iv. The alignment and updating of customer service standards in the NESI to
conform with international best practices.

v. The protection of the rights of end-use customers of distribution licensees
by specifying the minimum standards of service delivery.

i. Nigerian Electricity Regulatory Commission Customer Complaints
Handling Standards and Procedures.

ii. Nigerian Electricity Regulatory Commission Meter Reading, Billing, Cash
Collections and Credit Management for Electricity Supply Regulations.

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## iii. Nigerian Electricity Regulatory Commission Connection and Disconnection

## Procedures for Electricity Services.

## iv. Nigerian Electricity Regulatory Commission Customer Service Standards

## of Performance for Distribution Companies.

## v. Nigerian Electricity Regulatory Commission Methodology for Determining

## Connection Charges for Electricity Supply Regulations.

## B. NERC-R-117-2023: The Mini-grid Regulation was issued in December 2023 as a

## replacement of the Mini-grid Regulations of 2016 following a series of public and

## stakeholder consultations. In addition to stakeholder inputs, the new Regulation

## incorporates the changes and new provisions of the EA 2023. The major updates

## contained in the new Regulation include:

## i. The incorporation of portfolio applications, which allows developers to

## register multiple sites in a single submission.

## ii. Revision of the compensation mechanism for isolated mini-grid developers

## when a DisCo extends its network to the mini-grid site.

## iii. Refinement and redefinition of the Monitoring and Evaluation (M&E)

## framework, enforcement and reporting procedures.

## iv. Provision of a maximum of 15 business days allowance for DisCos to

## respond to developers' applications for information on a site. This is to

## forestall delays in application processing by DisCos.

## v. Definition of new caps for technical and non-technical losses for the

## determination of tariff for mini-grid projects using the MYTO methodology.

## 4.3 Orders

## Orders are a series of directions/instructions that the Commission issues to licensees

## to perform certain actions or desist from acting in a particular manner. Orders issued

## Nigerian Electricity Regulatory Commission

* * *

to licensees are situational and immediate in their impact and compliance. The
Commission issued sixteen (16) Orders to licensees in 2023. The summary of the
Orders issued by the Commission in 2023 is provided below:

A. NERC/001–012 /2023 — Orders on Reimbursement of Meter Costs for Meters
procured under the Meter Asset Provider and National Mass Metering Frameworks
(11 Orders issued to 11 DisCos). The objective of the Orders is to ensure the refund
of the cost of meters to all customers across the DisCos who paid for meters under
the MAP framework since its inception in 2018, through monthly energy credits.

The Order sought to ensure fairness, transparency and accountability of the
metering process as it provides a fair mechanism for the reimbursement of meter
costs to customers under the frameworks. Based on the Order, the cost of the
prepaid meter paid by the customers shall be amortised over 120 equal instalments
and reimbursed through energy credits computed based on the prevailing tariff at
the time of vending. Where a customer does not vend in a given month or months,
the DisCos shall at the point of the next vending, refund the accumulated energy
credits due to the customers for the period not vended. Where a postpaid customer
purchases a meter, the reimbursement by the DisCo shall be in the form of deductions
of fixed amounts from the monthly bill of the customer until the refund is complete.

i. Ensure that capital investment projects undertaken in the NESI are fully
aligned with the Performance Improvement Plan (PIPs) of the TCN and
DisCos with no stranded dependencies for providing service.

* * *

ii. Ensure optimal allocation of limited resources available for capital
expenditure in TCN’s procurement process in conformity with global best
practices for regulated utilities.

iii. Ensure optimal and prudent expenditure of limited resources on operating
expenditure by TCN.

iv. Ensure prudence and value for money for all network development
projects by TCN and DisCos.

The Order mandates that all capital expenditure by the TCN above ₦5 billion or a
revision of existing contract sums above 15% shall be reviewed by the Commission.
Based on the Order, the TCN is also required to file a proposed annual investment
st
plan and revenue requirements/budgets/estimates with the Commission by 31
October of the preceding financial year for approval.

C. NERC/2023/003 — Order on Migration of Customers and Compensation for
st
Service Failure under Service-Based Tariff Framework which took effect on 1 June
2023\. The objectives of the Order include:

i. Provide processes/procedures for migrating customers across service
bands in alignment with the quality of service provided to customers by
DisCos.

ii. Provide a framework for customer compensation and feeder service band
adjustment to account for DisCos’ failure to deliver on the Service Based
Tariff (SBT) committed service levels.

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## energy units while postpaid customers shall be billed based on the actual service

## experienced during the period.

## The Order further stipulates a revised procedure to DisCos for migrating customers

## between tariff bands (summary below):

## i. The DisCo shall file an application with the Commission for the proposed

## migration supported with key information including the name and location

## of the feeder, metering status of the feeder, quality of supply from the

## feeder covering a minimum period of two (2) weeks amongst other key

**information.** **ii. The Commission shall review the application and issue approvals for** **satisfactory applications within ten (10) working days of receipt of the** **migration request.** **iii. DisCos shall ensure that all affected customers receive notices of feeder** **migration at least five (5) days before implementation of the approved** **migration. The communication by DisCos must indicate the name of the** **feeder, the affected areas, and the current and proposed tariff/service** **bands.** **iv. The primary channel for notification of customers to be migrated shall be** **bulk SMS. DisCos shall also utilise their websites and other possible** **channels in addition to the bulk SMS for communication and continuous** **engagements with the affected customers.**

**v. Implementation of the approved migration shall take effect from the 1st** **day of the next billing month.**

## D. NERC/2023/005 — Order on Migration of Token Identifier of Standard Transfer

## Specification Meters from ey Revision 1 to ey Revision 2. The objectives of the

## Order are to:

## Nigerian Electricity Regulatory Commission

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## i. Ensure that all distribution licensees in the NESI migrate the Token

## Identifier (TID) of all Standard Transfer Specification (STS) meters in their

## network from key revision 1 to key revision 2 before 24th November

**2024.**

## ii. To ensure that customer vending is not constrained after 24th November

## 2024 on account of the inability to generate tokens.

## iii. Ensure that the distribution licensees develop clear and coherent

## communication strategies for the enlightenment of end-use customers and

## the general public on the migration of the TID of STS meters from key

## revision 1 to key revision 2.

## The STS describes a secure message system for carrying information between a

## point-of-sale and a meter currently being used in the Nigerian electricity metering

## and payment systems. The STS Association (STSA) maintains the STS technology

## and has mandated the migration of TID of all STS-compliant meters in the network

## of DisCos from key revision 1 to key revision 2 by 24th November 2024. This

## upgrade is necessary to prevent customer apathy from inability to vend, revenue

## loss to DisCos and risk of meter vandalism/bypass.

## E. NERC/2023/006 — Order on Deployment of Customer Engagement Platforms

## which took effect on 1st of September 2023. The objectives of the Order are to:

## i. Guide the minimum standards for the deployment of call centres by

## DisCos pursuant to section 119 of the EA 2023.

## ii. Standardise call centres deployed by DisCos for seamless integration

## with the Commission’s call centre.

## The NESI call centre is currently functional and provides an additional avenue for

## monitoring DisCos’ service quality and delivery to customers.

## Nigerian Electricity Regulatory Commission

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## F. NERC/2023/020 — Order on the Price Review of MAP Meters which took effect

**th** **on 6 September 2023. The objectives of this Order are to:**

## i. Ensure the fair and reasonable pricing of meters to both MAPs and end-

## user customers.

## ii. Ensure MAP’s ability to recover reasonable costs associated with meter

## procurement and maintenance while ensuring that their pricing structure

## allows for a viable return on investment.

## iii. Evaluate the affordability of meter services for customers, aiming to

## prevent excessive pricing that could burden end-users.

## iv. Ensure that MAPs can provide meters to end-use customers in the

## prevailing economic realities.

## The Order was issued following significant changes in macroeconomic indicators

## such as inflation and changes in foreign exchange rates. The Commission, through

## this Order, approved the review of MAP-issued meter prices from ₦58,661.69 to

₦81,975.16 and ₦109,684.36 to ₦143,836.10 for single and three-phased 4G **meters respectively.**

## 4.4 Licensing

**Section 63 (1) of the EA 2023 states that “without prejudice to the right of the States** **of the Federation to make laws and establish markets for the generation,** **transmission, system operation, distribution and supply of electricity within their** **respective territories, no person, except in accordance with a licence issued pursuant** **to the provisions of this Act or deemed to have been issued under section 213 (b)** **or as provided under this Act, shall construct, own, operate an undertaking other** **than an undertaking specified under subsection (2) of this section, or in any way** **engage in the business of: “**

## Nigerian Electricity Regulatory Commission

* * *

A. Electricity generation, excluding captive generation
B. Electricity transmission
C. Electricity distribution
D. Electricity supply
E. Electricity trading
F. System operation

The Commission as empowered by the EA 2023 regulates activities in the NESI and
grants licences for electricity generation, transmission, distribution, trading and
system operations in the NESI. The various types of licences granted by the
Commission include:

A. Generation Licence: This type of licence grants the holder the right to construct,
own, operate and maintain a generation station for the generation and supply of
electricity. The holder of a generation licence can sell electricity and ancillary
services to approved licensees including electricity trading companies, distribution
companies, eligible customers, single buyers etc. There are three (3) types of
generation licences:

ii. Embedded generation licence: This licence grants the licensee the right to
electricity generation and evacuation through an existing distribution
facility system or an independent distribution licensee. The embedded
generator licensee enters into a power purchase agreement with an
electricity distribution licensee (DisCo), or the operator of an independent
electricity distribution network.

* * *

iii. Off-grid electricity generation licence: This authorises a licensee to
generate and sell power to a single buyer (or community) without
connection to the national grid.

As of December 2023, the Commission has issued licences to thirty-one (31) gridconnected power plants in operation with a total nameplate capacity of 14,177MW.

Four (4) out of the thirty-one (31) power plants are hydropower plants while the
remaining are gas-fired thermal plants. Further details about the licenced gridconnected power plants are contained in Table 5.

* * *

Table 5: Details of licenced grid-connected Power Plant

| SN | Power Plant | Location | Ownership | Turbine Type | Installed Capacity | Fuel Type |
| --- | --- | --- | --- | --- | --- | --- |
| 1 | AES Barge | Lagos | IPP | Simple cycle gas turbine | 270MW | Gas |
| 2 | Aba Power | Abia | IPP | Simple cycle gas turbine | 140MW | Gas |
| 3 | Afam IV-V | Rivers | Privatised | Simple cycle gas turbine | 726MW | Gas |
| 4 | Afam VI | Rivers | IPP | Combined cycle gas turbine | 624MW | Gas |
| 5 | Alaoji | Abia | NIPP | Combined cycle gas turbine | 1,074MW | Gas |
| 6 | Azura | Benin | IPP | Simple cycle gas turbine | 450MW | Gas |
| 7 | Odukpani | Cross River | NIPP | Simple cycle gas turbine | 561MW | Gas |
| 8 | Egbin | Lagos | Privatised | Gas-fired steam turbine | 1,320MW | Gas |
| 9 | Geregu I | Kogi | Privatised | Simple cycle gas turbine | 414MW | Gas |
| 10 | Geregu II | Kogi | NIPP | Simple cycle gas turbine | 434MW | Gas |
| 11 | Ibom | Akwa Ibom | IPP | Simple cycle gas turbine | 190MW | Gas |
| 12 | Ihovbor | Edo | NIPP | Simple cycle gas turbine | 450MW | Gas |
| 13 | Okpai | Delta | IPP | Combined cycle gas turbine | 480MW | Gas |
| 14 | Olorunsogo | Ogun | Privatised | Simple cycle gas turbine | 336MW | Gas |
| 15 | Olorunsogo II | Ogun | NIPP | Combined cycle gas turbine | 675MW | Gas |
| 16 | Omoku | Rivers | IPP | Simple cycle gas turbine | 150MW | Gas |
| 17 | Gbarain | Rivers | NIPP | Simple cycle gas turbine | 225MW | Gas |
| 18 | Omotosho I | Ondo | Privatised | Simple cycle gas turbine | 336MW | Gas |
| 19 | Omotosho II | Ondo | NIPP | Simple cycle gas turbine | 450MW | Gas |
| 20 | Sapele ST | Delta | Privatised | Gas-fired steam turbine | 1,020MW | Gas |
| 21 | Sapele GT | Delta | NIPP | Simple cycle gas turbine | 450MW | Gas |
| 22 | Delta (Ughelli) | Delta | Privatised | Simple cycle gas turbine | 900MW | Gas |
| 23 | Trans-Amadi | Rivers | IPP | Simple cycle gas turbine | 136MW | Gas |
| 24 | Rivers IPP | Rivers | IPP | Simple cycle gas turbine | 180MW | Gas |
| 25 | Paras | Ogun | IPP | Simple cycle gas turbine | 96MW | Gas |
| 26 | Taopex | Lagos | IPP | Gas-fired steam turbine | 60MW | Gas |
| 27 | MEPP | Borno | Privatised | Simple cycle gas turbine | 50MW | Gas |
| 28 | Kainji | Niger | Concession | Reservoir | 800MW | Hydro |
| 29 | Jebba | Niger | Concession | Reservoir | 540MW | Hydro |
| 30 | Shiroro | Niger | Concession | Reservoir | 600MW | Hydro |
| 31 | Dadin Kowa | Gombe | Concession | Reservoir | 40MW | Hydro |

\*NIPP-Nigerian Integrated Power Projects, IPP-Independent Power Producers

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## B. Transmission Licence: This licence is granted for the construction, operation and

## maintenance of transmission systems within Nigeria, or that connects Nigeria with a

## neighbouring country at a voltage of 132kV or above. The Transmission Company

## of Nigeria (TCN) has the responsibility of transporting energy from power plants to

## DisCos and International customers and currently holds two licences; Transmission

## Service Provider (TSP) and System Operator (SO). The TSP owns and maintains the

## transmission infrastructure.

## C. System Operator: The SO is responsible for maintaining system stability, load

## balance, load dispatch and undertaking market operations responsibilities.

## D. Distribution Licence: The distribution licence authorises the holder to construct,

## operate and maintain a network operable at 33kV or lower to distribute electricity

## from grid supply points to the point of delivery to consumers or eligible customers.

## The licence authorises the holder to carry out installation, maintenance and reading

## Nigerian Electricity Regulatory Commission

* * *

of electricity meters as well as billing and collection of bills. The details of distribution
licensees as of December 2023 are given in Table 6.

Table 6: Distribution Licensees (DisCos) in the NESI

| S/N | DisCo | Franchise area(State/LG6) |
| --- | --- | --- |
| 1 | Aba Power(APLE) | Aba |
| 2 | Abuja(AEDC) | FCT,Niger,Kogi,Nasarawa |
| 3 | Benin(BEDC) | Edo,Delta,Ondo,Ekiti(Ado-Ekiti,Ikogosi Ekiti,Ipole-Iloro Ekiti) |
| 4 | Eko(EKEDP) | Lagos(Apapa,Festac,Ijora,Lekki,Ibeju,Ojo,Orile,Mushin,Victoria Island,Ikoyi) |
| 5 | Enugu(EEDC) | Enugu,Abia,Imo,Anambra,Ebonyi |
| 6 | Ibadan(IBEDC) | Oyo,Ogun,Osun,Kwara,parts of Ekiti |
| 7 | Ikeja(IE) | Lagos(Abule-Egba,Akowonjo,Ikeja,Ikorodu,Oshodi,Amuwo Odofin,Igando,Magodo,Ajao,Ijegun,Okefa,Shomolu) |
| 8 | Jos(JED) | Plateau,Bauchi,Benue,Gombe |
| 9 | Kaduna(KAEDC) | Kaduna,Sokoto,Kebbi,Zamfara |
| 10 | Kano(KEDCO) | Kano,Jigawa,Katsina |
| 11 | Port Harcourt(PHED) | Rivers,Cross River,Bayelsa,Akwa Ibom |
| 12 | Yola(YEDC) | Yola,Adamawa,Borno,Taraba,Yobe |

E. Trading Licence: This licence grants the holder the authority to purchase, resell
and trade electricity and ancillary services from independent power producers and
generation companies. All contracts for the purchase of electrical power and
ancillary services by the holder of the trading licence must be concluded in an open,
transparent and competitive manner and in accordance with the procedure
established by the Commission. In 2023, the Commission issued licences to seven
(7) electricity trading companies listed below. This is pursuant to the Commission’s
commitment to transition the Nigerian electricity market into bilateral wholesale
energy trading in compliance with the provisions of the EA 2023.

i. Commercio Electricity Exchange Limited

ii. Ecof Nigeria Limited

6
Local governments – LGs are written in italics

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## iii. Electric Utility Nigeria Limited

## iv. Onction Services Limited

## v. Ember Power Limited

## vi. Adefolorunsho Energy Network Limited

## vii. Midbelt Energy Company Limited

## 4.5 Permits and Certifications

## For activities which the EA 2023 does not explicitly grant the Commission licencing

## powers but which still require regulatory oversight, in line with international best

## practices, NERC issues permits or certificates to eligible companies/institutions to

## participate in those activities. Permits are authorisations that the Commission issues

## to entities that perform a regulatory activity with fewer licensing requirements while

## certificates are issued by the Commission to entities certified to have the skilled

## manpower to carry out specific activities in the NESI. The key activities for which the

## Commission issues permits or certificates are:

## A. Captive Power Generation: The Commission issues captive power generation

## permits to entities that aim to own and maintain power plants for generating

## power for their use and not for sale to a third party.

## B. Mini-grid: The Commission issues permits to mini-grid developers for the

## construction, operation, maintenance, and where applicable ownership of

## mini-grids with distribution capacity above 100kW and generation capacity

## up to 1MW while a registration certificate is issued to a mini-grid developer

## for one or more systems with a distribution capacity below 100kW.

**C. Meter Asset Provider (MAP): A MAP is an entity that is granted a permit by** **the Commission to provide metering services with roles that may include meter** **financing, procurement, supply, installation, maintenance, and replacement.**

## Nigerian Electricity Regulatory Commission

* * *

D. Meter Service Provider (MSP): An MSP is an entity certified by the
Commission as a manufacturer, supplier, vendor, or installer of electric
energy meters and/or metering systems.

The summary of licences, permits and certifications issued by the Commission in
2023 is contained in Table 7 and full details of the licensees are contained in
Appendix B.1 – B.4.

Table 7: Licenses, Permits and Certifications Issued by the Commission in 2023

| SN | License/Permit | Number |
| --- | --- | --- |
| 1 | On-grid generation | 1 |
| 2 | Off-grid generation | 8 |
| 3 | IEDN | 7 |
| 4 | Trading Licence | 5 |
| 5 | Embedded generation | 3 |
| 6 | Captive power | 15 |
| 7 | Mini-grid registration | 28 |
| 8 | Mini-grid permits | 18 |
| 9 | Meter service providers | 24 |
| 10 | MAP permit | 9 |
|  | Total | 118 |

4.6 Compliance Monitoring and Enforcement

Section 34(2)(f) of the EA 2023 specifies the powers of the Commission to “monitor
the operation of the electricity markets and sanction licensees in deserving
circumstances in accordance with the provisions of this Act and other subsidiary
legislation”. Furthermore, Section 64(1) of the Act states that “A licensee shall
comply with the provisions of its licence, regulations, codes, orders and other
requirements issued by the Commission from time to time”.

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

## instruments in the NESI. The primary enforcement mechanisms used by the

## Commission include:

## A. Notice to Commence Enforcement (NICE): this is a formal communication to

## a licensee informing them of the Commission’s intention to commence

## enforcement proceedings arising from their non-compliance with instructions

## issued by the Commission. The issuance of NICE is pursuant to the provisions

## of section 76(1) of the EA 2023.

## B. Rectification Directives: an Order or instruction to correct a mistake,

## submission or omission that ought to be done.

## C. Penalties: refers to a sanction or punishment imposed for violating a law,

## contract, rule, or regulation.

## D. Administrative fines: These are financial sanctions imposed by the

## Commission, to deter undesirable behaviour and encourage compliance.

## The summary of the various enforcement actions by the Commission in 2023 is

## contained in Table 8. As part of the effort to enforce compliance with all its

## regulatory instruments, codes and standards in the NESI, the Commission held a

## peer review meeting with the compliance and regulatory officers of licensees during

## the year to discuss the reporting obligations of licensees as well as health and safety

## matters. During the meeting, licensees' scorecards on compliance with health and

## safety standards, forum office decisions, and key performance indicators were

## discussed while highlighting areas of improvement.

## Nigerian Electricity Regulatory Commission

* * *

Table 8: Summary of enforcement actions carried out by the Commission in 2023

| S/N | Rectification Directive/(NICE) | Licensee | Date Issued | Deadline |
| --- | --- | --- | --- | --- |
| Rectification Directives |  |  |  |  |
| 1 | Failure to provide the World Bank's consultant with relevant information on their generator units for solar power integration studies. | 16 On-grid GenCos | 3 July 2023 | 14 July 2023 |
| 2 | Non-compliance to the Commission's directive to provide NBET with active and valid Bank Guarantees. | Abuja, Benin, Kaduna and Yola DisCos | 19 July 2023 | 3 August 2023 |
| 3 | Non-compliance with the Order on Performance Monitoring Framework | All DisCos | 11 August 2023 | 18 August 2023 |
| 4 | Report on electrocution caused by line snap | Benin DisCo | 11 August 2023 | 25 August 2023 |
| 5 | Failure to comply with two decisions of the Asaba Forum Office | Benin DisCo | 11 August 2023 | 18 August 2023 |
| 6 | Failure to comply with the decision of the Umuahia Forum Office | Enugu DisCo | 11 August 2023 | 18 August 2023 |
| 7 | Failure to comply with the decision of the Umuahia Forum Office | Enugu DisCo | 21 August 2023 | 30 August 2023 |
| 8 | Non-compliance with paragraphs D & F of the Order of the Commission requiring DisCos to file clear communication and public enlightenment plans on the migration of TID as well as roadmaps/project plans by 31 August 2023. | Eko, Enugu, Kaduna, Kano and Ikeja DisCos | 5 September 2023 | 12 September 2023 |
| 9 | Non-compliance with three (3) rulings of the Ikeja Forum Office. | Ikeja DisCo | 29 November 2023 | 12 December 2023 |
| 10 | Non-compliance with the Forum and Commission's decisions | Enugu DisCo | 16 October 2023 | 30 October 2023 |
| 11 | Non-compliance with the Commission's ruling in Appeal No: ANFO/NERC/423/2018 | Enugu DisCo | 16 October 2023 | 30 October 2023 |
| 12 | Non-compliance with the Commission's ruling in Appeal No: ANFO/2022/08/B975 | Abuja DisCo | 18 October 2023 | 31 October 2023 |
| Notice of Intention to Commence Enforcement Action(NICE) |  |  |  |  |
| 13 | Non-compliance with the Commission's directive to refund all customers affected by wrongful application of multiplier factor to bills. | Yola DisCo | 23 June 2023 | 14 days |
| 14 | Failure to comply with the request for information on all penalties for unauthorised access assessed and collected from end-use customers for January 2022 to December 2022, procedures for the assessment and collection as well as details of accounts into which penalties are deposited along with certified bank statements. | Enugu, Kaduna, Kano, Jos, Yola, and Benin DisCos | 1 August 2023 | 14 August 2023 |
| 15 | Failure to provide a detailed novation plan as requested by the Commission | NBET | 1 August 2023 | 14 August 2023 |
| 16 | Non-compliance with rectification directive issued following failure to file details of its information system infrastructure with the Commission | Enugu DisCo | 7 July 2023 | 21 July 2023 |

* * *

## Regulation, Licensing & Compliance NERC Annual Report 2023

**A cross-section of participants at the Compliance Peer Review training in Lagos, November 2023**

**4.7 Alternative Dispute Resolution among market participants**

## Alternative Dispute Resolution (ADR) refers to the settlement process instituted by

## the Commission for the resolution of disputes that may arise among market

## participants. Section 42.3 of the Market Rule empowers the Commission to appoint

## a Dispute Resolution Counsellor (DRC) and constitute a Dispute Resolution Panel

**(DRP).**

## Section 42.3.8 of the Market Rule stipulates that the DRP shall consist initially of at

## least three members and, upon the commencement of the Medium-Term Market,

## shall consist of at least ten (10) qualified persons, each of whom shall be appointed

## by the Commission.

## Pursuant to the Market Rules, the Commission has constituted a 10-person DRP and

## appointed a DRC responsible for arbitrating or otherwise resolving disputes between

## market participants. The DRP did not handle any disputes among industry

## stakeholders in 2023.

## Nigerian Electricity Regulatory Commission

* * *

# Chapter Five: Consumer Affairs and

# Stakeholder Engagements

* * *

5.1 Consumer Affairs

5.2 Customer Education

5.3 Customer Complaints

5.4 Stakeholder Engagements

* * *

## Consumer Affairs NERC Annual Report 2023

## 5.1 Consumer Affairs

## The Commission has developed various initiatives to ensure that electricity customers

## are aware of their rights and obligations and that customer care standards by

## licensees are according to international best practices. The main avenues of interface

## between the Commission and customers are:

## A. Customer Education/Town Hall meetings

## B. Customer complaints reporting channels

## 5.1.1 Consumer Education-Townhall Meetings

## The town hall/customer complaints resolution meetings are used to enlighten

## customers on the Commission’s activities and regulatory instruments, customer rights

## and obligations, and to facilitate swift resolution of complaints. These fora also

## provide avenues for the Commission to obtain feedback from customers which serve

## as input to the Commission in its decision-making process.

## In 2023, five (5) town hall/customer complaints resolution meetings were held at

## different locations across the country (Table 9) in collaboration with other

## government agencies including the Federal Competition and Consumer Protection

## Commission (FCCPC) and National Orientation Agency (NOA). During the

## meetings, discussions centred around several critical issues including customer rights

## and obligations, Service Based Tariff (SBT), metering gaps, estimated billing, energy

## caps, customer redress mechanism etc.

## Nigerian Electricity Regulatory Commission

* * *

Table 9: Town Hall Meetings held in 2023

| S/N | Date | DisCo | Location |
| --- | --- | --- | --- |
| 1 | 18-20 April 2023 | Jos | Jos |
| 2 | 09-11 May 2023 | Yola | Adamawa |
| 3 | 23-25 May 2023 | Benin | Asaba, Delta State |
| 4 | 07-09 November 2023 | Jos | Makurdi, Benue State |
| 5 | 22-23 November 2023 | Ikeja | Ikeja, Lagos State |

A cross-section of participants at the town hall/complaints resolution meeting held in Jos, April
2023

A cross-section of participants during the roadshow held to sensitise people about the town hall
meeting held in Adamawa, May 2023

* * *

## Consumer Affairs NERC Annual Report 2023

**A cross-section of participants at the town hall meeting held in Delta, May 2023**

**A cross-section of participants at the town hall meeting held in Makurdi, Benue State-November** **2023**

**A cross-section of participants at the town hall meeting held in Ikeja, Lagos State November 2023**

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## 5.1.2 Customer Complaints

## Pursuant to section 34(2)(c) of the Electricity Act 2023 which empowers the

## Commission to “establish appropriate consumer rights and obligations regarding the

## provision and use of electricity services” in the NESI, the Commission issued the

## Customer Protection Regulation (CPR) 2023 which adequately highlights the

## standards and procedures for handling customer complaints in the NESI.

## Furthermore, the Regulation provides a clear process flow for efficient customer

## complaint resolution in the NESI (Figure 3).

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

**Figure 3: Customer Complaint Flow chart**

## Nigerian Electricity Regulatory Commission

* * *

Consumer Affairs

5.1.3 Complaints Reporting Channels

Pursuant to the provisions of section 119(1)(c) of the EA 2023 which states that “the
Commission shall develop in consultation with licensees, the customer complaints
handling standard and procedure”, the Commission provides various channels for
customers to lodge complaints against their service providers. The primary channels
available for customers to lodge complaints in the NESI include:

A. NERC Customer Complaint Unit (NERC-CCU): This is a unit at the Consumer
Affairs Division of the Commission dedicated to the receipt and resolution of
complaints received directly from customers. Customers can lodge complaints
at the NERC CCU via emails, letters or phone calls (through the NESI Call
Centre).

The Commission launched the NESI call centre (NECC) in 2023 as one of its
initiatives geared towards improving customer experience in the NESI. The
NECC provides a centralised portal for customers to pass complaints directly
to their service providers. Being a centralised portal, it provides the
Commission with near real-time visibility into the filing and resolution of
customer complaints by the DisCos. Consequentially, this also allows the
Commission to monitor the DisCos’ compliance with customer service
standards of the CPR 2023.

B. DisCo Customer Complaint Unit (DisCo-CCU): The CPR 2023 mandates all
DisCos to establish customer complaint units (CCU) across their franchise area
dedicated to the receipt and resolution of complaints from customers.
Complaints can be lodged with the DisCo via electronic means including
phone calls, SMS, email, etc. Based on the CPR 2023, complaints received
by DisCos are to be resolved no later than 15 days of receipt, except where
it concerns meter accuracy and reconciliation of bills which should be
resolved within a billing cycle of one month. DisCos submit monthly customer
complaints reports which the Commission reviews to identify cases where
Nigerian Electricity Regulatory Commission 78 regulatory intervention is necessary. Any customer dissatisfied with the
outcome of handling his/her complaint at a DisCo’s CCU can refer such
complaints to the appropriate NERC Forum Office at the expiration of the
approved 30 days.

C. NERC Forum Offices: Forum offices serve as the “court of second instance”
for customers not satisfied with the resolution of their complaints at the DisCo-
CCU. As of 31 December 2023, the Commission had thirty-two (32)
operational Forum Offices in thirty (30) states and the FCT, Abuja. The details
including names, addresses and contacts of the Commission’s Forum Offices
are contained in Appendix C.4.

The Forum Office is managed by the forum secretariat while the hearings are
conducted by five (5) forum panel members who are not staff of the
Commission, as stipulated in the CPR 2023. The forum panels hear and
resolve customer complaints in the state in which it is situated, if there is no
Forum Office in a state, the Commission determines which neighbouring
Forum Office will have jurisdiction over the customer complaints from the
state. The composition of the forum panel is as follows:

i. A legal practitioner with experience in alternative dispute resolution
nominated by the Nigerian Bar Association (NBA).
ii. A financial expert nominated by either the Manufacturers Association

ii. A financial expert nominated by either the Manufacturers Association
of Nigeria, Nigerian Association of Chambers of Commerce, Industry,
Mines and Agriculture (NACCIMA) or any other reputable
organisation.

iv. A nominee of the Federal Competition and Consumer Protection
Commission (FCCPC).

* * *

## Consumer Affairs NERC Annual Report 2023

## v. A representative of an NGO based in the distribution company’s

## operating area nominated by the Commission.

## D. Power Outage Reporting System (PORS): On 12 September 2023, the

## Commission launched the PORS, which is a mobile application designed for

## electricity customers to report outages in real-time. Once outages are

## reported on the app by electricity consumers, the relevant DisCo is notified to

## allow it to immediately commence necessary remedial actions to restore

## power to the affected customers. When supply is restored, the Customers on

## the feeder may also receive notification via the app and can confirm that

## supply has been restored.

## The PORS provides data for the Commission to evaluate the compliance of

## DisCos with their service obligations to various feeders under the Service

## Based Tariff; failure to deliver the required service shall trigger the payment

## of compensation to the customers by the DisCos in line with the Order on

## Migration of Customers and Compensation for Service Failure under the

## Service Based Tariff Framework (NERC/2023/003) issued in May 2023.

**Stakeholders at the launch of the PORS app in Abuja, September 2023**

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## 5.1.4 Customer Complaints Received in 2023

## This subsection provides a summary of the types and relative resolution rates of the

## different customer complaints across the various channels explained in section 5.1.3

**above.**

## 5.1.4.1 NERC CCU

## Complaints are received through letters, emails and phone calls via the NESI call

## centre at the Commission’s CCU. In 2023, 7,207 complaints were received at the

## Commission’s CCU - Ikeja (3,752) and Eko (1,731) DisCos recorded the highest

## number of complaints by their customers accounting for 52.06% and 24.02% of the

## total respectively. Conversely, ano DisCo (16) and APLE (19) had the lowest

## number of complaints corresponding to 0.22% and 0.26% respectively.

## Cumulatively, 5,067 were resolved corresponding to a 70.31% resolution rate.

## The most common issues among the 7,207 complaints received were billing

## (37.67%), metering (32.84%), and service interruption (12.31%). The three (3)

## complaints categories cumulatively accounted for 82.82% of the total complaints in

## the year (Figure 4).

## Nigerian Electricity Regulatory Commission

* * *

Figure 4: Category of Complaints Received at the Commission’s CCU in 2023

5.1.4.2 DisCo-CCU

The total number of complaints received across all DisCos in 2023 was 1,220,245

- Ibadan and Port Harcourt DisCos received the highest complaints (207,216 and
  205,054 representing 16.98% and 16.80% of total complaints respectively). In
  comparison, Aba and Yola DisCos had the lowest complaints (4,029 and 11,930
  representing 0.33% and 0.98% of the total complaints respectively). Cumulatively,
  1,156,553 were resolved yielding a resolution rate of 94.78%.

The most common issues among the complaints received by DisCos during the year
were metering (53.09%), billing (16.30%), and service interruption (8.16%). These
three (3) complaints categories cumulatively accounted for 77.55% of the total
complaints in the year (Figure 5).

* * *

Figure 5: Category of Complaints Received by all DisCos in 2023

5.1.4.3 NERC Forum Offices

A summary of the appeals across the Forum Offices in 2023 is contained in Table
10\. In total, the Forum Offices had 10,144 (6,387 new appeals and 3,757 pending
appeals from 2022) active appeals through 2023. The Forum Office serving Ikeja
(2,689) and Ibadan (2,562) DisCos received the highest number of appeals
(corresponding to 26.51% and 25.26% of total appeals respectively) while Abuja
(243) and Yola (248) DisCos received the fewest appeals corresponding to 2.40%
and 2.44% of total appeals respectively.

Cumulatively, the Forum Offices had 359 sittings in 2023 and resolved 60.93%
(6,181) of the total active appeals. The breakdown of the various categories of
appeals received at the Forum Offices is presented in Figure 6. Billing was the most
prevalent complaint within the year, accounting for 61.41% of the total. Complaints
about metering and disconnection represented 23.90% and 5.28% of the appeals
respectively.

Cumulatively, the Forum Offices had 359 sittings in 2023 and resolved 60.93%
(6,181) of the total active appeals. The breakdown of the various categories of
appeals received at the Forum Offices is presented in Figure 6. Billing was the most
prevalent complaint within the year, accounting for 61.41% of the total. Complaints
about metering and disconnection represented 23.90% and 5.28% of the appeals

* * *

Table 10: Appeals Handled by Forum Offices in 2023

| Forum Offices | DisCos | Appeals Received¹ | Appeals Resolved | Appeals Pending² | Resolution Rate | No of Sittings |
| --- | --- | --- | --- | --- | --- | --- |
| Abuja, Lafia & Lokoja | Abuja | 243 | 166 | 76 | 68.31% | 25 |
| Ado-Ekiti,Asaba & Benin | Benin | 554 | 381 | 170 | 68.77% | 23 |
| Eko | Eko | 398 | 214 | 184 | 53.77% | 10 |
| Abakaliki,Akwa,Enugu,Owerri & Umuahia | Enugu | 1337 | 803 | 471 | 60.06% | 74 |
| Abeokuta,Ibadan,Ilorin&Osogbo | Ibadan | 2562 | 1411 | 992 | 55.07% | 77 |
| Ikeja | Ikeja | 2689 | 1667 | 1022 | 61.99% | 36 |
| Bauchi,Gombe,Jos&Makurdi | Jos | 166 | 107 | 37 | 64.46% | 27 |
| Gusau,Kaduna,Kebbi&Sokoto | Kaduna | 284 | 137 | 133 | 48.24% | 17 |
| Jigawa,Kano&Katsina | Kano | 307 | 171 | 118 | 55.70% | 17 |
| Calabar,Port Harcourt&Uyo | P/H | 1356 | 971 | 345 | 71.61% | 39 |
| Yola | Yola | 248 | 153 | 93 | 61.69% | 14 |
| All Forum Offices | All | 10,144 | 6,181 | 3,641 | 60.93% | 359 |

Appeals received include outstanding complaints from the preceding year as well as complaints rejected.
2\.
Some of the pending appeals are still within the regulatory timeframe of 2 months to resolve.

2\.
Some of the pending appeals are still within the regulatory timeframe of 2 months to resolve.

Figure 6: Category of Complaints Received by all Forum Offices in 2023

To ensure DisCos comply with the rulings of the Forum Offices, the Commission has
introduced “Compliance with forum rulings” as one of the indices contained in the

* * *

## Consumer Affairs NERC Annual Report 2023

## Order on Performance Monitoring Framework. As contained in the PI order, a

## DisCo is fined ₦10,000 per day for non-compliance with the forum ruling.

## Furthermore, the Commission is exploring strategies to improve the operational

## efficiency of Forum Offices such as ensuring that the forum panels sit regularly to

## increase the resolution rate and reduce the number of pending appeals carried over

## across years. The Commission also undertake regular training and capacity

## development for members of the forum panel to equip them to deliver on their

**mandates.**

## 5.2 Stakeholder Engagements

## The Commission engages relevant stakeholders as well as the public to appraise

## them of the Commission’s activities. The main avenues for interface between the

## Commission and stakeholders are:

## A. NESI stakeholder meetings

## B. Trainings/Workshops

## C. Other stakeholder engagement activities

## 5.2.1 Nigerian Electricity Supply Industry (NESI) Stakeholder Meetings

## The NESI meetings are periodic gatherings of all stakeholders in the NESI to

## deliberate on important industry issues and to review compliance and performances.

## The meetings usually have in attendance representatives of DisCos, GenCos,

## Transmission Service Provider (TSP), System Operator (SO), Market Operator

## (MO), Nigerian Bulk Electricity Trading (NBET) Company, Rural Electrification

## Agency (REA), other FGN Stakeholders and Development Partners (on an ad-hoc

## basis). Three NESI meetings were held in 2023 (Table 11).

## Nigerian Electricity Regulatory Commission

* * *

Table 11: NESI Meetings held in 2023

| S/N | NESI Meeting | Date | Location |
| --- | --- | --- | --- |
| 1 | Q1 NESI meeting | 06-07 March 2023 | Abuja, Nigeria |
| 2 | Q3 NESI meeting | 10-11 July 2023 | Lagos, Nigeria |
| 3 | Q4 NESI meeting | 09-10 October 2023 | Abuja, Nigeria |

Participants at the Q3 NESI meeting held in Lagos, July 2023

* * *

## Consumer Affairs NERC Annual Report 2023

**Participants at the Q4 NESI meeting held in Abuja, October 2023**

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## 5.2.2 Stakeholder Workshop on the 2023 Constitutional Amendment and

## Electricity Act 2023

## The Commission organised a stakeholder engagement workshop to review the

## impact of the Constitutional Amendment and the Electricity Act on the structure,

## operations, commercialisation and regulatory landscape of the NESI, and develop

## an actionable plan that will ensure an orderly transition to a multi-tiered regulatory

## regime. The specific aims of the workshop were to:

- **Bring all key stakeholders to the table to review the impacts of the** **constitutional changes on the industry structure and operations**
- **Gain a shared perspective on the outlook of the industry**
- **Agree on a plan for implementation**

## The two-day workshop was held between 13 - 14 July 2023 and was attended by

## key stakeholders in the sector including representatives from the Federal

## government, State governments, FMoP, licensees in the NESI, investors, and other

## critical stakeholders.

## At the end of the workshop, three thematic working groups (Table 12) were created

## to delve deep into the implications of the new dispensation envisaged in the EA

## 2023 and develop a roadmap for an orderly transition for the NESI. The

## composition of each working group is as follows:

- **Three (3) Federal representatives**
- **Three (3) State representatives**
- **Four (4) Licensees**
- **One (1) Independent Consultant**
- **One (1) Secretariat**

## Nigerian Electricity Regulatory Commission

* * *

Table 12: Thematic working groups to develop a roadmap for implementation of
EA 2023

| Committee | Mandate |
| --- | --- |
| Legal and Regulations | Evaluate the implications of the Amendment and the Act on the NESI and develop a common playbook that the States can adopt |
| Engineering and Technical | Evaluate the required changes to the technical interfaces and barriers and provide a framework for transition into a decentralised network |
| Commercial and Transactions | Develop a new commercial framework for the industry to implement the laws in the Amendment and the Electricity Act |

* * *

## Consumer Affairs NERC Annual Report 2023

**Participants at the EA workshop held in Lagos, July 2023**

## Nigerian Electricity Regulatory Commission

* * *

5.2.3 Other Stakeholder Engagements

The Commission held a series of other stakeholder engagements and activities during
the year, including workshops, training, customer service week celebrations as well
as hosting various stakeholders who paid courtesy visits to the Commission. The
summary of the Commission’s engagements with external stakeholders during the
year is contained in Table 13.

Table 13: Stakeholder engagements and other activities of the Commission in
2023

| S/N | Event | Date | Location |
| --- | --- | --- | --- |
|  | Training/Workshop |  |  |
| 1 | Electricity Consumers Enlightenment and Protection Workshop for Staff of the Federal Competition and Consumer Protection Commission(FCCPC)and National Orientation Agency(NOA) | 18-19July2023 | NERC HQ, Abuja |
| 2 | Training for newly recruited staff by the African Forum for Utility Regulators(AFUR) | 31 July-04August | NERC HQ, Abuja |
| 3 | Three-day training by the Nigeria National Accreditation System(NiNAS)for members of staff of the Engineering Division | 08-10August2023 | NERC HQ, Abuja |
| 4 | Two-day workshop for NESI stakeholders on Feeder Naming and Other Assets Nomenclature for the NESI | 10-11August2023 | NERC HQ, Abuja |
| 5 | A three-day workshop for Civil Society Organisations(CSOs)和Consumer Advocacy Groups | 28-30August2023 | Kano,Nigeria |
| 6 | Cost-Reflective Tariff training series sponsored by the U.S.Agency for International Development(USAID)and organised by the National Association of Regulatory Utility Commissioners(NARUC) | 13-15September2023 | NERC HQ,Abuja |
| 7 | One-day workshop organised by the African Forum for Utility Regulators(AFUR)on mini-grid tariff tools and methodologies | 18 September2023 | NERC HQ,Abuja |
| 8 | Three-day training for NERC Forum Panel members | 11-13October2023 | NERC HQ,Abuja |

* * *

NERC Annual Report 2023

| S/N | Event | Date | Location |
| --- | --- | --- | --- |
| 9 | Capacity strengthening workshop for DisCo's Heads of Corporate Communication | 27-29 November 2023 | Kano,Nigeria |
| 10 | Introduction to Arbitration Training for NERC staff | 12-13 December 2023 | NERC HQ,Abuja |
| Courtesy Visits |  |  |  |
| 11 | Courtesy visit by the Nigerian Institute of Electrical and Electronic Engineers(NIEEE) | 25 August 2023 | NERC HQ,Abuja |
| 12 | Courtesy visit by the Commandant of the Defense Intelligence College | 15 September 2023 | NERC HQ,Abuja |
| 13 | Courtesy call by a delegation from the Norwegian Water Resources and Energy Directorate(NVE) | 25 October 2023 | NERC HQ,Abuja |
| Other Activities |  |  |  |
| 14 | Launch of NERC Service Charter | 04 April 2023 | NERC HQ,Abuja |
| 15 | Commissioning of NERC Forum Office in Ado-Ekiti | 29 September 2023 | Ado-Ekiti,Nigeria |
| 16 | Customer Service Week Celebrations | 03-06 October 2023 | NERC HQ,Abuja |
| 17 | NERC and NESI Health and Stafey Managers meeting | 08-10November 2023 | Lagos,Nigeria |
| 18 | Peer review meeting with compliance and enforcement officers in the NESI | 20-21November 2023 | Lagos,Nigeria |
| 19 | Public hearing for the strategic review of the Performance Improvement Plan(PIP)of the Transmission Company of Nigeria(TCN) | 05December2023 | NERC HQ,Abuja |

* * *

## Consumer Affairs NERC Annual Report 2023

## A. Electricity Consumers Enlightenment and Protection Workshop for Staff of the

## Federal Competition and Consumer Protection Commission (FCCPC) and

## National Orientation Agency (NOA) \[18 – 19 July 2023\] - The workshop

## was aimed at strengthening partnerships with the FCCPC and NOA to

## guarantee the protection of the rights of electricity consumers.

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## B. Two-day workshop for NESI stakeholders on Feeder Naming and Other

## Assets Nomenclature for the NESI (10 -11 August 2023) - The workshop was

## aimed at developing a unified system for the naming of assets in the NESI.

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## C. A three-day workshop for Civil Society Organisations (CSOs) and Consumer

## Advocacy Groups (28 - 30 August 2023) - The workshop was organised by

## the Commission and aimed to enlighten participants on the steps the

## Commission is taking to address challenges in the NESI as well as regulatory

## instruments that have been developed to improve service standards and

## consumer protection in the NESI.

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## D. Cost-Reflective Tariff training series sponsored by the U.S. Agency for

## International Development (USAID) and organised by the National

## Association of Regulatory Utility Commissioners (NARUC) \[13 – 15\
\
## September 2023\]- The training was held at the Commission’s headquarters in

## Abuja as part of a series aimed at developing technical, commercial and legal

## regulatory frameworks to aid the power sector reforms in Nigeria.

## E. Commissioning of NERC Forum Office in Ado-Ekiti (29 September 2023)- The

## Forum Office was commissioned within the franchise area of Benin Electricity

## Distribution Company (BEDC).

## Nigerian Electricity Regulatory Commission

* * *

F. Customer Service Week Celebrations (03 – 06 October 2023) - The theme
of Y2023 Customer Service Week was “Team Service”. The week-long
activities included free medical care sessions, inter-divisional quiz
competitions, and indoor games amongst other activities.

* * *

## Consumer Affairs NERC Annual Report 2023

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## Nigerian Electricity Regulatory Commission

* * *

## Consumer Affairs NERC Annual Report 2023

## Nigerian Electricity Regulatory Commission

* * *

G. Courtesy call by a delegation from the Norwegian Water Resources and
Energy Directorate (NVE) to the Commission (25 October 2023)-The
delegation visited the Commission as part of its visit to critical stakeholders in
Nigeria to strengthen institutional and international collaborations.

* * *

H. 3-day Capacity strengthening workshop for DisCo’s Heads of Corporate
Communication (27 -29 November 2023). The workshop aimed at
identifying ways to simplify the communication of complex regulations to
consumers.

* * *

## Consumer Affairs NERC Annual Report 2023

## I. Public hearing for the strategic review of the Performance Improvement Plan

## (PIP) of the Transmission Company of Nigeria (TCN) \[05 December 2023\] -

## The stakeholder engagement was held at the Commission’s headquarters in

## Abuja. The engagement was to involve relevant stakeholders in the review of

## the PIP plan presented by the TCN.

## Nigerian Electricity Regulatory Commission

* * *

# Chapter Six: Electricity Tariffs

* * *

6.1 Introduction
6.2 Multi-Year Tariff Order (MYTO)
6.3 Tariff setting parameters
6.4 Tariff subsidies
6.5 Service-Based Tariff Regime (SBT)
6.6 2023/2024 Tariff Review

* * *

Electricity Tariffs

6.1 Introduction

The Commission is mandated by the EA 2023, section 34(1)(d), to ensure that prices
charged by licensees are fair to customers and sufficient to allow the licensees to
fully recover their efficient cost of operation. Pursuant to Section 76 of the now
repealed EPSR Act 2004 and in compliance with the provisions of Section 116 of
the EA 2023, the Commission has since 2007 adopted the Multi-Year Tariff
methodology for the determination of tariffs. Particularly, the Commission also
applies the building block approach to prepare the Multi-Year Tariff Order (MYTO)
issued to licensees.

6.2 Multi-Year Tariff Order (MYTO)

The MYTO is an incentive-based regulation that seeks to reward performance above
certain benchmarks, reduce technical and non-technical/commercial losses and lead
to cost recovery as well as improved performance standards from all industry
operators in the Nigerian Electricity Supply Industry. It is used to set cost-reflective
wholesale and retail prices for electricity in the industry by employing a unified way
to determine total industry revenue requirements tied to measurable performance
improvements and standards. The first MYTO was issued by the Commission in July
2008 and has been reviewed regularly with revised versions issued as necessary.

6.2.1 Objectives of the MYTO

A. Cost recovery/financial viability -regulated entities should recover their
(efficient) costs, including a reasonable rate of return on capital.

* * *

## Electricity Tariffs NERC Annual Report 2023

## B. Certainty and stability of the pricing framework which encourages an efficient

## level of investment.

## C. Incentives for improving performance – It provides incentives to reduce costs,

## improve quality of service and encourage efficient use of the network.

## D. Allocation of risk – It promotes the efficient allocation of risks.

## E. Simplicity and cost-effectiveness – It is easy to understand and implement.

## 6.2.2 Types of tariff reviews

## The MYTO provides a 15-year tariff path for the NESI. In 2014, the Commission

## issued the Regulations on Procedure for Electricity Tariff Reviews in the NESI which

## provides for the following types of reviews:

## A. Minor review: This is done to consider changes in a limited number of tariff-

## setting macroeconomic indices such as inflation, interest rates, exchange rates

## and generation capacity. Based on the regulation, minor reviews are to be

## conducted at least once in 6 months although minor reviews can be conducted

## annually, bi-annually or more frequently depending on the stability of

## macroeconomic indices.

**B. Major review: This is to be conducted once in five (5) years and entails a** **review of all inputs for tariff setting.**

## C. Extraordinary review: This type of review is conducted at the bequest of

## licensees. The Regulations allows licensees that require changes to their

## operating parameters to file for extraordinary tariff reviews following which

## the Commission conducts electricity rate case hearings.

## Nigerian Electricity Regulatory Commission

* * *

## Electricity Tariffs NERC Annual Report 2023

## 6.3 Tariff setting parameters

## The MYTO methodology uses a building blocks approach in setting Transmission

## and Distribution tariffs which provides the joint benefit of price cap and incentive-

## based regulation. The three building blocks are:

## A. The allowed return on capital –fair (market-based) rate of return on

## capital invested

## B. The allowed return of capital – recoup capital over the useful lives of the

## assets (depreciation)

## C. Efficient operating costs and overheads

## While the generation tariff is determined using a benchmark Long Run Marginal

## Cost (LRMC) of the most economically efficient new entrant, DisCo tariffs are

## determined by the building blocks to arrive at the utility’s revenue requirement and

## the volume of energy to be traded over a given period. The group of parameters

## which the Commission considers in determining or reviewing DisCos’ tariffs include:

## A. Macroeconomic indices: indices such as inflation rate, interest rate and

## foreign exchange rates are key assumptions for tariff setting in the MYTO

**model.**

**B. Aggregate Technical and Commercial Loss (ATC&C) targets and trajectories:** **ATC&C targets set the efficient loss levels that DisCos are expected to operate** **while still being able to earn their full revenue requirement. Failure to achieve** **the target ATC&C will negatively affect the DisCo’s long-term financial** **position. The ATC&C trajectory provided in the MYTO envisages that utilities** **will continually make investments including infrastructure modernisation,** **metering, etc. which will enable them to operate more efficiently.**

## Nigerian Electricity Regulatory Commission

* * *

C. Capital Expenditure (CAPEX): this involves the review of the utility’s
Regulatory Asset Base based on the CapEx investments made by the DisCo
pursuant to its approved Performance Improvement Plans (PiPs).

D. Operational Expenditure (OPEX): OPEX takes into consideration the costs a
DisCo incurs in its course of delivering electricity to customers including the
wholesale cost of energy. The OPEX of a DisCo can mainly be split into 2
categories – I) Fixed costs including rents, property insurance, property tax,
contracts, depreciation and amortisation II) Variable costs including
distribution operation and maintenance (labour, metering, line, street
lightning etc.), connection costs, service charge, administration and billing
costs.

E. Energy Offtake: based on the revenue requirement of the DisCo, the end-use
customer tariffs will be determined by the volume of energy to be traded by
the utility. DisCos can enjoy economies of scale - all things being equal, the
more energy a utility trades, the lower its price per unit of energy.

6.4 Service-Based Tariff Regime (SBT)

The MYTO 2020 aimed, amongst other objectives, to:

In August 2020, the Commission issued the MYTO 2020 which marked the
beginning of the Service Based Tariff (SBT) regime in the NESI. This underscores the
Commission’s commitment to ensuring that rates paid by customers are aligned with
the quality of service received.

* * *

A. Create a path towards transitioning to a fully service-based cost-reflective
tariff in the NESI

B. Disaggregate the pre-existing customers’ classes and clusters, reclassifying
them based on each DisCo’s commitment to service quality to them (which
comprises such factors as the quantum of energy delivered, its voltage, and
the DisCo’s average response time to resolving customer complaints)

C. Ensure that the tariff rates are aligned with the quality and availability of
electricity committed to customer clusters by the DisCos.

The customer clusters/classes specified in MYTO 2020 and expected service
delivery are contained in Table 14.

Table 14: Customer cluster and expected service delivery

| Service Band | Minimum hours of supply |
| --- | --- |
| A | 20 |
| B | 16 |
| C | 12 |
| D | 8 |
| E | 4 |

6.5 Tariff subsidies

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 energy 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 tariff Orders issued by the Commission.

* * *

parameters for each utility. Similarly, the allowed end-user tariff at each DisCo
considers the SBT principle, the rate design adopted by the DisCo and the
overarching Government policy on subsidy support. As a result, the tariffs payable
by the various customer classes of the different DisCos are not the same.

The 2023 cost-reflective tariffs, average allowed tariffs and the corresponding
subsidies required to bridge the revenue shortfall in the NESI are contained in Table
15.

Table 15: Average Tariff for Non-MD customers Across DisCos in 2023

| DisCo | CRT(№/kWh) | Allowed Tariff(№/kWh) | Subsidy(№/kWh) |
| --- | --- | --- | --- |
| Abuja | 83.35 | 63.24 | 20.11 |
| Benin | 88.04 | 63.24 | 24.8 |
| Eko | 79.77 | 60.06 | 19.71 |
| Enugu | 82.01 | 59.49 | 22.52 |
| Ibadan | 91.89 | 62.48 | 29.41 |
| Ikeja | 76.77 | 56.57 | 20.2 |
| Jos | 100.63 | 60.61 | 40.02 |
| Kaduna | 83.55 | 57.45 | 26.1 |
| Kano | 87.21 | 58.82 | 28.39 |
| PH | 88.88 | 61.4 | 27.48 |
| Yola | 190.55 | 65.99 | 124.56 |

\*CRT-Cost Reflective Tariff

On the other hand, Ikeja and Eko had relatively lower tariffs and subsidies. At the
national level, the average CRT was ₦86.10/kWh, while the average allowed tariff
was ₦60.06/kWh, resulting in an average subsidy of ₦26.04/kWh.

* * *

In line with the extant FGN policy to reduce subsidy intervention in the NESI and
effective from 2020, the Commission undertook minor tariff reviews which translated
to an increase in the ratio between the allowed tariff and the CRT from 55% in Jan
2020 to 94% in January 2023. Consequentially, the government’s subsidy
obligation was reduced from ₦501 billion in 2020 to ₦144 billion in 2022.

However, the FGN policy to unify FX rates in May 2023 combined with the lack of
minor reviews for H2 2023 resulted in a significant increase in the subsidy per kWh
(₦8.53/kWh in January vs. ₦26.04/kWh in December 2023). As a result, the
government’s monthly subsidy obligation increased from an average of ₦12.00
billion in 2023/Q1 to an average of ₦84.00 billion by 2023/Q4.

6.6 End-user Tariffs in Nigeria and Other West African Countries

The average allowed end-use customer electricity tariff in Nigeria in 2023 compared
to those of selected African countries (predominantly West African countries) is
presented in Table 16. On average, across 2023, the average customer tariff in
Nigeria was US$0.09/kWh (approximately ₦69.08) which was the lowest tariff
charged across the selected countries representing 48.46% of the average .

The average allowed end-use customer electricity tariff in Nigeria in 2023 compared
to those of selected African countries (predominantly West African countries) is
presented in Table 16. On average, across 2023, the average customer tariff in
Nigeria was US$0.09/kWh (approximately ₦69.08) which was the lowest tariff
7
charged across the selected countries representing 48.46% of the average .

| Country | Average Cost($) | Average Cost(№) |
| --- | --- | --- |
| Gambia | 0.215 | 165.03 |
| Benin Republic | 0.180 | 138.17 |
| Burkina Faso | 0.210 | 161.19 |
| Ghana | 0.140 | 107.46 |
| Guinea Bissau | 0.310 | 237.95 |
| Ivory Coast | 0.110 | 84.43 |
| Liberia | 0.275 | 211.09 |
| Mali | 0.210 | 161.19 |
| Mauritania | 0.160 | 122.81 |
| Mauritius | 0.132 | 101.32 |

* * *

Electricity Tariffs

| Country | Average Cost($) | Average Cost(N) |
| --- | --- | --- |
| Niger | 0.180 | 138.17 |
| Nigeria | 0.090 | 69.08 |
| Senegal | 0.230 | 176.55 |
| Sierra Leone | 0.130 | 99.79 |
| Togo | 0.200 | 153.52 |
| Uganda | 0.170 | 130.49 |
| Gambia | 0.215 | 165.03 |

1
Note: Average rate of tariffs is as of August 2023, at an exchange rate of NGN767.59/$1

The relatively low tariff in Nigeria is partly due to the tariff subsidy provided by the
Federal Government of Nigeria (“FGN”) and the relatively cheaper gas price to the
power sector in Nigeria.

6.7 2023/2024 Extraordinary Tariff Review

The FGN policy to unify exchange rates had a consequential impact on the wider
macroeconomic environment, including inflation rate. In a bid to ensure that these
changes did not negatively impact their ability to deliver service to customers and
pursuant to the provisions of the 2014 Regulations on Procedure for Electricity Tariff
Reviews in the NESI, all DisCos filed applications for extra-ordinary tariff reviews
with the Commission in June 2023.

6.7.1 Rate Case Hearing Process and Structure

The Commission conducted rate case hearings for all DisCos from 24 July to 08
August 2023, at its Headquarters in Abuja. A panel of three Commissioners

As part of their submissions, the Commission directed DisCos to include all data to
justify all assumptions and parameters that had been considered as part of their
analyses. Subsequently, the DisCos’ rate review applications were published on the
Commission’s website and notices were published in four (4) national newspapers,
soliciting stakeholder comments and participation in a public hearing on the rate
case application.

* * *

presided over the hearing in compliance with the Business Rules of the Commission,
8
while invitations were extended to critical sector stakeholders including consumer
groups to interrogate the submissions of the DisCos. Each DisCo was afforded
sufficient time to present the justification for its proposed tariff review following which
the panel, invited stakeholders and intervenors sought clarification and made
comments.

The highlights of the comments received on the applications included:

A. The need to minimise the exposure of electricity tariffs to fluctuations in
exchange rates and the international oil and gas market
B. The slow pace of meter rollout which contributes to higher losses and the cost
of the operations of utilities
C. Low quality of services rendered by utilities and non-adherence to the servicebased obligation
D. Need to ensure that the DisCos exclude assets contributed/procured by
customers from their revenue requirement
E. Concerns over the prudence of DisCos’ historic operating expenses (OpEx)
and capital expenditures (CapEx)

F. Concerns over corporate governance practices and internal control policies
inhibiting service delivery

The Commission duly considered the comments including the impact of changes in
macroeconomic variables, prudence in expenditure, and operational efficiency
parameters provided in the DisCos revenue requirement and resultant end-user
tariffs. Pursuant to section 116 of the EA 2023 and extant regulations, the

8
Federal Competition and Consumer Protection Commission (FCCPC), Nigerian Society of Engineers (NSE),
National Union of Electricity Employees (NUEE), Manufacturers Association of Nigeria (MAN), Nigerian
Association of Chambers of Commerce, Industry, Mines and Agriculture (NACCIMA), the Bureau of Public
Enterprise (BPE), Transmission Company of Nigeria Plc (TCN), registered intervenors (Appendix D.2).

* * *

Commission considered and approved cost-reflective tariffs for the DisCos with effect
from 01 January 2024. Notwithstanding, in line with the policy direction of the FGN
on electricity subsidy, the allowed end-user tariffs to be charged by DisCos were
frozen at the rates which became effective in January 2023 (Table 17).

Table 17: Cost-Reflective and Allowed Tariffs effective 01 January 2024

| DisCo | CRT(№/kWh) | Allowed Tariff(№/kWh) | Subsidy(№/kWh) |
| --- | --- | --- | --- |
| Abuja | 120.88 | 63.24 | 57.64 |
| Benin | 126.00 | 60.10 | 65.90 |
| Eko | 114.80 | 59.50 | 55.30 |
| Enugu | 127.70 | 59.00 | 68.70 |
| Ibadan | 126.10 | 62.50 | 63.60 |
| Ikeja | 112.10 | 56.60 | 55.50 |
| Jos | 138.90 | 60.60 | 78.30 |
| Kaduna | 129.40 | 57.50 | 71.90 |
| Kano | 128.20 | 58.80 | 69.40 |
| PH | 127.00 | 61.40 | 65.60 |
| Yola | 214.10 | 66.00 | 148.10 |

CRT-Cost-reflective tariff

* * *

Chapter Seven:
State of the Nigerian
Electricity Supply Industry
(NESI)

* * *

7.1 Operational Report
7.2 Grid Indices
7.2 Metering
7.3 Commercial Report

* * *

## State of the Industry NERC Annual Report 2023

## 7.1 Operational Report

## The operational performance of the NESI is a measure of how effectively available

## resources are utilised to generate electricity. Optimum operational performance is

## essential to ensure adequate, safe electricity generation, transmission, and supply.

## In evaluating the operational performance of the NESI in 2023 the following Key

## Performance Indicators (KPIs) were considered:

## A. Available generation

## B. Plant availability factor

## C. Total generation

## D. Generation load factor

## E. Generation mix

## 7.1.1 Available Generation

## In 2023, the average available generation capacity of the twenty-seven (27) grid-

## connected power plants was 4,544.31MW. A review of monthly data showed that

## during the year (2023), the average available generation capacity peaked in

## March, October and November respectively (Figure 7). The increased average

## available capacity in March was driven by improved mechanical availability of

## Egbin ST, Sapele, Delta GS, Omotosho, Olorunsogo, and Omotosho NIPP plants,

## while the increases in October and November were driven by improved availability

## of the hydropower plants (Shiroro, ainji, Jebba, and Dadin owa) owing to

## improved water reserves after the rainy season.

## Nigerian Electricity Regulatory Commission

* * *

Average Available Capacity 2023 4544.31MW

Figure 7: Average Available Capacity (MW) in 2023

7.1.2 Plant availability factor

The availability factor of a plant is measured as a ratio of the maximum rated output
of the plant declared by the operator (available capacity) relative to the maximum
rated output specified by the manufacturer (installed capacity). The available
capacity of a plant may change from time to time due to several factors including i)
atmospheric conditions at the plant; ii) mechanical availability of the plant (planned
and unplanned outages); iii) feedstock availability, etc. The formula for the plant
availability factor (PAF) is represented by equation 7.1.

The plant availability factor is a critical parameter for evaluating the overall health
of the upstream segment of the NESI. In 2023, the overall availability factor for all
grid-connected plants was 35.90%. This shows that more than 64% of the installed
capacity in the NESI was not available. Overall, seven (7) plants had availability factors above 50% with the Azura IPP plant recording the highest availability factor
of 88.94% (Table 18). Conversely, Olorunsogo NIPP had an availability factor of
4.27% and Alaoji NIPP recorded a 1.58% PAF because it was unavailable
throughout the fourth quarter due to feedstock (gas) unavailability.

Table 18: Plant Availability Factor (%) in 2023

| Plant | InstalledCapacity(MW) | Average AvailabilityCapacity2023 | Plant AvailabilityFactor(%)2023 |
| --- | --- | --- | --- |
| AzuraIPP | 461 | 410.03 | 88.94 |
| Paras | 85 | 67.03 | 78.86 |
| Okpai | 480 | 314.08 | 65.43 |
| Jebba | 570 | 362.78 | 63.65 |
| DadinKowaGTS | 40 | 24.38 | 60.95 |
| Shiroro | 600 | 335.07 | 55.84 |
| Kainji | 760 | 407.56 | 53.63 |
| Geregu | 435 | 211.00 | 48.51 |
| EgbinST(GAS) | 1320 | 633.11 | 47.96 |
| AfamVI | 650 | 311.24 | 47.88 |
| Odukpani | 625 | 260.91 | 41.75 |
| DeltaGS | 900 | 370.67 | 41.19 |
| RiversIPP | 180 | 70.11 | 38.95 |
| Omotosho | 304 | 117.95 | 38.80 |
| Ibom | 191 | 72.95 | 38.20 |
| Olorunsogo | 304 | 95.18 | 31.31 |
| Omoku | 150 | 42.79 | 28.53 |
| TransAmadi | 100 | 20.83 | 20.83 |
| OmotoshoNIPP | 500 | 100.26 | 20.05 |
| TaopexEnergy | 60 | 9.57 | 15.95 |
| SapeleGTNIPP | 452 | 68.36 | 15.12 |
| SapelaST | 720 | 89.94 | 12.49 |
| GereguNIPP | 435 | 39.14 | 9.00 |
| IhovborNIPP | 450 | 30.56 | 6.79 |
| AfamIV-V | 726 | 41.90 | 5.77 |
| OlorunsogoNIPP | 690 | 29.43 | 4.27 |
| AlaojiNIPP | 472 | 7.45 | 1.58 |
| Total | 12,660 | 4,544.30 | 35.90 |

The low overall availability factor of the power plants in the NESI is a major source
of concern to the Commission. The largest driver of plant unavailability in 2023 was
mechanical outages. Approximately 38.04% (4,802.80MW) of the total installed

* * *

## State of the Industry NERC Annual Report 2023

## capacity of grid-connected plants was unavailable due to mechanical outages . The

**age of many of the power plants (as of December 31 2023, the average plant in** **the NESI is 21 years old) and challenges with the maintenance of generating units** **are the biggest driving factors behind the mechanical outages. Other contributory** **factors to the low PAF experienced in the NESI include:**

- **Liquidity challenges at the upstream segment of the NESI (applicable to all** **GenCos): this is caused by the gross underpayment of GenCo invoices by** **DisCos (market shortfall) and the Government (unpaid subsidy costs). Without** **sufficient cash flows, GenCos cannot maintain their generation units, leading** **to extended outages. The liquidity challenges have also prevented operators** **of the privatised generation assets from recovering capacity that had been** **inoperable before privatisation.**
- **Gas supply challenges (applicable to thermal GenCos): Lack of reliable gas** **supply to the plants due to gas infrastructure constraints on the national gas** **network and the absence of fully effective Gas Supply Agreements (GSA). As** **of the end of December 2023, only five (5) plants out of the total twenty-three** **(23) thermal plants are operating with fully effective GSAs. This means that** **10** **the remaining eighteen (18) plants secure gas on a “best endeavour basis ”** **which puts them at great risk of having their supply curtailed by the suppliers** **when there is a reduction in gas production.**

## Improving the liquidity flows to the GenCos through greater enforcement of payment

## discipline on DisCos as well as the timely payment of subsidies by the Federal

## Government are essential to allow GenCos to fund much-needed capital expenditure

**9** **Any capacity that has not been operated in the past 1 year due to mechanical faults falls into this category** **10** **Best endeavour basis refers to a situation where parties (i.e., GenCos and Gas suppliers) transact without a** **fully effective contract, therefore there are limited service requirements and obligations between parties.** **Nigerian Electricity Regulatory Commission**

* * *

## State of the Industry NERC Annual Report 2023

## to reclaim units that have been inoperable for extended periods as well as fund the

## preventive maintenance of operable units to prevent long-term outages.

## To manage the overall availability of plants on the grid, the System Operator (SO)

## must implement the provisions of section 22.3 of the Grid Code on scheduling

**outages in a way that does not put the grid at risk of low gross availability.** **Furthermore, GenCos must engage with the gas subsector to align outages on the** **gas infrastructure (e.g. pipeline maintenance activities) with planned plant outages.**

## 7.1.3 Total Generation

**The hourly output produced by all the units in a power plant fluctuates based on grid** **demand, mechanical operability of the unit(s), and the availability of feedstock.** **Plants are only dispatched when the load on the grid is sufficient to offtake the energy** **while operating within acceptable technical limits. The factors that determine the** **dispatch of a plant include:**

## A. Plant availability (mechanical and feedstock)

## B. Load offtake on the grid

## C. Financial competitiveness of the plant in the economic merit order dispatch

## The gross generation on the National Grid in 2023 was 36,710.38GWh, which

## translates to an average hourly generation of 4,190.68MWh/h (equation 7.2).

**Total generation Ave. hourly generation (MWh)x 24 x total number of days in the year (7.2)**

## The average hourly generation was higher in the first quarter (Jan – March) and the

## fourth quarter (October – December) 2023, which is consistent with the expectations

## that the reservoir feeding the hydropower plants is sufficiently refilled during the

## rainy season (Figure 8).

## Nigerian Electricity Regulatory Commission

* * *

2023 continued a trend of relatively low average hourly generation in Q3 in spite
of the fact that it is the period when the rainy season commences. The reason why
the grid cannot utilise the increased hydropower plant availability during this period
is the fragility of the distribution network. When it rains, many of the DisCo’s feeders
often trip due to old age as well as non-compliance with the necessary engineering
standards.

Figure 8: Average Hourly Generation (MWh/h) in 2023

7.1.4. Average Share (%) of Generation Output

The contribution of eighteen (18) power plants out of the twenty-seven (27) gridconnected power plants, which account for 94.48% of the total electricity generated
in 2023 is presented in Figure 9. Egbin power plant had the highest average share
of generation output (14.09%) compared to the other power plants. ainji, Azura
IPP, Delta GS, and Jebba power plants had more than 8% average share of generation output respectively. Conversely, Sapele GT accounted for the lowest
share of output contributing 1.30% of the total energy generated within the year.

Figure 9: Average Share (%) of Generation Output by Power Plants in 2023

7.1.5 Generation Load Factor

The load factor is a measure of the utilisation of a power plant’s available capacity,
calculated as the ratio of the average electricity generated over a period to the
maximum possible generation (assuming all the available capacity is utilised all the
time over the period). A higher load factor means better capacity utilisation thereby
reducing the cost per unit of energy and increasing profitability, as fixed costs are
spread over a larger amount of dispatched energy. The load factor (also known as
the dispatch rate) reflects both the demand for energy and a plant’s ability to supply
it. The formula for load factor is represented by equation 7.3.

{sf}L o a d\ sf\\sf F a c t o r^{\ }=\\frac{{\\sf T o T a l}\ E n e r g y\ \\sf C n n e a a e d\ (M N W)}{{\\sf A v e.\ }A v a i i a b l e\ C o p e c i t y\ ((M W){\\times}24r s p\ p e r i o d\ (i n\ d a y s)}\\times100

× 100 (7.3)

* * *

## State of the Industry NERC Annual Report 2023

## The overall load factor for all grid-connected power plants in 2023 was 92.22%;

## meaning that only 7.88% of available energy (MWh) was not dispatched during

## the year. In the absence of a Supervisory Control and Data Acquisition (SCADA),

## and provisioning for spinning reserve, the SO and DisCos do not operate the system

## to its limit to allow for some inherent protection against grid disturbances. Therefore,

## it is almost impossible for grid-connected power plants to record load factors above

**~95%.**

## The load factors of the seven (7) power plants with the highest dispatch rates in

## 2023 are represented in Figure 10. Four (4) power plants (Omoku, Trans Amadi,

## Afam VI, and Olorunsogo) recorded dispatch rates of 100% while eighteen (18)

## power plants recorded dispatch rates above 90%. All hydropower plants except

## Shiroro (86%) recorded dispatch rates above 90% pursuant to the Commission’s

**11** **Order (Order No: NERC/182/2019) on mandatory and priority dispatch of** **hydropower plants.**

**100 100 100 100 98** **97 96** **88**

**(%)** **Load Factor** **Omoku Trans Amadi Afam VI Olorunsogo Olorunsogo Omotosho Delta GS Others** **NIPP** **Generation Companies**

**Figure 10: Plant Load Factor (%) in 2023**

**11** **The order stipulates that hydropower plants which are the cheapest energy generation source, should be** **dispatched with priority to reduce wholesale energy costs for consumers.** **Nigerian Electricity Regulatory Commission**

* * *

## State of the Industry NERC Annual Report 2023

## 7.1.6 Generation Mix

## The electricity generation mix refers to the combination of fuels used to generate

## electricity over a period. The composition of the generation mix varies across

## countries and is influenced by factors such as natural resource availability,

## government policies, environmental considerations, type of power plants, energy

## demand, and seasonal fluctuations. An ideal energy mix must balance the three key

## elements of the energy trilemma:

**12**

**A. Energy Security** **13**

**B. Energy Sustainability** **14**

**C. Energy Affordability/Equity**

## The formula for the share of electricity generated by fuel source is given by equation

**7.4.** **Total electricty generated from fuel i (MWh)** **Share of fueli× 100 (7.4)** **Total electricity generated from all fuel sources (MWh)**

## The contribution from hydropower plants to total generation in 2023 was 24.75%

## (9,086.90GWh). The NCC tracks the daily water levels at all hydropower plants

**and manages the dispatch of the plants to ensure that there is sufficient water in the** **plants’ reservoirs to allow them to run during the peak of the dry season albeit with** **limited output compared to the wet season. This is critical to grid stabilisation as it** **allows for year-round security of supply from the hydropower plants which are all** **located in the northern part of the Country.**

**12** **This reflects a nation’s capacity to meet current and future energy demands reliably, withstand, and bounce** **back from system shocks with minimum disruption to supplies.** **13** **This represents the transition of a nation’s energy system towards mitigating and avoiding potential** **environmental harm and climate change impacts.** **14** **This reflects a nation’s ability to provide universal access to affordable, fairly priced and abundant energy** **for domestic and commercial use.** **Nigerian Electricity Regulatory Commission**

* * *

7.2 Grid Indices

The Transmission Company of Nigeria (TCN) which has the responsibility of
transporting energy from power plants to distribution substations holds two licenses;
Transmission Service Provider (TSP) and System Operator (SO). The TSP owns and
maintains the transmission infrastructure while the SO is responsible for maintaining
system stability, load balance, load dispatch and undertaking market operations
responsibilities. To assess the performance of the grid, the Commission focuses on
the following four (4) ey Performance Indicators ( PIs) that relate to power
transmission:

A. Transmission loss factor

B. Stability of grid frequency

D. Incidence of system collapse

7.2.1 Transmission Loss Factor

Transmission Loss Factor (TLF) refers to the proportion of the total energy sent out
by the power plants that was either lost in transmission or utilised in the transmission
station i.e., neither delivered to the DisCos nor exported to local and international
bilateral customers. There is an inverse relationship between the TLF and the
efficiency of the transmission system; i.e. a decline in the TLF indicates an
improvement in transmission efficiency over a given period. The formula for TLF is
represented by equation 7.5.

The average TLF In 2023 was 8.17%, as shown in Figure 11. A TLF of 8.17%
indicates that for every 100MWh of energy injected into the grid, 8.17MWh of the

\\mathsf{T I F}\ =\ \\left(1\\cdot\\frac{\\mathsf{E n e r g y\ d e l i v e r e d\ t o\ a l l\ D i s C o s+E n e r g y\ E x p o r t e d}}{\\mathsf{E n e r g y\ S e n t\ o u l\ b y\ a l l\ G e n C o s}}\\right)right\ \\times100 energy was undelivered to DisCos and international customers due to losses in the
transmission network or consumption at the transmission substation.

The average TLF of 8.17% recorded in 2023 represents an under-performance of -
0.92pp relative to the MYTO target for 2023 (7.25%). The 7.25% TLF target set by
the Commission for 2023 represents the maximum efficient transmission loss, which
is to be paid by the customers. Exceeding the TLF target means that the Transmission
Service Provider (TSP) will not earn its full revenue requirement because there is no
provision to recover revenues needed to cover excess (inefficient) losses.

Figure 11: Actual TLF (%) vs. MYTO TLF Target (%) in 2023

7.2.2 Grid Frequency

Frequency is a crucial power quality parameter that industrial customers are
particularly concerned about due to the sensitivity of their heavy-duty machinery. In industrial production assembly lines, the machines are designed to operate only
within pre-set frequency tolerance limits and therefore often have a low tolerance
for frequency fluctuations. As specified in section 10.1.2 of the Grid Code, the
standard frequency for operation on the Grid is 50Hz.

The code provides that under normal circumstances, the grid can operate within a
deviation of ±0.5% i.e. between a lower limit of 49.75Hz and an upper limit of
50.25Hz. Section 10.1.2 of the Grid Code further provides that in extreme
circumstances, the grid may operate within a deviation of ±2.5% i.e. system
frequency may reach a lower bound stress limit of 48.75Hz and an upper bound
stress limit of 51.25Hz.

A system’s stability over a given period is measured by its ability to operate as close
as possible to the 50Hz benchmark set in the Grid Code; this means that the lower
the range between the average upper daily system frequency and the average
lower daily system frequency, the more stable the system has been. In 2023, the
average upper daily system frequency was 50.81Hz, while the average lower daily
system frequency was 49.04Hz, which translates to a range of 1.77Hz.

Figure 12: Monthly System Frequency (Hz) from Jan – Dec 2023

* * *

## State of the Industry NERC Annual Report 2023

**Figure 12 shows that the monthly average upper and lower bounds of the system**

## frequency were all outside the normal operation limits but within the stress limits

## throughout 2023. The consistent operation of the grid outside the normal frequency

## limits during the year 2023 indicates an imbalance in the supply and demand of

## electricity on the grid which is primarily caused by the lack of a Supervisory Control

## and Data Acquisition (SCADA) system.

## The System Operator (SO) has invested in an IoT-based solution to improve real-

## time visibility into the operations of the Grid. However, the inability to remotely

## operate the entire system as would be possible under the SCADA system continues

## to pose challenges to the SO’s ability to operate the grid within the normal

## operational frequency limits.

## 7.2.3 Voltage Fluctuation

## To guarantee the quality of electricity delivered to end users, the Grid Code specifies

## a nominal system voltage of 330kV with a tolerance range of ±5% (313.50kV to

## 346.50kV in the lower and upper bounds respectively). Fluctuations in grid voltage,

## including spikes, dips, flickers, and brownouts, can cause significant harm to

## consumers and result in substantial commercial losses. Extreme cases of voltage

## fluctuations, particularly at the distribution network level can cause severe damage

## to industrial machines.

## The system voltage pattern for 2023 is illustrated in Figure 13. The average lower

## and upper operating voltage bounds for the transmission network in 2023 were

## 298.23kV and 352.22kV respectively (range of 54.00kV); both values are outside

## the respective allowable limits which shows that the grid performance did not comply

## with the standard specified in the Grid Code.

## Nigerian Electricity Regulatory Commission

* * *

The Commission continues to engage with TCN and other stakeholders to ensure
sustained efforts at keeping the system voltage within the regulated limits, providing
a safe and reliable electricity supply to end users.

Figure 13: Monthly System Voltage (kV) from Jan – Dec 2023

7.2.4 System Collapse

The national power grid is a vast network of electrical transmission lines that link
power stations to end-use customers across the nation and it is designed to function
within specific stability boundaries, including voltage (330kV ± 5.0%) and frequency
(50Hz ± 0.5%). Any deviation from these stability ranges can result in decreased
power quality and, in severe cases, cause widespread power outages ranging from
a partial collapse of a section of the grid to a full system collapse.

(mathbf330\\mathrm{k V}\\pm5.0%)

* * *

frequency increases. In reaction to the grid operating at a frequency outside of the
normal operation range (especially when the frequency is too low), safety settings
on generation units may cause the units to shut down. This often exacerbates the
frequency imbalance on the grid thereby causing more generation units to shut down
resulting in a full or partial system collapse.

There were three (3) incidents of system collapses in 2023. Two of the incidents
occurred in the third quarter after three consecutive quarters (2022/Q4 to
2023/Q2) without any system collapse. The third incident occurred in the fourth
quarter. The details of grid collapse incidents between 2019 and 2023 are
contained in Table 19 and the summary of the causes of the three (3) incidents
recorded in 2023 are contained in Table 20.

Table 19: System Collapses in 2019 – 2023

|  | No. of Collapses |  |  |  |  |
| --- | --- | --- | --- | --- | --- |
| Category of Collapse | 2019 | 2020 | 2021 | 2022 | 2023 |
| Partial Collapses | 1 | 0 | 2 | 2 | 0 |
| Total Collapses | 10 | 4 | 2 | 4 | 3 |

* * *

Table 20: System collapse incidents in 2023

| SN | Date | Immediate Cause | Remote Cause | Inference |
| --- | --- | --- | --- | --- |
| 1 | 19thof September,2023(11:31hours) | The immediate cause was due to the tripping of some Generating Units of Kainji,Jebba,and Dadin KowaPower Stations under frequency protection. | The loss of lines G3B and S4Gisolated Delta power station generating units which led to a decrease in system frequency from50.20Hzto48.21HzThis was the remote cause of the system collapse. | When lines G3B and S4G were lost,this isolated some generating units atDelta Power Station.A load of346MW was lost and that resulted in a sharp decline in system frequency from50.20Hzto48.21Hz. |
| 2 | 14thof September,2023(00:41hours) | The immediate cause of the system collapse was due to the tripping ofKainji and Shiroro generating units on the grid resulting in the frequency-load imbalance. | The remote cause was the explosion of the Kainji and Jebba Line 2 blue phaseCapacitorVoltageTransformer and the burning of theblue isolator of Kainji and Jebba330kV line1which made the Jebbaunits to be on full speed no load condition | At00:40hours two generating units ofShiroro Power Station tripped and lost224MW of powerAt00:40:58hours,four generating units ofKainji Power Station trippedwith a generation loss of423MWbringing the total load lost to647MWand leading to a system collapse |
| 3 | 11thof December,2023 | Between13:48hrs&13:49hrs,there was a simultaneous tripping of four(4)330kVcircuits(Olorunsogo/IkejaWest,Osogbo/Ihovbor,Osogbo/IkejaWest,and Afam/Alaoji).Thisresulted in the loss of878.13MWdue to the separation ofEgbin, | Investigations indicate that the incident was potentially triggered bytwo(2)remote causesFirst,the multiple tripping ofinterconnected330kV circuitsis suspected to be a result of relaymaloperation or poor coordination. | The multiple tripping ofinterconnected330kV circuits andthe simultaneous tripping ofEgbin,OlorunsogoI&2,and Paras power plants resulted in the loss of878.13MWof power causing thesystem to collapse. |

:{\\bf r},

\\overline{19^{\\prime h}}

14^{t h}

11^{t}{}^{h}

* * *

State of the Industry

| SN | Date | Immediate Cause | Remote Cause | Inference |
| --- | --- | --- | --- | --- |
|  |  | Olorunsogo Ph I, & II, and Paras power plants located on the western axis of the grid. As a result, the grid frequency dropped from 50.25Hz to 48.01Hz which led to the cascaded tripping of several thermal and hydropower plants and the eventual collapse of the grid. | Second, the simultaneous tripping of Egbin, Olorunsogo I&2,and Paras power plants would have resulted from a disruption in gas supply via the western axis of the ELPS gas pipeline. |  |

* * *

7.3 Metering

The status of the metering of end-use customers is presented in Table 21. The total
number of registered customers as of December 2023 was 13,162,572 with
5,842,726 (44.39%) of the customers metered.

Table 21: Metering Progress as of December 2023

| DisCos | Total No.of Registered Customers2023 | No.of MeteredCustomers2023 | MeteringProgress(%)2023 | MeteringGap(%)2023 |
| --- | --- | --- | --- | --- |
| Aba | 191,405 | 54,462 | 28.45 | 71.55 |
| Abuja | 1,414,356 | 856,435 | 60.55 | 39.45 |
| Benin | 1,324,373 | 659,511 | 49.80 | 50.20 |
| Eko | 736,146 | 431,336 | 58.59 | 41.41 |
| Enugu | 1,396,440 | 616,210 | 44.13 | 55.87 |
| Ibadan | 2,401,864 | 1,046,873 | 43.59 | 56.41 |
| Ikeja | 1,238,295 | 898,202 | 72.54 | 27.46 |
| Jos | 730,402 | 243,049 | 33.28 | 66.72 |
| Kaduna | 864,128 | 206,076 | 23.85 | 76.15 |
| Kano | 872,656 | 210,338 | 24.10 | 75.90 |
| Port Harcourt | 1,179,194 | 494,246 | 41.91 | 58.09 |
| Yola | 813,313 | 125,988 | 15.49 | 84.51 |
| Total | 13,162,572 | 5,842,726 | 44.39 | 55.61 |

A total of 672,539 meters were installed across all DisCos in 2023. Ikeja (149,713),
Ibadan (125,759), and Abuja (105,154) DisCos had the highest number of meter
installations representing 22.26%, 18.70% and 15.63% respectively of the total
installations. Conversely, ano DisCo had the lowest number of installations (2,056)
accounting for 0.31% of the total installations (Table 22).

* * *

Table 22: Meter Deployment by DisCos in 2023

| DisCo | No. of Metered Customers as of December 2023 | No. of Customers Metered in 2023 | % of total installations |
| --- | --- | --- | --- |
| Aba | 54,462 | 54,462 | 8.10% |
| Abuja | 856,435 | 105,154 | 15.64% |
| Benin | 659,511 | 34,338 | 5.11% |
| Eko | 431,336 | 36,838 | 5.48% |
| Enugu | 616,210 | 73,256 | 10.89% |
| Ibadan | 1,046,873 | 125,759 | 18.70% |
| Ikeja | 898,202 | 149,713 | 22.26% |
| Jos | 243,049 | 12,680 | 1.89% |
| Kaduna | 206,076 | 10,039 | 1.49% |
| Kano | 210,338 | 2,056 | 0.31% |
| Port Harcourt | 494,246 | 48,989 | 7.28% |
| Yola | 125,988 | 19,255 | 2.86% |
| Total | 5,842,726 | 672,539 | 100% |

The five (5) frameworks that are available for DisCos to meter their customers are
contained in the Meter Asset Provider and National Mass Metering Regulations
(NERC-R-113-2021) which was issued in 2021. Descriptions of the frameworks are
contained below -

The five (5) frameworks that are available for DisCos to meter their customers are
contained in the Meter Asset Provider and National Mass Metering Regulations
(NERC-R-113-2021) which was issued in 2021. Descriptions of the frameworks are

C. Vendor Financed: This is a mutual agreement between a DisCo and a Local
Meter Manufacturer/Assembler (LMMA) or Meter Asset Provider (MAP) on

B. National Mass Metering Programme: This is a policy intervention with support
from the CBN for the provision of long-term (10-year tenure) single-digit
interest loans to DisCos strictly for the provision of locally
manufactured/assembled meters to customers.

* * *

a deferred payment arrangement where the base cost of meters shall not
exceed the regulated price approved by the Commission.

D. DisCo Financed: This involves the procurement of meters from other sources
outside the MAP and NMMP framework. The allowable costs of meters,
accessories, installation and warranties should not exceed the regulated
pricing approved by the Commission and the terms of supply should not be
in conflict with terms of existing MAP and NMMP contracts.

E. Other External Efficient Meter Financing: The Commission has also approved
other external meter financing that are efficient, cost-effective, and in tune
with the terms of existing MAP and NMMP contracts.

Table 23: Meter installations under the metering frameworks

| S/N | Framework | Meter Installations in 2023 |
| --- | --- | --- |
| 1 | NMMP | 25847 |
| 2 | MAP | 585265 |
| 3 | DisCo Financed | 53 |
| 4 | Vendor Financed | 6912 |

A total of 25,847 meters were installed under the NMMP framework in 2023 (Table

of meter installations representing 64.12%, 24.47% and 8.95% respectively of
customers metered under the framework in 2023. Jos (529), aduna (99), and
Ibadan (7) DisCos recorded the least meter installations. Abuja, Enugu, Ikeja, ano
and Port Harcourt DisCos have achieved 100% meter installations from the meters
allocated for customers within their franchise area under the framework.

of meter installations representing 64.12%, 24.47% and 8.95% respectively of
customers metered under the framework in 2023. Jos (529), aduna (99), and
Ibadan (7) DisCos recorded the least meter installations. Abuja, Enugu, Ikeja, ano
and Port Harcourt DisCos have achieved 100% meter installations from the meters
allocated for customers within their franchise area under the framework.

* * *

## State of the Industry NERC Annual Report 2023

## 21.49%), Abuja (103,200; 17.63%), Enugu (73,256; 12.52%), and Port Harcourt

## (48,989; 8.37%) DisCos that have completed their meter installations under the

## NMMP framework, recorded the highest number of meters installed under the MAP

## framework in 2023. aduna (9,887; 1.69%), Yola (2,681; 0.46%), and ano

## (2,056; 0.35%) recorded the lowest meter installations under the MAP in 2023.

## A total of 6,912 meters were installed under the Vendor Finance metering

## framework in 2023. Only three (3) DisCos; Benin (2,849), Ikeja (2,109), and Abuja

## (1,954) DisCos installed meters under the vendor-financed metering framework in

## 2023\. A total of 53 customers were metered under the DisCo Financed framework

## by aduna DisCo in 2023.

## Nigerian Electricity Regulatory Commission

* * *

## State of the Industry NERC Annual Report 2023

## 7.4 Commercial Report

## The commercial performance of the NESI is a measure of the flow of funds from

## customers to upstream electricity industry players. The financial performance is

## critical because funds are required for all the players along the value chain to sustain

## their operations. In evaluating the commercial performance of the NESI in 2023, the

## following parameters have been considered:

## A. Energy offtake performance

## B. Energy billed and billing efficiency

## C. Revenue and collection efficiency

## D. Aggregate Technical, Commercial and Collection (ATC&C) loss

## E. Remittances to the Market Operator (MO) and the Nigerian Bulk

## Electricity Trading Company (NBET)

## 7.4.1 Energy offtake performance

## Effective July 1, 2022, the NESI transitioned into the Partial Activation of Contract

## (PAC) regime which enabled the DisCos to determine their unconstrained power

## requirements in absolute Megawatt (MW) known as their Partially Contracted

## Capacity (PCC). This marked a change from the previous regime under which energy

## was allocated to DisCo based on the % contained in the vesting contracts signed

## with NBET – “MYTO load allocation”. When the gross available generation is

**below the total PCC of the DisCos, the SO shall allocate capacities to the DisCos in** **line with the guidelines for the implementation of the Economic Merit Order of** **Dispatch (EMOD).**

## The PAC regime set out a framework to enable GenCos to earn capacity payments

## i.e., payments for making an agreed generation capacity available irrespective of

**whether it is dispatched by the SO or not. This is in line with international best**

## Nigerian Electricity Regulatory Commission

* * *

practices in power procurement contracting and it increases the predictability of
revenue flows for GenCos, thus allowing for critical routine maintenance activities to
improve the availability of their plants.

The PAC regime reinforces the DisCos capacity payment scheme which took effect
on 1st January 2020 and acts as a deterrent against discretionary non-offtake of
energy. To further improve contract discipline along the upstream segment of the
NESI, the PAC regime provides for Liquidated Damages (LD) to be paid by GenCos
to the DisCos in situations where the DisCo does not receive the contracted capacity
15
due to challenges at the generation and/or transmission sub-segments. In July
2022, updated Service Level Agreements (SLA) were signed between DisCos and
TCN to institutionalise the compensation mechanism for DisCos when TCN’s
limitations prevent them from getting their contracted energy.

Each DisCo’s load offtake performance for 2023 is presented in Table 24.
Cumulatively, the DisCos’ offtake performance in 2023 was 95.50%. Ten (10)
DisCos took less energy than their PCC, and only Eko DisCo took more energy
(107.69% offtake performance; offtake of 433.90MWh/h against PCC of
402.93MWh/h) than its allocation. Yola (92.77%), Enugu (89.91%%) and Jos
(87.19%) DisCos recorded the lowest energy offtake performances.

| DisCos | Offtake(MWh/h) | PCC(MWh/h) | OfftakePerformance(%) |
| --- | --- | --- | --- |
| Abuja | 511.76 | 545.69 | 93.78% |
| Benin | 291.28 | 306.62 | 95.00% |
| Eko | 433.90 | 402.93 | 107.69% |
| Enugu | 287.69 | 319.99 | 89.91% |
| Ibadan | 405.97 | 417.24 | 97.30% |
| Ikeja | 533.49 | 559.58 | 95.34% |

15
Liquidated Damages (LD) are only due when issues are not Force Majeure i.e. the issues are within the
control of the TCN/GenCo.

* * *

State of the Industry

| DisCos | Offtake(MWh/h) | PCC(MWh/h) | OfftakePerformance(%) |
| --- | --- | --- | --- |
| Jos | 177.94 | 204.08 | 87.19% |
| Kaduna | 210.38 | 219.22 | 95.97% |
| Kano | 213.56 | 226.68 | 94.21% |
| Port Harcourt | 249.61 | 266.48 | 93.67% |
| Yola | 106.74 | 115.06 | 92.77% |
| All DisCos | 3,422.31 | 3,583.57 | 95.50% |

7.4.2 Energy Billed and Billing Efficiency

Billing Efficiency measures the proportion of energy billed to customers (including
metered and unmetered customers) relative to the total energy supplied to a given
area over a period. The formula for billing efficiency is represented by equation 7.6.

{\\tt{S e l i i n g\ E i f f c i e n c y}}\ eqref\ {{o v e:e}}}{==\\frac{{\\tt{T o r a l\ U r i n t\ B i l i e d\ k W W}}}{{\\tt{T o t t E n e r y y}\ {\\tt{R e c e i r e~b y}t h\ M e e v o r k k\ \[k W W\]}}}}\ \\\ \\times\ 1110\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\ \\\

× 100 (7.6)

The amount of energy received by DisCos at their trading points in 2023 was
29,979.46GWh, out of which 23,747.75GWh was billed to the end-users, resulting
in a billing efficiency of 79.21%. Billing Efficiency covers the technical and
commercial loss components in the Aggregate, Technical, Commercial and
Collection (ATC&C) loss. Some of the major factors that contribute to billing losses
are detailed below.

A. Poor customer enumeration: this is the inability of DisCos to identify all
electricity consumers.

C. Energy theft: this is the deliberate action by some electricity consumers to
consume electricity without making payments.

* * *

particularly relevant for areas of the network with substandard or aged
infrastructure.

The billing efficiency performance of all DisCos contained in Table 25 shows that
Eko and Ikeja had the highest billing efficiencies of 89.50% and 87.82%
respectively for 2023. Conversely, aduna recorded the lowest billing efficiency of
53.18%, indicating that aduna DisCo lost 46.82% of the energy received to
technical and commercial inefficiencies in 2023.

Table 25: Energy Received and Billed by DisCos in 2023

| DisCos | Total Energy Received(GWh) | Total Energy Billed(GWh) | Billing Efficiency(%) |
| --- | --- | --- | --- |
| Abuja | 4,483 | 3,239 | 72.25 |
| Benin | 2,552 | 2,179 | 85.40 |
| Eko | 3,801 | 3,402 | 89.50 |
| Enugu | 2,520 | 1,868 | 74.13 |
| Ibadan | 3,556 | 2,824 | 79.41 |
| Ikeja | 4,673 | 4,104 | 87.82 |
| Jos | 1,559 | 1,266 | 81.19 |
| Kaduna | 1,843 | 980 | 53.18 |
| Kano | 1,871 | 1,326 | 70.89 |
| Port Harcourt | 2,187 | 1,808 | 82.73 |
| Yola | 935 | 750 | 80.25 |
| All DisCos | 29,979 | 23,747 | 79.21 |

The Commission continues to engage DisCos on regulatory interventions to address
the factors driving DisCos’ billing inefficiency. The key driver of technical losses is
infrastructure inadequacy. DisCos must therefore implement projects contained in
their respective Performance Improvement Plans (PIP) as approved by the
Commission in 2021. To address the commercial component of billing inefficiency,
DisCos must undertake holistic asset mapping and customer enumeration process
which will facilitate the identification of illegal electricity consumers.

* * *

State of the Industry

7.4.3 Revenue and Collection Efficiency

Collection efficiency is the ratio of the amount that is collected from customers
compared to the amount billed to them by the DisCos. The significant under-recovery
of the bills issued to customers by DisCos is driven by a lack of willingness of
customers to pay bills when due, unsatisfactory DisCos’ services and inadequate
customer metering among other challenges. The formula for collection efficiency is
represented by equation 7.7.

{\\sf C o l l e c t i o n\ E f f i c i e n c y\ (\ r o)))\\=\ \ \\frac{{\\sf R e v e n u e\ C o l l e c t e d}}{{\\sf B i l l e d\ A m m o n t}}\ \ \\times\ 100}

× 100 (7.7)

The total revenue collected by the DisCos from customers in 2023 was ₦1,077.51
billion out of the total bill of ₦1,463.24 billion to customers, leaving an outstanding
balance of ₦385.73 billion. This translates to a collection efficiency of 73.64% which

balance of ₦385.73 billion. This translates to a collection efficiency of 73.64% which
implies that for every ₦100.00 worth of energy billed to customers by DisCos in
2023, approximately ₦26.36 was not recovered from customers. The low collection
efficiency combined with billing inefficiency has continued to adversely impact the
financial liquidity of the industry, ultimately limiting the NESI’s ability to grow and
attract investment.

balance of ₦385.73 billion. This translates to a collection efficiency of 73.64% which
implies that for every ₦100.00 worth of energy billed to customers by DisCos in
2023, approximately ₦26.36 was not recovered from customers. The low collection
efficiency combined with billing inefficiency has continued to adversely impact the
financial liquidity of the industry, ultimately limiting the NESI’s ability to grow and

In 2023, only Ikeja had a collection efficiency above 90% which can be partly
attributable to the fact that it leads the DisCos in terms of overall metering rate
(72.54%) as of the end of 2023. This was followed by Eko and Abuja DisCos with
collection efficiencies of 84.31% and 80.19% respectively, conversely, Yola DisCo
had the lowest collection efficiency of 43.56% (Table 26).

* * *

Table 26: Revenue Performance of DisCos in 2023

| DisCos | Total Billings(N'Billion) | Revenue Collected(N'Billion) | Collection Efficiency(%) |
| --- | --- | --- | --- |
| Abuja | 212,253 | 170,203 | 80.19 |
| Benin | 132,117 | 84,927 | 64.28 |
| Eko | 211,241 | 178,091 | 84.31 |
| Enugu | 111,667 | 83,282 | 74.58 |
| Ibadan | 164,917 | 113,474 | 68.81 |
| Ikeja | 236,899 | 222,431 | 93.89 |
| Jos | 89,308 | 40,346 | 45.18 |
| Kaduna | 58,160 | 32,730 | 56.28 |
| Kano | 83,848 | 54,086 | 64.50 |
| Port Harcourt | 110,084 | 74,963 | 68.10 |
| Yola | 52,745 | 22,976 | 43.56 |
| All DisCos | 1,463,239 | 1,077,509 | 73.64 |

7.4.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss

The Aggregate Technical, Commercial and Collection (ATC&C) loss is the measure
of the gross losses incurred by a DisCo in supplying electricity to end-use customers;
it measures the revenue shortfall a DisCo suffers arising from a combination of billing
(technical and commercial) as well as collection losses. The ATC&C loss comprises
the following components:

A. Technical Loss: heat loss due to load flow in electrical lines and transformation
loss in transformers.

B. Commercial Loss: due to discrepancy in meter reading, erroneous billing,
unmetered consumption, or energy theft.

The formula for ATC&C loss is represented by equation 7.8.

C. Collection Loss: unpaid bills.

* * *

The ATC&C loss is a critical performance parameter for tariff determination because
it is used to set efficiency targets for the DisCos; the ATC&C rate provided in the
tariff represents the efficient losses which the DisCos are allowed to recover from
customers. The Tariff Orders issued to DisCos make allowance for specific ATC&C
loss level targets for each DisCo. Just as the case of TLF explained in section 7.2.1,
the Commission has the responsibility of constantly reviewing the allowed ATC&C
for each DisCo to reflect the maturity of the market and investments being made by
the DisCo.

The average ATC&C loss for all the DisCos in 2023 was 41.67% comprising 20.79%
technical and commercial losses, and 26.36% collection loss. Collection losses
(including unpaid bills from sensitive customers, disputed bills, etc.) continue to form
a substantial part of the ATC&C loss. This reinforces the need for DisCos to intensify
efforts in revenue collection to improve their cash flow and meet market obligations.
Non-payment of bills by Federal/State Ministries, Departments and Agencies (MDA)
also continues to contribute to the ATC&C loss incurred by DisCos. To avoid a moral
hazard that may hinder regulatory action on underperforming DisCos, the
government across all tiers must pay their bills fully and promptly.

| DisCos | MYTO Targets | Average ATC&C Loss | Variance; target-actual(pp) |
| --- | --- | --- | --- |
| Abuja | 19.27% | 42.06% | -22.79 |
| Benin | 17.37% | 45.11% | -27.74 |
| Eko | 14.18% | 24.54% | -10.36 |
| Enugu | 11.31% | 44.72% | -33.41 |
| Ibadan | 15.47% | 45.36% | -29.89 |
| Ikeja | 11.37% | 17.54% | -6.17 |
| Jos | 27.27% | 63.32% | -36.05 |
| Kaduna | 10.65% | 70.07% | -59.42 |
| Kano | 15.85% | 54.27% | -38.42 |
| Port Harcourt | 21.45% | 43.66% | -22.21 |
| Yola | 64.12% | 65.04% | -0.92 |
| Overall MYTO Level | 20.75% |  |  |
| Aggregate technical, commercial & collection Loss | - | 41.67% |  |
| Technical&Commercial Losses | - | 20.79% |  |
| Collection Losses | - | 26.36% |  |

The overall ATC&C loss of 41.67% in 2023 was substantially higher than the
efficient ATC&C loss provided in the MYTO for 2023 (20.75%). The inability of the
DisCos to meet their allowed loss targets and the consequential inability to meet
revenue requirements compromises their long-term financial position.

The overall ATC&C loss of 41.67% in 2023 was substantially higher than the
efficient ATC&C loss provided in the MYTO for 2023 (20.75%). The inability of the
DisCos to meet their allowed loss targets and the consequential inability to meet
revenue requirements compromises their long-term financial position.

In absolute terms, Ikeja maintained its record of having the lowest ATC&C in the
market (17.54%) for the sixth consecutive year (Table 27). Conversely, aduna was
the worst performing DisCo with an ATC&C of 70.07% in 2023, this means that for
every ₦100.00 worth of energy delivered by the DisCo in 2023, it only collected
₦29.93 in revenue from customers.

Although none of the DisCos met their MYTO ATC&C targets, Yola and Ikeja were
the closest to attaining their MYTO target for the year with variances of -0.92pp
(target of 64.12% vs 65.04%) and -6.17pp (target of 11.37% vs 17.54%)
respectively. aduna, ano, and Jos DisCos had the widest variances relative to
their allowed MYTO targets for the year with -59.42pp (target of 10.65% vs
70.07%), -38.42pp (target of 15.85% vs 54.27%), and -36.05pp (target of 27.27%
vs 63.32%) respectively.

7.4.5 Market Remittance

* * *

DisCos. The Commission is responsible for determining each DisCo’s Minimum
Remittance Obligation (MRO) based on its allowed tariff – the MRO is contained in
the periodic Tariff Orders issued by the Commission. For ease of administration of
the subsidy, the MRO is only applied on the NBET invoice and represents the share
(in percentage) of an NBET invoice which the DisCo is expected to pay. DisCos are
required to pay 100% of the invoice issued to them by the MO for transmission and
other services.

The implementation of the MRO sought to end the discretionary remittances by
DisCos, ensure transparency and equity in the disbursement of market funds for the
benefit of all participants in the industry and ultimately address the liquidity crisis
16
facing the industry. The applicable MRO (%) for each DisCo to NBET in 2023 is
contained in Table 28. The cumulative MRO for DisCos was 52.92% (₦685.69
billion out of ₦1,295.75 billion NBET invoices), meaning that the government
incurred a subsidy obligation of ₦610.06 billion (47.08% of total NBET invoices).

| DisCos | Minimum Remittance Obligation(NBET) | Minimum Remittance Obligation(MO) | Remittance Obligation(NBET&MO) |
| --- | --- | --- | --- |
| Abuja | 65.17% | 100% | 69.17% |
| Benin | 48.27% | 100% | 54.47% |
| Eko | 57.45% | 100% | 62.52% |
| Enugu | 57.30% | 100% | 62.33% |
| Ibadan | 46.99% | 100% | 53.37% |
| Ikeja | 60.37% | 100% | 64.96% |
| Jos | 35.99% | 100% | 43.97% |
| Kaduna | 44.00% | 100% | 50.70% |
| Kano | 48.70% | 100% | 54.77% |
| Port Harcourt | 52.95% | 100% | 58.46% |
| Yola | 13.19% | 100% | 21.39% |
| All DisCos | 52.92% | 100% | 58.44% |

16
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 impacts their ability to discharge their functions optimally.

* * *

An MRO-adjusted invoice of ₦858.03 billion was issued by NBET and MO for
energy costs and administrative services to DisCos in 2023. The DisCos remitted a
total of ₦706.73 billion, resulting in a deficit of ₦151.30 billion during the year –
this underpayment is known as “market shortfall”. Based on the above, the gross
DisCo remittance rate to the upstream segment for 2023 was 82.37%.

A comparative analysis of DisCos’ market invoice (NBET + MO) and remittance in
2023 is presented in Figure 14. Eko DisCo recorded remittance performance above
17
100% (102.91%) while 3 DisCos; Yola, Benin, and Ibadan recorded remittance
performances above 90% (98.71%, 92.12% and 90.19% respectively). aduna
DisCo recorded the lowest remittance rate of 15.97% in 2023 due to its significant
ATC&C losses, as mentioned in earlier section 7.4.4.

A comparative analysis of DisCos’ market invoice (NBET + MO) and remittance in
2023 is presented in Figure 14. Eko DisCo recorded remittance performance above
) while 3 DisCos; Yola, Benin, and Ibadan recorded remittance
performances above 90% (98.71%, 92.12% and 90.19% respectively). aduna
DisCo recorded the lowest remittance rate of 15.97% in 2023 due to its significant
ATC&C losses, as mentioned in earlier section 7.4.4.

Figure 14: DisCos’ Remittance Performance to NBET and MO in 2023

17
Remittance performance above 100% is due to payment of outstanding invoices.

Nigerian Electricity Regulatory Commission

* * *

The DisCos’ disaggregated remittances to NBET and MO are summarised in Table
29\. Out of the ₦685.69 billion invoice issued by NBET in 2023, DisCos remitted
₦578.43 billion translating to a remittance performance of 84.34%. The top-
18
performing DisCos were Eko (105.76%), Yola (105.24%), Ikeja (96.20%), Benin
(95.15%) and Ibadan (93.11%). Conversely, aduna DisCo recorded the lowest
remittance performance to NBET in 2023 (17.59%).

The MO invoice in 2023 was ₦172.33 billion, and the DisCos remitted ₦128.40
billion, translating to a 74.51% remittance performance rate. The top-performing
DisCos were Yola (90.91%), Eko (90.85%) and Ikeja (90.38%) with remittances
above 90% to the MO in 2023. Conversely, aduna DisCo recorded the lowest
remittance (10.75%) to MO in 2023.

Table 29: DisCos Remittance Performance to NBET and MO in 2023

| DisCos | NBET(N'Billion) |  |  | MO(N'Billion) |  |  |
| --- | --- | --- | --- | --- | --- | --- |
| Invoice2023 | Remit.2023 | Performance2023 | Invoice2023 | Remit.2023 | Performance2023 |  |
| Abuja | 131.92 | 98.96 | 75.02% | 26.20 | 20.79 | 79.35% |
| Benin | 53.22 | 50.64 | 95.15% | 15.03 | 12.23 | 81.37% |
| Eko | 84.86 | 89.75 | 105.76% | 19.99 | 18.16 | 90.85% |
| Enugu | 64.70 | 52.80 | 81.61% | 15.08 | 9.86 | 65.38% |
| Ibadan | 70.72 | 65.85 | 93.11% | 20.56 | 16.49 | 80.20% |
| Ikeja | 124.77 | 120.03 | 96.20% | 27.04 | 24.44 | 90.38% |
| Jos | 25.09 | 21.82 | 86.97% | 9.94 | 6.47 | 65.09% |
| Kaduna | 34.91 | 6.14 | 17.59% | 10.79 | 1.16 | 10.75% |
| Kano | 39.79 | 25.20 | 63.33% | 10.95 | 5.60 | 51.14% |
| Port Harcourt | 50.61 | 41.74 | 82.47% | 12.68 | 9.50 | 74.92% |
| Yola | 5.15 | 5.42 | 105.24% | 4.07 | 3.70 | 90.91% |
| All DisCos | 685.69 | 578.34 | 84.34% | 172.33 | 128.40 | 74.51% |
| Special Customer:(‘Million） |  |  |  |  |  |  |
| Ajaokuta Steel(№) | 2,260.10 | 0.00 | 0.00% | 297.07 | 0.00 | 0.00% |

2. Remittances above 100% are due to payment of outstanding invoices.

3. Remittances above 100% are due to payment of outstanding invoices.


18
Yola DisCo was privatised in 2021 and had its ATC&C allowance reset with an expectation that it would
enjoy FGN subsidy to cover the gap between the allowed tariffs and the resultant cost-reflective tariffs.
Consequentially, it continues to enjoy very low remittance obligations to NBET which explains its relatively high
remittance rate.

* * *

## State of the Industry NERC Annual Report 2023

## It is clear from the remittance figures above that challenges persist with the upstream

## market liquidity. With the payment assurance waterfall in place, DisCos’ inability

## to remit also confirms that they were unable to earn their entire revenue requirement,

## which would have prevented them from having the funds to undertake necessary

## operational/capital investments. DisCos are the last mile in the energy trading value

## chain and should implement measures to improve revenue recovery to guarantee

## the flow of funds to upstream sector participants as well as sustain their own

## operations and long-term financial sustainability.

## On its part, the Commission is committed to ensuring full compliance with MROs for

## which failure to comply will result in appropriate sanctions. In this regard, to enforce

## market discipline and compliance with payment obligations, the Commission has

## directed NBET to exercise its contractual rights on the payment security cover

## provided by DisCos in accordance with the provisions of the Market Rules.

## Ajaokuta Steel Co. Ltd and the host community did not make any payment with

## respect to the ₦2.26 billion and ₦0.29 billion energy invoices and service charges

## received from NBET and MO respectively, in 2023. As detailed in the quarterly

## reports, the Commission has escalated the issue of continual non-payment of

## electricity bills by Ajaokuta to the relevant federal ministries to find a lasting solution.

## Failure to settle the obligations may put the Ajaokuta complex at risk of being

## disconnected from its service providers (NBET and MO) on the grounds of gross

**indebtedness.**

**19** **In June 2020, the remit of the fund manager responsible for the escrow was expanded to include the** **implementation of the payment waterfall framework which was designed by the Commission to increase** **upstream market remittance to NBET and TCN. This was to cover the cost of energy taken from GenCos,** **transmission charges (payable to the TSP) and the MO’s administrative charges.**

## Nigerian Electricity Regulatory Commission

* * *

The remittance performance of local and international bilateral customers to MO in
2023 is contained in Table 30. The international bilateral customers (i.e., Societe
Nigerienne d’electricite – NIGELEC, Societe Beninoise d’Energie Electrique – SBEE
and Compagnie Energie Electrique du Togo – CEET) received a total invoice of
$53.55 million from the MO in 2023 and made a total payment of $50.36 million
corresponding to a remittance performance of 94.04%. The local bilateral
customers received a total invoice of ₦10,320.84 million from MO in 2023 and
made a payment of ₦8,766.15 million corresponding to a remittance performance
of 84.94%.

The Commission has requested the MO to enforce the payment assurance
mechanisms provided in the Market Rules when bilateral customers default in settling
their invoices. Pursuant to this, all bilateral customers are expected to post the
relevant guarantees with the MO and these are to be drawn down by the MO when
the customers do not make necessary payments within the approved timelines.

Table 30: Bilateral Customers (International & Local) Invoices & Remittances in
2023

| International Customers | Invoice($'million) | Remittance($'million) | Performance(%) |
| --- | --- | --- | --- |
| Paras-SBEE | 11.67 | 11.67 | 100.00 |
| Transcorp/SBEE | 13.58 | 13.58 | 100.00 |
| Mainstream/NIGELEC | 12.44 | 12.45 | 100.08 |
| Odukpani/CEET | 15.86 | 12.66 | 79.82 |
| Total | 53.55 | 50.36 | 94.04 |
| Bilateral Customers | Invoice(N' million) | Remittance(N' million) | Performance(%) |
| Egbin Ikeja | 0.00 | 0.00 | 0.00 |
| Mainstream/Inner Galaxy |  |  |  |
| Mainstream/Kam Industries |  |  |  |
| Mainstream/Kam Integrated |  |  |  |
| Mainstream/PRISM | 4,422.55 | 4,455.78 | 100.75 |
| Mainstream/ZERBERCED |  |  |  |
| Mainstream/Kam Steel Shagamu |  |  |  |
| Mainstream/Adefolorunsho Venture |  |  |  |

* * *

State of the Industry

\| Odukpani/Sunflag

| Omotosho 11/Pulkit | 155.43 | 29.14 | 18.75 |
| --- | --- | --- | --- |
| Omotosho II/Weewood | 214.05 | 138.65 | 64.77 |
| North South/Star Pipe | 124.67 | 124.67 | 100.00 |
| Trans-Amadi/FMPI |  |  |  |
| Trans-Amadi/OAU | 131.98 | 110.60 | 83.80 |
| Omotosho 11/EKOEDC | 3,287.60 | 3,287.60 | 100.00 |
| Alaoji GenCo/APLE(N) | 1,515.02 | 230.00 | 15.18 |
| Taopex/Kam Steel Shagamu |  |  |  |
| Taopex/Kam Integrated | 440.90 | 389.71 | 88.39 |
| Jebba/Quantum Steel | 28.64 | 0.00 | 0.00 |
| Total | 10,320.84 | 8,766.15 | 84.94 |

1. Remittances above 100% are due to payment of outstanding invoices.

* * *

# Appendix

# APPENDIX

# Appendix

# APPENDIX

* * *

Appendix

A. Human Resource Management

st
Table A.1: Forum Secretaries of the Commission as of 31 December 2023

| S/N | Name | Forum Office |
| --- | --- | --- |
| 1 | Emeka Stanley Anako | Abakaliki Forum Office, Ebonyi State |
| 2 | Adesoji Oluwo | Abeokuta Forum Office, Ogun State |
| 3 | Grace Ekpenyong | Abuja Forum Office,FCT |
| 4 | Nnabuife J. Ogana | Asaba Forum Office,Delta State |
| 5 | Princess Agwu | Awka Forum Office,Anambra State |
| 6 | Akiti Wilson Barguma | Bauchi Forum Office,Bauchi State |
| 7 | Victor O.Odiase | Benin Forum Office,Edo State |
| 8 | Blessing Ikharo Abua | Calabar Forum Office,Cross River State |
| 9 | Ado Jamilu | Dutse Forum Office,Jigawa State |
| 10 | Chikaeze Osakumi | Eko Forum Office,Lagos State |
| 11 | Anuoluwapo Akintayo | Ekiti Forum Office |
| 12 | Henrietta Ene | Enugu Forum Office,Enugu State |
| 13 | Abubakar Yuguda | Gombe Forum Office |
| 14 | Bashir Adam | Damaturu Forum Office,Gombe State |
| 15 | Aminu Dauda | Gusau Forum Office,Zamfara State |
| 16 | Olaiya O.Abe | Ibadan Forum Office,Oyo State |
| 17 | Damilola Akintokunbo | Ikeja Forum Office,Lagos State |
| 18 | Chukwunonso Joachim | Ikeja Forum Office,Lagos State |
| 19 | Oluwakemi Mary Iyanda | Ilorin Forum Office,Kwara State |
| 20 | Ja'afar Ibrahim\* | Jigawa Forum Office,Jigawa State |
| 21 | Samuel Andzenge | Jos Forum Office,Plateau State |
| 22 | Mansur Abdullahi | Kaduna Forum Office,Kaduna State |
| 23 | Ja'afar Ibrahim | Kano Forum Office,Kano State |
| 24 | Abubakar Kurna | Katsina Forum Office,Katsina State |
| 25 | Umar Khalifa | Kebbi, Forum Office |
| 26 | Samuel Negedu | Lafia Forum Office,Nasarawa State |
| 27 | Nebo Joseph | Lokoja Forum Office,Kogi State |
| 28 | Pamela Ishaya Zakari | Makurdi Forum Office,Benue State |
| 29 | Afaoma Ubani | Owerri Forum Office,Imo State |
| 30 | Azeez Mutiu Akofe | Osogbo Forum Office,Osun State |
| 31 | Daniel Osumawei | Port-Harcourt Forum Office,River State |
| 32 | Kabiru.U.Musa | Sokoto Forum Office,Sokoto State |
| 33 | Chioma Okechukwu | Umuahia Forum Office,Abia State |
| 34 | Peter A.Dickson | Uyo Forum Office,Akwai Ibom State |
| 35 | Sydney W.Maksha | Yola Forum Office,Adamawa State |

* * *

B. Licence, Permit and Certification

Table B.1: Licences issued and renewed by the Commission in 2023

| S/N | Applicants | Capacity(MW) | Licence Type | Location | Fuel Type |
| --- | --- | --- | --- | --- | --- |
| A. | New Issue |  |  |  |  |
| 1 | Alausa Power Limited | 23.00 | Off-Grid Generation | Oregun,Lagos | Gas |
| 2 | ABV Utility Limited | 20.00 | IEDN | Lekki,Lagos | NA |
| 3 | Waltersmith Industrial Park Electricity Distribution Company Limited | NA | IEDN | Ohaji-Egbema,Imo | NA |
| 4 | Waltersmith Ugamma Power Company Limited | 200.00 | IEDN | Ohaji-Egbema,Imo | Gas |
| 5 | Zungeru Hydro Electricity | 700.00 | On-Grid Generation | Kaduna River,Niger State | Hydro |
| 6 | Electric Utility Nigeria Limited | NA | Trading License | NA | NA |
| 7 | Onction Services Limited | NA | Trading License | NA | NA |
| 8 | Daybreak Power Solutions Limited | 1.40 | Off-Grid Generation | Lagos State | Solar |
| 9 | Daybreak Power Solutions Limited | 1.50 | Off-Grid Generation | Abia State | Solar |
| 10 | Daybreak Power Solutions Limited | 1.58 | Off-Grid Generation | Borno State | Solar |
| 11 | Daybreak Power Solutions Limited | 1.60 | Off-Grid Generation | Kano State | Solar |
| 12 | Daybreak Power Solutions Limited | 2.73 | Off-Grid Generation | Lagos State | Solar |
| 13 | Ekiti IPP Limited | 5.00 | Embedded Generation | Ekiti State | Gas |
| 14 | Olokiti Power Distribution Limited | NA | IEDN | Ekiti State | NA |
| 15 | Ember Power Limited | NA | Trading License | Lagos State | NA |
| 16 | Ibadan Hybrid Power Limited | 30.00 | Embedded Generation | Oyo State | Gas |
| 17 | Alaro Power Free Zone Enterprise | 10.00 | Embedded Generation | Lagos State | Gas |
| 18 | Ibadan Hybrid Distribution Limited | NA | IEDN | Oyo State | NA |
| 19 | Isolo Power Supply Company Limited | NA | IEDN | Lagos State | NA |
| 20 | Zeta Technical Services Limited | NA | IEDN | Lagos State | NA |
| 21 | Rensource Commercial and Industrial Limited | 5.00 | Off-grid Generation | Abuja | Solar |
| 22 | CrossBoundary Nigeria Limited | 2.50 | Off-grid Generation | Oyo State | Solar |
| 23 | Adefolunho Energy Network Limited | NA | Trading License | NA | NA |
| 24 | Midbelt Energy Company Limited | NA | Trading License | NA | NA |
| B. | Renewal |  |  |  |  |
| 25 | Island Power Limited | 10.00 | Embedded generation | Lagos State | Gas |
| 26 | Energy Company of Nigeria Limited | NA | IEDN | Lagos State | NA |
| 27 | Isolo Power Generation Limited | 20.00 | Renewal | Lagos State | Gas |
| C. | License Amendment |  |  |  |  |
| 28 | Daybreak Power Solutions Limited | 3.50 to 5.70 | Amendment | Kano State | Gas |
| 29 | Daybreak Power Solutions Limited | 1.60 to 2.70 | Amendment | Oyo State | Gas |
| 30 | Daybreak Power Solutions Limited | 1.50 to 2.10 | Amendment | Abuja | Gas |

\*IEDN is an acronym for an Independent Electricity Distribution Network

* * *

Table B.2: Captive power generation Permits granted by the Commission in
2023

| S/N | Applicants | Location | Capacity(MW) |
| --- | --- | --- | --- |
| A. | Permit Issued |  |  |
| 1 | E.T Energy Enterprises Global Limited | Obiowo Ezeaba Nkamu,West,EnuguState | 8.00 |
| 2 | Rack Centre Nigeria Limited | 18 Jagal Close Oregun,Lagos State | 10.00 |
| 3 | Saipem Contracting Nigeria Limited | JV Camp,Rivers State | 5.14 |
| 4 | Saipem Contracting Nigeria Limited | Workers Village Camp,Rivers State | 10.05 |
| 5 | CHI Limited | 14 Chivita Avenue,Ajao Estate,LagosState | 23.59 |
| 6 | Tower Alloys Industries Limited | Ota Industrial Estate,Ota,OgunState | 10.00 |
| 7 | Junaid Synergy Limited | Kudirat Abiola Way,Ikeja,LagosState | 1.20 |
| 8 | Okomu Oil Palm Limited | Okomu,Ovia South,EdoState | 8.86 |
| 9 | British American Tobacco Company Limited | Ibadan,OyoState | 1.40 |
| 10 | Pardee Foods Nigeria Limited | Sango Otta,OgunState | 3.87 |
| 11 | Geeta Plastic Products Nigeria Limited | Mushin,LagosState | 1.80 |
| 12 | First Global Commerce Solutions Limited | LagosState | 77.00 |
| 13 | Wacot Rice Argungu Limited | KebbiState | 1.58 |
| 14 | Mangal Industries Limited | KogiState | 50.00 |
| 15 | Open Access data centre Limited | LagosState | 3.20 |

- CPG is an acronym for Captive Power Generation

* * *

Table B.3: Mini-grid registrations and Permits approved by the Commission in
2023

S/N
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28

| S/N | Name | Location | Capacity(Kw) |
| --- | --- | --- | --- |
|  | A. Approved Registration |  |  |
| 1 | Zylab Technology Nigeria Limited | Ankpa, Kogi | 100.00 |
| 2 | Solonic Energy Limited | Bakonu Community,Nasarawa | 100.00 |
| 3 | ACOB Lighting Limited | Oretedo,Odigbo,Ondo | 40.00 |
| 4 | ACOB Lighting Tech Limited | Sule, Ovia Southwest,Edo | 60.00 |
| 5 | Powergen Nigeria Assets Limited | Idanre,Ondo State | 860.00 |
| 6 | Darway Coast Nigeria Limited | Ifo, Ogun State | 698.00 |
| 7 | Bagaja Renewable Limited | Kumbosto,Kano State | 450.00 |
| 8 | Bagaja Renewable Limited | Kumbosto,Kano State | 550.00 |
| 9 | Solmenz Engineering Venture Nigeria Limited | Gbako,Niger State | 147.00 |
| 10 | A4&T Projects Limited | Fagbo,Ondo State | 169.00 |
| 11 | GVE Projects Limited | Bakin Ciyawa,Plateau State | 630.00 |
| 12 | GVE Projects Limited | Kwande,Plateau State | 340.00 |
| 13 | Everlink Telesat Network Limited | Akugbene,Delta State | 950.00 |
| 14 | Everlink Telesat Network Limited | Ogbidubudu,Delta State | 460.00 |
| 15 | Maskh Nigeria Limited# | Bauchi State | 190.00 |
| 16 | Acob Lightning Technology Limited+ | Kaduna State | 350.00 |
| 17 | NxtGrid Nigeria Limited | Edo State | 13.65 |
| 18 | NxtGrid Nigeria Limited | Edo State | 50.05 |
| 19 | NxtGrid Nigeria Limited | Ondo State | 77.35 |
| 20 | Sholep Energy Limited | Osun State | 100.00 |
| 21 | Orahachi Investment Limited | Kogi State | 50.00 |
| 22 | Ochuvus Nigeria Limited | Niger State | 100.00 |
| 23 | Ochuvus Nigeria Limited | Enugu State | 100.00 |
| 24 | Community Energy Social Enterprises Limited | Osun State | 74.00 |
| 25 | Community Energy Social Enterprises Limited | Osun State | 74.00 |
| 26 | Community Energy Social Enterprises Limited | Osun State | 49.00 |
| 27 | Community Energy Social Enterprises Limited | Osun State | 49.00 |
| 28 | Sandstream Nigeria LimitedB. Approved Permits | Kano State | 169.00 |

* * *

NERC Annual Report 2023

Appendix

| 29 | Darway Coast Nigeria Limited | Ijoko, Ogun | 993.80 |
| --- | --- | --- | --- |
| 30 | Nayo Tropical Technical Limited | Rafin Zurfi Community,Gwagwalada | 40.00 |
| 31 | Everlink Telecast Limited | Tamigbe,Burutu | 360.00 |
| 32 | Ventura Logistics Services Limited | Amaechi Okposo,Ohaozara, Ebonyi | 75.00 |
| 33 | Vaya Energy Solutions Limited | Belel Community,Maiha,Adamawa | 200.00 |
| 34 | A4&T Power Solutions Limited | Lagos State | 880.00 |
| 35 | Ashipa Electric Limited | Bayelsa State | 200.00 |
| 36 | Eauxwel Nigeria Limited | Abia State | 100.00 |
| 37 | Prado Power Limited | Benue State | 470.00 |
| 38 | Havenhill Energy Limited | Kwara State | 150.00 |
| 39 | A4&T Power Solutions Limited | Ondo State | 339.00 |
| 40 | A4&T Power Solutions Limited |  | 979.00 |
| 41 | Metikon Engineering Limited | Ondo State | 278.40 |
| 42 | Metikon Engineering Limited | Cross River State | 278.40 |
| 43 | Husk Power Energy System Nigeria Limited | Cross River State | 100.00 |
| 44 | Independent Energy Projects Financial Limited | Nasarawa State | 169.00 |
| 45 | Independent Energy Projects Financial Limited | Plateau State | 169.00 |
| 46 | International Energy Services Limited | Plateau State | 186.00 |

#Registration certificates were approved for nine (9) sites within Itas, Gadau, Ganjuwa & atogun local governments of Bauchi State.
+Registration certificates were approved for ten (10) sites within auru local government of aduna State.

* * *

Table B.4: Meter service providers certified by the Commission in 2023

| S/N | Applicant | Application Type |
| --- | --- | --- |
| 1 | Dexta Integrated Global Services Limited | Installer A2 |
| 2 | Zeelectric Engineering Nigeria Limited | Installer A1 |
| 3 | B.M.W | Installer C1 |
| 4 | Visotek Nigeria Limited | Installer C1 |
| 5 | Zeelectric Engineering Nigeria Limited | Installer A1 |
| 6 | Morgan Energy Limited | Installer A1 |
| 7 | Brylali Engineering Services Limited | Installer A1 |
| 8 | Powerdrones Engineering Limited | Installer A1 |
| 9 | Pontes Monnies Consult Limited | Installer A1 |
| 10 | Yisconfen International Company Limited | Installer A1 |
| 11 | Emdee Engineering Limited | Installer A1 |
| 12 | Empic Engineering Company Limited | Installer A1 |
| 13 | Adeq Global Resources Limited | Installer A1 |
| 14 | Primepro Power Limited | Installer A1 |
| 15 | Fulenell Nigeria Limited | Installer A1 |
| 16 | Beresford Integrated Services Ltd | Installer A1 |
| 17 | Goldengates options Ltd | Installer C1 |
| 18 | J. Marine Logistics Limited | Manufacturer |
| 19 | Paktim Metering Nigeria Limited | Manufacturer |
| 20 | Pactim Metering Nigeria Limited | Manufacturer |
| 21 | Direct Credit E-Solution Nigeria Limited | Manufacturer |
| 22 | Metering Solutions Manufacturing Services Limited | Manufacturer |
| 23 | Direct Credit E-Solution Nigeria Limited | Manufacturer |
| 24 | Maskh Nigeria Limited | Importer |
| 25 | Kayz Consortium Limited | MAP Permit |
| 26 | Cresflow Energy Limited | MAP Permit |
| 27 | Chris-Ejik International Agencies Limited | MAP Permit |
| 28 | Cresflow Energy Limited | MAP Permit |
| 29 | Aries Electric Limited | MAP Permit |
| 30 | Klartek Nigeria Limited | MAP Permit |
| 31 | Integrated Resources Limited | MAP Permit |
| 32 | G. Unit Engineering Limited | MAP Permit |
| 33 | KAYZ Consortium Limited | MAP Permit |

Class “A1” Certification authorises a holder to undertake installations of (i) Low Voltage single-phase and three-phase
Metering systems for installation exceeding 750 metering Systems/Contract, and (ii) Installations at grid voltages exceeding
1
5 Metering Systems. Class “C1” Certification authorises a holder to undertake installations of Low Voltage Distribution singlephase and three-phase Metering Systems exceeding 500 Metering Systems/Contract.

* * *

Appendix

C. Customer Complaints

Table C.1: Customer complaints received and resolved by DisCos in 2023

| DisCos | 2023/Q1 |  |  |  | 2023/Q2 |  |  |  | 2023/Q3 |  |  |  | 2023/Q4 |  |  |  | 2023 |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Customers' Complaints('000) |  |  | Customers' Complaints('000) |  |  | Customers' Complaints('000) |  |  | Customers' Complaints('000) |  |  | Customers' Complaints('000) |  |  | Customers' Complaints('000) |  |  |  |  |  |
| Received | Resolved | Unresolved | Received | Resolved | Unresolved | Received | Resolved | Unresolved | Received | Resolved | Unresolved | Received | Resolved | Unresolved | Received | Resolved | Unresolved |  |  |  |
| Abuja | 26.10 | 25.68 | 0.41 | 29.83 | 29.43 | 0.40 | 30.75 | 30.46 | 0.28 | 30.05 | 29.73 | 0.31 | 116.73 | 115.31 | 1.42 |  |  |  |  |  |
| Aba | - | - | - | - | - | - | 1.91 | 1.28 | 0.63 | 2.11 | 1.13 | 0.97 | 4.02 | 2.42 | 1.60 |  |  |  |  |  |
| Benin | 5.87 | 5.57 | 0.29 | 23.36 | 22.79 | 0.56 | 12.18 | 12.01 | 0.17 | 8.89 | 8.58 | 0.30 | 50.30 | 48.96 | 1.34 |  |  |  |  |  |
| Eko | 24.59 | 22.60 | 1.99 | 48.39 | 47.10 | 1.29 | 51.36 | 47.30 | 4.05 | 52.56 | 50.04 | 2.51 | 176.92 | 167.06 | 9.85 |  |  |  |  |  |
| Enugu | 41.58 | 39.06 | 2.52 | 42.54 | 39.37 | 3.17 | 47.55 | 43.90 | 3.65 | 42.36 | 39.80 | 2.55 | 207.21 | 195.26 | 11.94 |  |  |  |  |  |
| Ibadan | 37.98 | 34.53 | 3.45 | 55.11 | 52.74 | 2.36 | 59.90 | 56.67 | 3.22 | 54.21 | 51.31 | 2.90 | 110.22 | 93.90 | 16.31 |  |  |  |  |  |
| Ikeja | 28.34 | 18.74 | 9.60 | 28.77 | 26.39 | 2.37 | 28.24 | 25.63 | 2.61 | 24.85 | 23.13 | 1.72 | 81.17 | 77.39 | 3.78 |  |  |  |  |  |
| Jos | 14.69 | 13.80 | 0.89 | 27.73 | 26.90 | 0.82 | 20.46 | 19.49 | 0.96 | 18.28 | 17.19 | 1.09 | 30.22 | 28.47 | 1.74 |  |  |  |  |  |
| Kaduna | 7.17 | 6.77 | 0.40 | 7.52 | 7.04 | 0.48 | 8.01 | 7.52 | 0.48 | 7.50 | 7.12 | 0.37 | 52.38 | 52.18 | 0.19 |  |  |  |  |  |

\\frac{\\frac{\\Phi}{2}}{\\frac{\\Phi}{2}}

* * *

Appendix

Table C.2: Category of customer complaints received by DisCos, 2018-2023

| ComplaintCategories | 2023('000) |  |  |  |  | 2022('000) |  |  |  |  | 2021('000) |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual |  |
| Metering | 118.99 | 149.71 | 191.36 | 177.52 | 638.32 | 79.63 | 111.95 | 117.26 | 122.80 | 431.66 | 50.32 | 50.65 | 55.28 | 53.30 | 209.58 |
| Interruption | 23.01 | 23.61 | 26.94 | 24.55 | 98.13 | 37.18 | 23.43 | 21.75 | 24.23 | 106.60 | 43.61 | 48.21 | 45.06 | 38.45 | 175.34 |
| Voltage | 4.27 | 4.33 | 4.49 | 4.80 | 17.80 | 16.27 | 9.98 | 4.13 | 4.34 | 34.74 | 22.89 | 29.32 | 30.23 | 26.07 | 108.53 |
| Load Shedding | 1.51 | 2.43 | 1.66 | 0.86 | 6.48 | 14.71 | 5.33 | 1.30 | 1.46 | 22.82 | 17.79 | 18.22 | 14.36 | 14.14 | 64.52 |
| Billing | 56.72 | 53.36 | 43.02 | 42.86 | 195.97 | 41.64 | 32.93 | 49.92 | 61.02 | 185.52 | 38.92 | 42.76 | 48.54 | 39.39 | 169.62 |
| Disconnection | 4.11 | 4.69 | 4.91 | 4.26 | 17.98 | 26.99 | 7.25 | 7.34 | 4.84 | 46.43 | 34.36 | 31.31 | 31.01 | 28.12 | 124.82 |
| Connection Delay | 3.69 | 3.06 | 2.07 | 0.52 | 9.35 | 12.79 | 2.99 | 1.28 | 2.95 | 20.02 | 19.22 | 15.98 | 14.82 | 14.76 | 64.79 |
| Others | 37.17 | 65.80 | 59.45 | 55.30 | 218.24 | 14.14 | 38.01 | 38.22 | 39.43 | 129.81 | 9.80 | 4.97 | 7.78 | 8.37 | 30.92 |
| Total | 249.68 | 325.89 | 333.94 | 310.71 | 1,220.24 | 243.38 | 231.90 | 241.24 | 261.10 | 977.64 | 236.93 | 241.47 | 247.11 | 222.63 | 948.17 |
| ComplaintCategories | 2020('000) |  |  |  |  | 2019('000) |  |  |  |  | 2018('000) |  |  |  |  |
| /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual | /Q1 | /Q2 | /Q3 | /Q4 | Annual |  |
| Metering | 44.66 | 48.01 | 71.89 | 41.45 | 206.03 | 37.12 | 46.43 | 38.83 | 41.54 | 163.94 | 18.20 | 43.89 | 35.87 | 32.67 | 130.60 |

* * *

Table C.3: Appeals received and resolved by forum offices 2023

| S/N | Forum Offices | 2023/Q1 |  |  |  | 2023/Q2 |  |  |  | 2023/Q3 |  |  |  | 2023/Q4 |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Customers' Complaints |  |  |  | Customers' Complaints |  |  |  | Customers' Complaints |  |  |  | Customers' Complaints |  |  |  |  |  |  |  |  |  |
| Received | Resolved | Pending | Resolution Rate | Received | Resolved | Pending | Resolution Rate | Received | Resolved | Pending | Resolution Rate | Received | Resolved | Pending | Resolution Rate |  |  |  |  |  |  |
| 1 | Aabakaliki | 54 | 0 | 54 | 0% | 88 | 8 | 80 | 9% | 117 | 85 | 31 | 64% | 67 | 52 | 15 | 78% | 326 | 145 | 180 | 44% |
| 2 | Abeokuta | 67 | 21 | 1 | 31% | 27 | 1 | 26 | 4% | 133 | 64 | 19 | 43% | 122 | 17 | 42 | 14% | 349 | 103 | 88 | 30% |
| 3 | Abujia | 47 | 27 | 19 | 57% | 43 | 29 | 14 | 67% | 51 | 31 | 20 | 61% | 52 | 44 | 8 | 85% | 193 | 131 | 61 | 68% |
| 4 | Ada-Ekiti | - | - | - | - | - | - | - | - | - | - | - | - | 3 | 1 | 2 | 33% | 3 | 1 | 2 | 33% |
| 5 | Asaba | 90 | 90 | 31 | 66% | 86 | 71 | 15 | 83% | 65 | 52 | 13 | 93% | 68 | 22 | 44 | 32% | 309 | 204 | 103 | 66% |
| 6 | Awka | 80 | 40 | 40 | 50% | 116 | 87 | 29 | 75% | 116 | 93 | 23 | 62% | 97 | 83 | 14 | 86% | 409 | 303 | 106 | 74% |
| 7 | Bauchi | 5 | 0 | 0 | 100% | 7 | 7 | 0 | 100% | 5 | 3 | 2 | 80% | 4 | 4 | 0 | 100% | 21 | 19 | 2 | 90% |
| 8 | Benin | 11 | 0 | 10 | 0% | 75 | 64 | 11 | 0% | 90 | 67 | 23 | 56% | 66 | 45 | 21 | 0% | 242 | 176 | 65 | 73% |
| 9 | Calbar | 64 | 36 | 18 | 67% | 41 | 28 | 12 | 68% | 55 | 27 | 17 | 23% | 37 | 30 | 7 | 81% | 167 | 121 | 44 | 72% |
| 10 | Dektei | 15 | 0 | 15 | 0% | 15 | 1 | 14 | 17% | 17 | 17 | 0 | 0% | 6 | 5 | 1 | 83% | 153 | 30 | 43% |  |
| 11 | Eko | 33 | 4 | 29 | 12% | 73 | 19 | 54 | 26% | 136 | 90 | 46 | 76% | 156 | 101 | 55 | 65% | 398 | 214 | 184 | 54% |

* * *

Table C.4: List and Addresses of NERC Forum Offices as of December 2023

| S/N | Forum Office | Location | Telephone | Email |
| --- | --- | --- | --- | --- |
| 1 | Abakaliki, Ebonyi State | 3, Ezekua Crescent, Off Nsugbe Street, Abakaliki Ebonyi State | 9037808590 | [abakalikiforum@nerc.gov.ng](mailto:abakalikiforum@nerc.gov.ng) |
| 2 | Abeokuta, Ogun State | 33, First Avenue, Ibara Housing Estate, Ibrar GRA, Abeokuta | 9139811008 | [abekutaforum@nerc.gov.ng](mailto:abekutaforum@nerc.gov.ng) |
| 3 | Abuja, FCT | 14, Road 131, Gwarinpa, Federal Capital Territory, Abuja | 8146862225 | [abujaforum@nerc.gov.ng](mailto:abujaforum@nerc.gov.ng) |
| 4 | Ado-Ekiti, Ekiti State | Km 5, Iwokoro Road, Ado Ekiti, Ekiti State | 9169978242 | [ado-ekitiforum@nerc.gov.ng](mailto:ado-ekitiforum@nerc.gov.ng) |
| 5 | Asaba, Delta State | Denis Osadebe Way, Beside Mobil Filling Station, Asaba, Delta State | 9062277247 | [osabaforum@nerc.gov.ng](mailto:osabaforum@nerc.gov.ng) |
| 6 | Awka, Anambra State | Plot 80, Aroma Junction Layout, Opp, CBN, Awka, Anambra State | 9037808594 | [awkaforum@nerc.gov.ng](mailto:awkaforum@nerc.gov.ng) |
| 7 | Bauchi, Bauchi State | 37, Old Jos Road, GRA, Bauchi, Bauchi State | 9062924607 | [bauchiforum@nerc.gov.ng](mailto:bauchiforum@nerc.gov.ng) |
| 8 | Benin, Eda State | 34, Akpakpava Street, Benin City, Eda State | 9037808592 | [beninforum@nerc.gov.ng](mailto:beninforum@nerc.gov.ng) |
| 9 | B/Kebbi, Kebbi State | 8, Ahmadu Bello Way, Opp, Kebbi State Govt House, Kebbi State | 9062863161 | [birninkebbforum@nerc.gov.ng](mailto:birninkebbforum@nerc.gov.ng) |
| 10 | Calabar, C/Rivers State | Plot 109, MCR Road by Ibok Street, Calabar, Cross River State | 9062863159 | [calabarforum@nerc.gov.ng](mailto:calabarforum@nerc.gov.ng) |
| 11 | Dutse, Jigawa State | Dutse G.R.A, Dutse, Jigawa State | 7031704827 | [jigawaforum@nerc.gov.ng](mailto:jigawaforum@nerc.gov.ng) |
| 12 | Eko, Lagos State | 61, Odunlami Street, Off Marina, Lagos Island, Lagos State | 8106807261 | [ekoforum@nerc.gov.ng](mailto:ekoforum@nerc.gov.ng) |
| 13 | Enugu, Enugu State | John Anichukw Close, Plot 7 Mkpkitki Pocket Layout, Enugu, Enugu State | 8146862230 | [enuguforum@nerc.gov.ng](mailto:enuguforum@nerc.gov.ng) |
| 14 | Gombe, Gombe State | Government Layout GDP/2, Along Ministry of Education Road, Gombe State | 8140440079 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) |
| 15 | Gusau, Zamfara State | 2 Canteen Daji, J. B. Yakubu Road, Gusau, Zamfara State | 9062863163 | [gusauforum@nerc.gov.ng](mailto:gusauforum@nerc.gov.ng) |
| 16 | Ibadan, Oyo State | Jibowu Str, Opp, Magara Police Station, Iyaganku, G.R.A, Ibadan, Oyo State | 8146862252 | [ibadantorum@nerc.gov.ng](mailto:ibadantorum@nerc.gov.ng) |
| 17 | Ikegia, Lagos State | 199, Obafemi Awolowo Way, Alausa, Ikegia, Lagos State | 8106807298 | [ikegiaforum@nerc.gov.ng](mailto:ikegiaforum@nerc.gov.ng) |
| 18 | Ilorin, Kwara State | 30, Stadium Road, Off Taiwo Road, Ilorin, Kwara State | 9062924603 | [ilorinforum@nerc.gov.ng](mailto:ilorinforum@nerc.gov.ng) |
| 19 | Jos, Plateau State | 5a, Ray-field Road, Jos, Plateau State | 9037808597 | [josforum@nerc.gov.ng](mailto:josforum@nerc.gov.ng) |
| 20 | Kaduna, Kaduna State | 22, Ahmedu Bello Way, Oppsite NNDC Building, Kaduna, Kaduna State | 8106807299 | [kadunaforum@nerc.gov.ng](mailto:kadunaforum@nerc.gov.ng) |
| 21 | Kano, Kano State | 2, Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 8146862222 | [kanaforum@nerc.gov.ng](mailto:kanaforum@nerc.gov.ng) |
| 22 | Katsina, Katsina State | 7, Abuja Crescent, Off Hassan Usman Katsina Road, Katsina, Katsina State | 7031704821 | [katsinasforum@nerc.gov.ng](mailto:katsinasforum@nerc.gov.ng) |
| 23 | Lafia, Nasarawa State | Manyi Street, Off Jos Road, Bukan Sidi, Lafia, Nasarawa State | 9062924599 | [lafiaforum@nerc.gov.ng](mailto:lafiaforum@nerc.gov.ng) |
| 24 | Lokaja, Kogi State | Hassan Kastina Rd, Opp, State Civil Service Commission, Zone B Police HQ, Lokija, Kogi State. | 9062924601 | [lokajaforum@nerc.gov.ng](mailto:lokajaforum@nerc.gov.ng) |

* * *

Appendix

D. Rate Case Hearing

Table D.1: DisCos representatives at the Rate Case Hearings

| DisCos | Lead Representative | Designation | Date |
| --- | --- | --- | --- |
| Abuja | Engr. Adeoye Fadeyibi | MD/CEO | 24 July, 2023 |
| Benin | Mr. Deolu Ijose | MD/CEO | 24 July, 2023 |
| Eko | Dr. Tinuade Sanda | MD/CEO | 24 July, 2023 |
| Kano | Mr. Ahmed Dangana | MD/CEO | 25 July, 2023 |
| Ikeja | Mrs. Foluke Soetan | MD/CEO | 25 July, 2023 |
| Enugu | Mr. Praveen Chorgade | MD/CEO | 25 July, 2023 |
| Jos | Engr. Abdu Bello Mohammed | MD/CEO | 26 July, 2023 |
| Port Harcourt | Dr. Benson Uhweru | MD/CEO | 26 July, 2023 |
| Ibadan | Engr. Kingsley Achife | MD/CEO | 26 July, 2023 |
| Kaduna | Mr. Yusuf Usman Yahaya | MD/CEO | 27 July, 2023 |
| Yola | Mr. Abubakar Jibrin | Ag.MD/CEO | 27 July, 2023 |
| Aba Power | Mr. Patrick Umeh | MD/CEO | 08 August, 2023 |

* * *

Table D.2: List of Intervenors at the Rate Case Hearings

| S/N | Name | DisCo |
| --- | --- | --- |
| 1 | Pastor Nwokocha Anozie Innocent | APLE |
| 2 | Eleweke Ikenna Austin | APLE |
| 3 | Michael Ahunanya | APLE |
| 4 | Godwin Nwaigwe | APLE |
| 5 | Jonathan Giama(CHDR Delta State) | Benin |
| 6 | Andrew Pinneh | Benin |
| 7 | Olabayo Balogun | Eko |
| 8 | Adeola Samuel-ilori | Eko |
| 9 | Ugochukwu Ugwoeje | Enugu |
| 10 | Rasaki Fabayo | Ibadan |
| 11 | Azeez Bisilimi | Ibadan |
| 12 | Adesina Edwards(Asabari Consultative Council) | Ibadan |
| 13 | Adeshola Sylvester | Ibadan |
| 14 | Ola-Olamide Emmanuel | Ibadan |
| 15 | Oloyede fatai Ayinde | Ibadan |
| 16 | Alh. Salihu Imam | Ibadan |
| 17 | Akinbodunse Shadrack | Ibadan |
| 18 | Hon.Sunday Moses Oladapo | Ikeja |
| 19 | Idris Akano | Ikeja |
| 20 | Adeola Samuel-ilori | Ikeja |
| 21 | Jamila M.Umar | Jos |
| 22 | Almustapha Abdulkarim | Kaduna |
| 23 | Jamila M.Umar | Kaduna |
| 24 | Bassey Inyang | Port Harcourt |
| 25 | Chidike Okoro | Port Harcourt |
| 26 | Engr.Tony Nwobo | Port Harcourt |

* * *

E. Electricity Generation

Table E.1: Available Capacity, Energy Generated and Energy Delivered 2020-2023

|  | Installed Available Capacity(MW) |  |  |  | Energy Generated(MWh) |  |  |  |  | Energy Delivered to the Grid(MWh) |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Period | 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 |  |  |
| January | 4,394 | 4,783 | 5,103 | 5,663 | 4,083 | 4,265 | 4,495 | 3,817 | 4,021 | 2,836 | 4,424 | 3,732 |  |  |
| February | 4,726 | 4,863 | 5,513 | 5,755 | 4,502 | 4,317 | 4,561 | 4,114 | 4,441 | 2,675 | 4,482 | 4,008 |  |  |
| March | 4,828 | 4,491 | 5,601 | 5,275 | 4,432 | 3,728 | 4,410 | 3,912 | 4,346 | 2,655 | 4,328 | 3,858 |  |  |
| April | 4,334 | 5,099 | 5,023 | 6,315 | 4,177 | 3,813 | 4,308 | 4,099 | 4,095 | 2,659 | 4,229 | 4,031 |  |  |
| May | 4,421 | 4,608 | 5,002 | 6,421 | 4,071 | 3,630 | 4,149 | 4,168 | 4,029 | 2,288 | 4,075 | 4,100 |  |  |
| June | 4,426 | 3,845 | 4,505 | 6,341 | 3,949 | 3,224 | 3,774 | 3,726 | 3,863 | 2,674 | 3,705 | 3,660 |  |  |
| July | 4,139 | 4,092 | 4,858 | 6,301 | 3,968 | 3,634 | 3,940 | 3,821 | 3,911 | 2,882 | 3,866 | 3,757 |  |  |
| August | 4,060 | 4,575 | 5,593 | 6,673 | 3,946 | 3,939 | 4,003 | 4,045 | 3,891 | 2,825 | 3,934 | 3,981 |  |  |
| September | 4,435 | 4,456 | 5,453 | 6,048 | 3,858 | 4,047 | 3,867 | 3,863 | 3,808 | 2,903 | 3,801 | 3,806 |  |  |
| October | 4,964 | 4,233 | 5,764 | 6,710 | 4,452 | 3,976 | 4,138 | 4,155 | 4,399 | 3,043 | 4,078 | 4,088 |  |  |
| November | 5,076 | 4,537 | 5,432 | 5,893 | 4,399 | 4,304 | 4,336 | 4,424 | 4,338 | 3,252 | 4,275 | 4,358 |  |  |
| December | 4,450 | 4,740 | 5,200 | 5,888 | 4,450 | 4,265 | 4,495 | 3,817 | 4,021 | 2,836 | 4,424 | 3,732 |  |  |
| Average | 4,521 | 4,527 | 5,254 | 6,107 | 4,191 | 4,317 | 4,561 | 4,114 | 4,096 | 2,675 | 4,482 | 4,008 |  |  |

Table E.2: Plants’ Average Load Factor, 2020-2023

|  | Load Factor(%) |  |  |  |
| --- | --- | --- | --- | --- |
| GenCos | 2023 | 2022 | 2021 | 2020 |
| Afam IV-V | 93.69 | 78.90 | 75.69 | 62.84 |
| Afam VI IPP | 100.00 | 97.72 | 92.91 | 68.79 |
| Alaoji NIPP | 88.35 | 80.10 | 51.29 | 40.06 |
| Azura Edo IPP | 90.31 | 93.23 | 88.90 | 79.74 |
| Dadin Kowa | 95.93 | 97.93 | - | - |
| Delta | 96.39 | 87.69 | 82.27 | 67.77 |
| Egbin | 93.28 | 91.48 | 81.59 | 65.36 |
| Gbarain NIPP | NA | - | - | 42.91 |
| Geregu | 94.17 | 83.57 | 76.14 | 64.04 |
| Geregu NIPP | 91.88 | 88.03 | 64.91 | 64.84 |
| Ibom Power IPP | 54.57 | 52.37 | 80.69 | 55.02 |
| Ihovbor NIPP | 81.16 | 84.02 | 50.60 | 36.79 |
| Jebba | 93.18 | 98.44 | 85.08 | 78.73 |
| Kainji | 95.52 | 98.09 | 95.05 | 83.6 |
| Odukpani NIPP | 92.63 | 72.70 | 72.88 | 61.62 |
| Okpai IPP | 84.72 | 81.37 | 78.52 | 59.02 |
| Olorunsogo | 99.83 | 84.90 | 75.45 | 61.87 |
| Olorunsogo NIPP | 98.26 | 82.60 | 65.11 | 60.54 |
| Omoku IPP | 100.00 | 100.00 | 87.26 | 55.6 |
| Omotosho | 97.40 | 89.66 | 84.07 | 65.69 |
| Omotosho NIPP | 85.51 | 87.19 | 52.76 | 60.5 |
| Paras Energy IPP | 87.39 | 82.84 | 79.20 | 73.87 |
| Rivers IPP | 89.23 | 92.03 | 71.72 | 72.92 |
| Sapele | 90.29 | 68.67 | 51.87 | 55.98 |
| Sapele NIPP | 79.90 | 66.91 | 77.37 | 33.71 |
| Shiroro | 85.53 | 89.63 | 74.54 | 67.59 |
| Trans-Amadi IPP | 100.00 | 99.05 | 79.12 | 65.98 |
| Total | 92.22 | 85.94 | 79.92 | 61.74 |

* * *

Table E.3: Annual Electricity Output and Share by Fuel Type, 2020-2023

|  |  | Total Electricity Output(GWh) |  |  |  | Fuel Share of Electricity Output(%) |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Period | Fuel Type | 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 |
| Q1 | Thermal | 6,979 | 6,497 | 7,683 | 6,327 | 74 | 73 | 77 | 73 |
| Hydro | 2,370 | 2,350 | 2,227 | 2,286 | 25 | 26 | 22 | 26 |  |
| Q2 | Aggregate | 9,350 | 8,848 | 9,910 | 8,613 | 100 | 100 | 100 | 100 |
| Thermal | 7,068 | 6,324 | 7,373 | 7,121 | 79 | 81 | 81 | 81 |  |
| Hydro | 1,798 | 1,442 | 1,628 | 1,613 | 20 | 18 | 18 | 18 |  |
| Q3 | Aggregate | 8,867 | 7,766 | 9,001 | 8,734 | 100 | 100 | 100 | 100 |
| Thermal | 6,456 | 6,027 | 6,729 | 6,318 | 74 | 70 | 77 | 76 |  |
| Hydro | 2,208 | 2,512 | 1,962 | 1,946 | 25 | 29 | 22 | 23 |  |
| Q4 | Aggregate | 8,664 | 8,850 | 8,692 | 8,265 | 100 | 100 | 100 | 100 |
| Thermal | 7,087 | 6,438 | 6,832 | 7,248 | 72 | 70 | 72 | 75 |  |
| Hydro | 2,702 | 2,926 | 2,648 | 2,379 | 27 | 31 | 27 | 24 |  |
| Annual | Aggregate | 9,789 | 9,365 | 9,481 | 9,628 | 100 | 100 | 100 | 100 |
| Thermal | 27,623 | 25,613 | 28,619 | 27,016 | 75 | 73 | 77 | 76 |  |
| Hydro | 9,086 | 9,328 | 8,466 | 8,213 | 24 | 26 | 22 | 23 |  |
| Aggregate | 36,710 | 34,942 | 37,086 | 35,230 | 100 | 100 | 100 | 100 |  |

Table E.4: Plant Share of Total Electricity Output, 2020-2023

|  | Electricity Output by Plant(GWh) |  |  |  | Electricity Output by Plant(%) |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| GenCos | 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 |
| AES Barge IPP | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
| Afam IV-V | 344 | 432 | 585 | 450 | 0.94 | 1.24 | 1.59 | 1.29 |
| Afam VI IPP | 2,737 | 853 | 2,404 | 2,248 | 7.46 | 2.44 | 6.53 | 6.36 |
| Alaoji NIPP | 58 | 579 | 505 | 544 | 0.16 | 1.66 | 1.37 | 1.53 |
| ASCO IPP | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
| Azura Edo IPP | 3,244 | 3,454 | 3,252 | 2,925 | 8.84 | 9.89 | 8.84 | 8.27 |
| Dadin Kowa | 205 | 234 | 0 | - | 0.56 | 0.67 |  |  |
| Delta | 3,130 | 3,341 | 112 | 2,688 | 8.53 | 9.56 | 7.53 | 7.56 |
| Egbin | 5,173 | 3,800 | 2,769 | 4,780 | 14.09 | 10.87 | 15.29 | 13.54 |
| Gbarain NIPP | 0 | 0 | 0 | 84 | 0 | 0 | 0 | 0.24 |
| Geregu | 1,741 | 1,619 | 5,626 | 2,039 | 4.74 | 4.63 | 6.70 | 5.76 |
| Geregu NIPP | 315 | 734 | 2,463 | 816 | 0.86 | 2.1 | 1.85 | 2.31 |
| Ibom Power IPP | 349 | 309 | 681 | 322 | 0.95 | 0.88 | 0.30 | 0.93 |
| Ihovbor NIPP | 217 | 529 | 111 | 195 | 0.59 | 1.51 | 0.40 | 0.53 |
| Jebba | 2,961 | 2,859 | 149 | 2,725 | 8.07 | 8.18 | 8.37 | 7.68 |
| Kainji | 3,410 | 3,202 | 3,078 | 2,946 | 9.29 | 9.16 | 7.70 | 8.31 |
| Odukpani NIPP | 2,117 | 1,925 | 2,834 | 2,461 | 5.77 | 5.51 | 6.90 | 6.99 |
| Okpai IPP | 2,331 | 2,066 | 2,537 | 1,588 | 6.35 | 5.91 | 6.40 | 4.46 |
| Olorunsogo | 832 | 953 | 2,356 | 1,139 | 2.27 | 2.73 | 2.94 | 3.2 |
| Olorunsogo NIPP | 253 | 349 | 1,080 | 132 | 0.69 | 1 | 0.17 | 0.37 |
| Omoku IPP | 487 | 424 | 64 | 556 | 1.33 | 1.21 | 1.03 | 1.78 |
| Omotosho | 1,006 | 918 | 377 | 1,062 | 2.74 | 2.63 | 2.77 | 2.99 |
| Omotosho NIPP | 751 | 722 | 1,018 | 660 | 2.05 | 2.07 | 0.76 | 1.85 |

* * *

Table E.5: Average Monthly Transmission Loss Factor, 2021-2023

|  | Energy Injected into Grid(GWh) |  |  | Energy Delivered to DisCos&Exported(GWh) |  |  | Transmission Losses Factor(%) |  |  | MYTO Assumption(%) |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Month | 2023 | 2022 | 2021 | 2023 | 2022 | 2021 | 2023 | 2022 | 2021 | 2023 |  |
| January | 3,263 | 3,136 | 3,295 | 2,755 | 2,812 | 3,043 | 7.32% | 8.15% | 7.64% |  | 7.25% |
| February | 2,974 | 2,860 | 3,007 | 2,744 | 2,554 | 2,781 | 8.19% | 8.54% | 7.51% |  |  |
| March | 2,983 | 2,754 | 3,220 | 2,982 | 2,487 | 2,982 | 8.19% | 7.38% | 7.37% |  |  |
| April | 3,247 | 2,717 | 3,004 | 2,720 | 2,446 | 2,816 | 7.73% | 8.44% | 7.49% |  |  |
| May | 2,948 | 2,662 | 3,033 | 2,715 | 2,081 | 2,809 | 9.56% | 8.43% | 7.41% |  |  |
| June | 3,002 | 2,291 | 2,664 | 2,562 | 2,465 | 2,464 | 7.72% | 8.20% | 7.49% |  |  |
| July | 2,776 | 2,677 | 2,834 | 2,664 | 2,593 | 2,654 | 8.17% | 8.08% | 6.34% |  |  |
| August | 2,897 | 2,870 | 2,890 | 2,670 | 2,637 | 2,705 | 8.39% | 7.78% | 6.43% |  |  |
| September | 2,912 | 2,847 | 2,714 | 2,544 | 2,701 | 2,522 | 7.26% | 7.50% | 7.07% |  |  |
| October | 2,742 | 2,917 | 3,030 | 2,977 | 2,851 | 2,785 | 8.89% | 7.42% | 8.07% |  |  |
| November | 3,266 | 3,059 | 3,091 | 2,944 | 3,012 | 2,828 | 8.83% | 6.81% | 8.50% |  |  |
| December | 3,229 | 3,263 | 3,243 | 2,998 | 2,755 | 2,983 | 7.74% | 7.71% | 8.03% |  |  |
| Average | 3,020 | 2,838 | 3,005 | 2,773 | 2,616 | 2,781 | 8.17% | 7.87% | 7.45% |  |  |
| Total | 36,240 | 34,054 | 36,065 | 33,273 | 31,393 | 33,373 | 8.17% | 7.87% | 7.45% |  |  |

Table E.6: Number of System Collapses, 2011-2023

| Year |  | Type | Jan. | Feb. | Mar. | Apr. | May | Jun. | Jul. | Aug. | Sep. | Oct. | Nov. | Dec. | Total |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2011 | Total Collapse | 0 | 0 | 0 | 0 | 4 | 3 | 1 | 1 | 1 | 1 | 2 | 1 | 0 | 13 |
| Partial Collapse | 0 | 1 | 1 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | 2 | 0 | 6 |  |  |
| 2012 | Total Collapse | 0 | 0 | 2 | 1 | 5 | 2 | 1 | 0 | 0 | 2 | 2 | 1 | 16 |  |
| Partial Collapse | 0 | 0 | 2 | 3 | 0 | 0 | 0 | 0 | 1 | 0 | 1 | 1 | 8 |  |  |
| 2013 | Total Collapse | 0 | 1 | 2 | 2 | 3 | 4 | 1 | 1 | 1 | 1 | 4 | 2 | 22 |  |
| Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 2 |  |  |
| 2014 | Total Collapse | 2 | 0 | 0 | 2 | 0 | 3 | 1 | 0 | 0 | 1 | 0 | 0 | 9 |  |
| Partial Collapse | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 2 | 1 | 4 |  |  |
| 2015 | Total Collapse | 1 | 0 | 1 | 0 | 2 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 6 |  |
| Partial Collapse | 0 | 0 | 1 | 0 | 2 | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 4 |  |  |
| 2016 | Total Collapse | 0 | 0 | 2 | 3 | 6 | 5 | 0 | 0 | 1 | 1 | 2 | 2 | 22 |  |
| Partial Collapse | 0 | 0 | 1 | 0 | 1 | 3 | 1 | 0 | 0 | 0 | 0 | 0 | 6 |  |  |
| 2017 | Total Collapse | 5 | 3 | 0 | 3 | 1 | 1 | 0 | 0 | 1 | 1 | 0 | 0 | 15 |  |
| Partial Collapse | 1 | 0 | 1 | 0 | 0 | 0 | 1 | 0 | 3 | 3 | 0 | 0 | 9 |  |  |
| 2018 | Total Collapse | 5 | 1 | 0 | 0 | 0 | 1 | 1 | 0 | 2 | 0 | 0 | 2 | 12 |  |
| Partial Collapse | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 |  |  |
| 2019 | Total Collapse | 4 | 1 | 0 | 1 | 1 | 1 | 0 | 1 | 0 | 0 | 0 | 1 | 10 |  |
| Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 1 |  |  |
| 2020 | Total Collapse | 1 | 0 | 0 | 1 | 0 | 1 | 0 | 0 | 0 | 0 | 1 | 0 | 4 |  |
| Partial Collapse | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |  |  |

* * *

Table E.7: Average Daily System Frequency, 2020-2023

| Period | Stress |  |  |  |  | Nominal Standard | Average system frequency(upper bound) |  |  |  | Average system frequency(lower bound) |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Upper Limit | Lower Limit | Higher Stress limit | Lower Stress limit |  | 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 |  |  |
| January | 50.25 | 49.75 | 51.25 | 48.75 | 50 | 50.60 | 50.68 | 50.49 | 50.82 | 49.10 | 49.13 | 49.17 | 49.67 |  |
| February | 50.96 | 50.60 | 50.59 | 50.7 | 49.11 | 49.05 | 49.38 | 49.75 |  |  |  |  |  |  |
| March | 51.01 | 50.78 | 50.62 | 50.65 | 49.02 | 49.07 | 49.29 | 49.48 |  |  |  |  |  |  |
| April | 50.93 | 51.12 | 50.72 | 50.77 | 48.98 | 49.08 | 49.12 | 49.63 |  |  |  |  |  |  |
| May | 51.10 | 50.47 | 50.64 | 50.67 | 49.08 | 49.13 | 49.13 | 49.7 |  |  |  |  |  |  |
| June | 51.06 | 50.73 | 50.70 | 50.86 | 49.06 | 49.09 | 49.07 | 49.73 |  |  |  |  |  |  |
| July | 50.73 | 50.63 | 50.69 | 50.78 | 48.96 | 48.71 | 49.95 | 49.83 |  |  |  |  |  |  |
| August | 50.56 | 51.14 | 50.81 | 50.74 | 48.98 | 48.65 | 49.35 | 49.84 |  |  |  |  |  |  |
| September | 50.83 | 50.81 | 51.00 | 50.81 | 49.08 | 48.76 | 49.24 | 49.86 |  |  |  |  |  |  |
| October | 50.69 | 50.66 | 50.96 | 50.88 | 48.88 | 49.08 | 49.43 | 49.7 |  |  |  |  |  |  |
| November | 50.67 | 50.44 | 50.72 | 50.58 | 49.19 | 49.07 | 49.32 | 49.34 |  |  |  |  |  |  |
| December | 50.62 | 50.56 | 50.59 | 50.44 | 49.05 | 49.09 | 49.20 | 49.4 |  |  |  |  |  |  |
| Average | 50.81 | 50.72 | 50.71 | 50.73 | 49.04 | 48.99 | 49.30 | 49.66 |  |  |  |  |  |  |

Table E.8: Average Daily System Voltage, 2020-2023

|  | Upper Voltage limit(kV) | Lower Voltage limit(kV) | Nominal Standard(kV) | Average system voltage(upper bound)(kV) |  |  |  | Average system voltage(lower bound)(kV) |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2023 | 2022 | 2021 | 2020 | 2023 | 2022 | 2021 | 2020 |  |  |  |  |
| January | 346.50 | 313.50 | 330.00 | 357.50 | 352.90 | 349.81 | 355.48 | 300.50 | 297.74 | 298.48 | 298.19 |
| February | 354.28 | 352.76 | 348.96 | 351.52 | 299.17 | 297.36 | 299.21 | 299.00 |  |  |  |
| March | 349.55 | 351.18 | 350.87 | 352.65 | 292.75 | 297.00 | 296.07 | 299.03 |  |  |  |
| April | 351.97 | 358.00 | 349.13 | 356.80 | 299.34 | 299.00 | 297.17 | 290.97 |  |  |  |
| May | 354.30 | 357.00 | 351.75 | 355.29 | 296.33 | 300.00 | 294.78 | 290.87 |  |  |  |
| June | 356.27 | 358.00 | 353.47 | 355.90 | 297.03 | 300.00 | 299.97 | 297.50 |  |  |  |
| July | 350.77 | 335.42 | 353.35 | 355.00 | 300.00 | 299.53 | 300.16 | 296.93 |  |  |  |
| August | 353.32 | 358.24 | 352.23 | 354.47 | 299.39 | 299.10 | 298.74 | 297.67 |  |  |  |
| September | 355.73 | 353.21 | 352.90 | 354.83 | 299.20 | 299.83 | 297.74 | 300.97 |  |  |  |
| October | 348.00 | 351.03 | 352.90 | 353.74 | 297.00 | 299.45 | 297.74 | 296.16 |  |  |  |
| November | 348.00 | 352.96 | 352.76 | 352.37 | 299.00 | 299.93 | 397.36 | 294.87 |  |  |  |
| December | 347.00 | 352.21 | 351.18 | 349.55 | 299.00 | 298.73 | 297.00 | 298.61 |  |  |  |
| Average |  |  |  | 352.22 | 352.74 | 351.61 | 353.97 | 298.23 | 298.97 | 297.87 | 296.73 |

* * *

Metering

Table E.9: Customers registered, metered, and unmetered, 2023

| Registered Customers(RC)by DisCos |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Distribution Company | 2023/Q1As of 31 March |  | 2023/Q2As of 30 June |  | 2023/Q3As of 30 September |  | 2023/Q4As of 31 December |  |
| RegisteredCustomers | % | RegisteredCustomers | % | RegisteredCustomers | % | RegisteredCustomers | % |  |
| 184,348 | 1.49 | 187,274 | 1.49 | 189,043 | 1.47 | 191,405 | 1.45 |  |
| Aba | 1,323,358 | 10.69 | 1,353,671 | 10.78 | 1,388,325 | 10.83 | 1,414,356 | 10.75 |
| Benin | 1,214,377 | 9.81 | 1,270,157 | 10.11 | 1,291,181 | 10.07 | 1,324,373 | 10.06 |
| Eko | 701,083 | 5.66 | 708,946 | 5.64 | 724,480 | 5.65 | 736,146 | 5.59 |
| Enugu | 1,394,664 | 11.27 | 1,395,950.00 | 11.11 | 1,396,440 | 10.89 | 1,396,440 | 10.61 |
| Ibadan | 2,266,168 | 18.31 | 2,309,585 | 18.39 | 2,350,136 | 18.32 | 2,401,864 | 18.25 |
| Ikeja | 1,188,391 | 9.60 | 1,206,641 | 9.61 | 1,232,688 | 9.61 | 1,238,295 | 9.41 |
| Jos | 711,589 | 5.75 | 716,774 | 5.71 | 722,731 | 5.64 | 730,402 | 5.55 |
| Kaduna | 848,568 | 6.86 | 854,818 | 6.81 | 856,991 | 6.68 | 864,128 | 6.57 |
| Kano | 851,550 | 6.88 | 857,109 | 6.82 | 861,466 | 6.72 | 872,656 | 6.63 |
| Port Harcourt | 1,179,194 | 9.53 | 1,179,194 | 9.39 | 1,179,194 | 9.19 | 1,179,194 | 8.96 |
| Yola | 514,953 | 4.16 | 520,930 | 4.15 | 632,330 | 4.93 | 813,313 | 6.18 |
| Total | 12,378,243 | 100.00 | 12,561,049 | 100.00 | 12,825,005 | 100.00 | 13,162,572 | 100 |

Metered Customers by DisCos

| Distribution Company | 2023/Q1As of 31 March |  | 2023/Q2As of 30 June |  | 2023/Q3As of 30 September |  | 2023/Q4As of 31 December |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| MeteredCustomers | % | MeteredCustomers | % | MeteredCustomers | % | MeteredCustomers | % |  |
| Aba | 45,509 | 0.85 | 47,164 | 0.85 | 50,397 | 0.88 | 54,462 | 0.93 |
| Abuja | 782,344 | 14.59 | 809,268 | 14.59 | 835,961 | 14.65 | 856,435 | 14.66 |
| Benin | 615,296 | 11.48 | 626,241 | 11.29 | 639,162 | 11.20 | 659,511 | 11.29 |
| Eko | 405,087 | 7.56 | 418,437 | 7.54 | 424,552 | 7.44 | 431,336 | 7.38 |
| Enugu | 562,117 | 10.49 | 588,060 | 10.60 | 604,405 | 10.59 | 616,210 | 10.55 |
| Ibadan | 942,315 | 17.58 | 980,296 | 17.67 | 1,011,630 | 17.72 | 1,046,873 | 17.92 |
| Ikeja | 812,480 | 15.16 | 849,413 | 15.31 | 887,485 | 15.55 | 898,202 | 15.37 |
| Jos | 231,381 | 4.32 | 235,850 | 4.25 | 239,442 | 4.19 | 243,049 | 4.16 |
| Kaduna | 198,972 | 3.71 | 201,386 | 3.63 | 203,718 | 3.57 | 206,076 | 3.53 |
| Kano | 206,471 | 3.85 | 207,798 | 3.75 | 209,153 | 3.66 | 210,338 | 3.60 |
| Port Harcourt | 458,915 | 8.56 | 469,073 | 8.46 | 483,491 | 8.47 | 494,246 | 8.46 |
| Yola | 99,547 | 1.86 | 113,497 | 2.05 | 118,442 | 2.08 | 125,988 | 2.16 |
| Total | 5,360,434 | 100.00 | 5,546,483 | 100.00 | 5,707,838 | 100.00 | 5,842,726 | 100.00 |

| Distribution Company | 2023/Q1As of 31 March |  | 2023/Q2As of 30 June |  | 2023/Q3As of 30 September |  | 2023/Q4As of 31 December |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| UnmeteredCustomers | % | UnmeteredCustomers | % | UnmeteredCustomers | % | UnmeteredCustomers | % |  |
| Aba | 138,839 | 1.98 | 140,110 | 2.00 | 138,646 | 1.95 | 136,943 | 1.87 |
| Abuja | 541,014 | 7.71 | 544,403 | 7.76 | 552,364 | 7.76 | 557,921 | 7.62 |
| Benin | 599,081 | 8.54 | 643,916 | 9.18 | 652,019 | 9.16 | 664,862 | 9.08 |
| Eko | 295,996 | 4.22 | 290,509 | 4.14 | 299,928 | 4.21 | 304,810 | 4.16 |
| Enugu | 832,547 | 11.86 | 807,890 | 11.52 | 792,035 | 11.13 | 780,230 | 10.66 |
| Ibadan | 1,323,853 | 18.86 | 1,329,289 | 18.95 | 1,338,506 | 18.81 | 1,354,991 | 18.51 |
| Ikeja | 375,911 | 5.36 | 357,228 | 5.09 | 345,203 | 4.85 | 340,093 | 4.65 |
| Jos | 480,208 | 6.84 | 480,924 | 6.86 | 483,289 | 6.79 | 487,353 | 6.66 |
| Kaduna | 649,596 | 9.26 | 653,432 | 9.32 | 653,273 | 9.18 | 658,052 | 8.99 |
| Kano | 645,079 | 9.19 | 649,311 | 9.26 | 652,313 | 9.17 | 662,318 | 9.05 |
| Port Harcourt | 720,279 | 10.26 | 710,121 | 10.12 | 695,703 | 9.77 | 684,948 | 9.36 |
| Yola | 415,406 | 5.92 | 407,433 | 5.81 | 513,888 | 7.22 | 687,325 | 9.39 |
| Total | 7,017,809 | 100.00 | 7,014,566 | 100.00 | 7,117,167 | 100.00 | 7,319,846 | 100.00 |

Unmetered Customers by DisCos

* * *

F. Commercial Performance

Table F.1: DisCos’ energy received, billed and billing efficiency 2021-2023

| DisCos | Total Energy Received (GWh) |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- |
| 2023 Quarters |  |  |  | Annual |  |  |  |
| /Q1 | /Q2 | /Q3 | /Q4 | 2023 | 2022 | 2021 |  |
| Abuja | 1091 | 1081 | 1060 | 1248 | 4483 | 3,906 | 4,050 |
| Benin | 635 | 649 | 602 | 665 | 2552 | 2,698 | 2,683 |
| Eko | 927 | 897 | 938 | 1039 | 3801 | 3,125 | 3,591 |
| Enugu | 640 | 616 | 583 | 682 | 2520 | 2,612 | 2,841 |
| Ibadan | 856 | 817 | 894 | 988 | 3556 | 3,450 | 4,092 |
| Ikeja | 1150 | 1132 | 1159 | 1232 | 4673 | 4,082 | 4,548 |
| Jos | 409 | 352 | 372 | 426 | 1559 | 1,566 | 1,403 |
| Kaduna | 492 | 389 | 416 | 546 | 1843 | 2,110 | 2,324 |
| Kano | 506 | 418 | 416 | 531 | 1871 | 1,923 | 1,951 |
| Port Harcourt | 548 | 533 | 528 | 578 | 2187 | 2,024 | 2,109 |
| Yola | 240 | 213 | 217 | 265 | 935 | 856 | 902 |
| Total | 7,495 | 7,101 | 7,184 | 8199 | 29,980 | 28,352 | 30,494 |
| Average | 681 | 646 | 653 | 745 | 2,725 | 2,577 | 2,772 |
|  | Total Energy Billed (GWh) |  |  |  |  |  |  |
| /Q1 | /Q2 | /Q3 | /Q4 | 2023 | 2022 | 2021 |  |
| 783 | 796 | 776 | 884 | 3,239 | 2,677 | 2,682 |  |
| Abuja | 546 | 549 | 518 | 566 | 2,179 | 2,274 | 2,246 |
| Benin | 824 | 818 | 826 | 934 | 3,402 | 2,786 | 3,141 |
| Eko | 824 | 818 | 826 | 934 | 3,402 | 2,786 | 3,141 |
| Enugu | 463 | 453 | 443 | 509 | 1,868 | 1,852 | 2,035 |
| Ibadan | 667 | 676 | 682 | 800 | 2,824 | 2,567 | 2,920 |
| Ikeja | 984 | 1044 | 1007 | 1070 | 4,104 | 3,613 | 4,081 |
| Jos | 332 | 293 | 303 | 338 | 1,266 | 1,181 | 976 |
| Kaduna | 268 | 250 | 220 | 242 | 980 | 1,349 | 1,767 |
| Kano | 368 | 304 | 292 | 362 | 1,326 | 1,346 | 1,454 |
| Port Harcourt | 452 | 444 | 439 | 474 | 1,809 | 1,639 | 1,625 |
| Yola | 157 | 163 | 176 | 253 | 750 | 486 | 420 |

* * *

Table F.2: Revenue performance by DisCos, 2021-2023

| DisCos | Total Billing (N³ Billion) |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- |
| 2023 Quarters |  |  |  | Annual |  |  |  |
| /Q1 | /Q2 | /Q3 | /Q4 | 2023 | 2022 | 2021 |  |
| Abuja | 51.28 | 52.77 | 50.73 | 57.47 | 212.25 | 154.22 | 140.63 |
| Benin | 32.57 | 33.77 | 31.41 | 34.36 | 132.12 | 122.07 | 105.77 |
| Eko | 50.45 | 49.31 | 51.81 | 59.68 | 211.24 | 151.31 | 145.61 |
| Enugu | 27.77 | 27.37 | 25.90 | 30.63 | 111.67 | 101.34 | 98.00 |
| Ibadan | 38.74 | 39.95 | 39.77 | 46.46 | 164.92 | 137.33 | 139.71 |
| Ikeja | 56.90 | 58.76 | 58.35 | 62.90 | 236.90 | 182.42 | 184.22 |
| Jos | 23.95 | 20.82 | 21.12 | 23.42 | 89.31 | 73.57 | 49.32 |
| Kaduna | 17.24 | 13.95 | 12.10 | 14.87 | 58.16 | 71.98 | 89.77 |
| Kano | 22.04 | 19.33 | 19.15 | 23.32 | 83.85 | 73.79 | 69.17 |
| Port Harcourt | 27.55 | 27.13 | 26.55 | 28.85 | 110.08 | 90.34 | 76.23 |
| Yola | 10.89 | 11.46 | 12.66 | 17.74 | 52.75 | 26.93 | 18.47 |
| Total | 359.38 | 354.61 | 349.56 | 399.69 | 1,463.24 | 1,185.31 | 1,116.92 |
| Average | 32.67 | 32.24 | 31.78 | 36.34 | 243.87 | 107.76 | 101.54 |
|  | Total Revenue Collected (N³ Billion) |  |  |  |  |  |  |
| /Q1 | /Q2 | /Q3 | /Q4 | 2023 | 2022 | 2021 |  |
| 39.10 | 43.58 | 41.29 | 46.23 | 170.20 | 127.80 | 117.61 |  |
| Abuja | 19.54 | 21.81 | 21.20 | 22.38 | 84.93 | 69.90 | 58.16 |
| Benin | 40.96 | 43.25 | 43.69 | 50.19 | 178.09 | 127.79 | 120.89 |
| Eko | 19.03 | 20.88 | 20.04 | 23.33 | 83.28 | 70.93 | 69.83 |
| Enugu | 19.03 | 20.88 | 20.04 | 23.33 | 83.28 | 70.93 | 69.83 |
| Ibadan | 24.85 | 28.09 | 28.72 | 31.82 | 113.47 | 95.67 | 91.37 |
| Ikeja | 49.61 | 55.82 | 57.25 | 59.75 | 222.43 | 168.31 | 157.40 |
| Jos | 9.72 | 9.52 | 10.14 | 10.96 | 40.35 | 31.01 | 24.80 |
| Kaduna | 7.63 | 8.28 | 7.74 | 9.07 | 32.73 | 28.25 | 30.64 |

* * *

Table F.3: ATC&C losses performance, 2019-2023

|  | 2023 |  | 2022 |  | 2021 |  | 2020 |  | 2019 |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| DisCos | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) | MYTO Target(%) | ATC&C Losses(%) |
| Abuja | 19.27 | 42.06 | 19.27 | 43.20 | 22.80 | 44.62 | 22.33 | 45.8 | 24 | 41.07 |
| Benin | 17.37 | 45.11 | 17.37 | 51.73 | 21.71 | 53.96 | 23.91 | 55.41 | 31 | 50.52 |
| Eko | 14.18 | 24.54 | 14.18 | 24.71 | 14.70 | 27.38 | 11.23 | 30.85 | 14 | 26.22 |
| Enugu | 11.31 | 44.72 | 11.31 | 50.38 | 19.96 | 48.97 | 20.56 | 53.83 | 29 | 30.94 |
| Ibadan | 15.47 | 45.36 | 15.47 | 48.16 | 18.55 | 53.33 | 19.67 | 56.74 | 25 | 47.74 |
| Ikeja | 11.37 | 17.54 | 11.37 | 18.33 | 12.52 | 23.34 | 10.81 | 28.21 | 15 | 23.91 |
| Jos | 27.27 | 63.32 | 27.27 | 68.22 | 35.98 | 65.02 | 39.12 | 67.79 | 44 | 60.4 |
| Kaduna | 10.65 | 70.07 | 10.65 | 74.90 | 17.18 | 74.05 | 20.12 | 76.80 | 32 | 66.81 |
| Kano | 15.85 | 54.27 | 15.85 | 53.61 | 18.65 | 48.94 | 22.06 | 50.78 | 29 | 43.72 |
| PH | 21.45 | 43.66 | 21.45 | 47.30 | 25.85 | 51.76 | 29.70 | 60.80 | 37 | 61.62 |
| Yola | 64.12 | 65.04 | 64.12 | 69.50 | 29.44 | 75.96 | 23.71 | 73.24 | 28 | 65.08 |
| All DisCos: |  |  |  |  |  |  |  |  |  |  |
| MYTO Level | 20.75 |  | 20.75 |  | 21.58 |  | 22.11 |  | 26 |  |
| ATC&C Losses | - | 41.67 | - | 45.46 |  | 46.85 |  | 50.57 |  | 43.85 |
| ATC Losses | - | 20.79 | - | 23.21 |  | 23.43 |  | 25.67 |  | 17.23 |
| C Losses | - | 26.36 | - | 28.98 |  | 30.58 |  | 33.50 |  | 32.16 |

Notes of the table: MYTO is Multi-Year Tariff Order; ATC&C is Aggregate Technical, Commercial and Collection; ATC is
aggregate Technical & Commercial losses; and C is Collection loss

* * *

Table F.4: NBET and MO invoice to DisCos, 2019-2023

|  | Jan23 | Feb23 | Mar23 | Apr23 | May23 | Jun23 | Jul23 | Aug23 | Sep23 | Oct23 | Nov23 | Dec23 | 2023 | 2022 | 2021 | 2020 | 2019 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| NBET Invoice | Amount in (¥/Billion) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Abuja | 11.14 | 10.93 | 12.80 | 11.74 | 15.08 | 18.92 | 19.40 | 19.43 | 19.57 | 22.55 | 24.23 | 16.60 | 202.41 | 109.61 | 101.33 | 89.91 | 87.88 |
| Benin | 6.58 | 6.45 | 7.07 | 6.82 | 9.31 | 10.57 | 10.36 | 10.19 | 11.08 | 12.23 | 12.74 | 6.85 | 110.25 | 74.89 | 72.87 | 64.93 | 54.28 |
| Eko | 8.23 | 7.40 | 8.38 | 7.14 | 10.24 | 12.33 | 13.22 | 13.60 | 15.10 | 18.68 | 21.00 | 12.40 | 147.71 | 84.43 | 93.01 | 84.12 | 77.99 |
| Enugu | 6.81 | 6.97 | 7.03 | 6.87 | 9.00 | 10.56 | 10.15 | 10.22 | 10.69 | 12.90 | 13.23 | 8.47 | 112.91 | 75.01 | 75.05 | 62.88 | 52.94 |
| Ibadan | 8.77 | 8.77 | 9.86 | 8.79 | 12.03 | 13.47 | 13.47 | 13.99 | 15.50 | 17.32 | 19.38 | 9.16 | 150.49 | 100.45 | 108.07 | 97.72 | 83.21 |
| Ikejia | 11.40 | 11.53 | 13.15 | 11.65 | 15.88 | 19.34 | 20.50 | 20.78 | 20.50 | 22.10 | 24.24 | 15.67 | 206.65 | 117.90 | 122.51 | 107.19 | 89.52 |
| Jos | 4.56 | 4.42 | 4.67 | 4.37 | 5.60 | 5.45 | 6.66 | 6.53 | 7.06 | 8.33 | 8.65 | 3.43 | 69.73 | 45.56 | 41.33 | 37.44 | 29.46 |
| Kaduna | 5.23 | 5.08 | 5.34 | 4.56 | 5.43 | 5.88 | 7.34 | 7.35 | 7.31 | 10.12 | 10.74 | 4.96 | 79.34 | 60.44 | 63.97 | 58.34 | 45.69 |
| Kano | 5.34 | 5.09 | 5.82 | 4.84 | 6.25 | 6.16 | 7.02 | 7.40 | 8.08 | 9.77 | 10.61 | 5.21 | 81.60 | 57.59 | 58.66 | 52.43 | 41.27 |
| Port Harcourt | 5.75 | 5.93 | 5.95 | 5.73 | 7.90 | 8.59 | 8.93 | 9.44 | 9.39 | 10.31 | 11.15 | 6.53 | 95.59 | 57.28 | 54.28 | 48.39 | 45.77 |

NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively.

* * *

Table F.5: Remittances to NBET and MO by DisCos, 2019-2023

|  | Jan23 | Feb23 | Mar23 | Apr23 | May23 | Jun23 | Jul23 | Aug23 | Sep23 | Oct23 | Nov23 | Dec23 | 2023 | 2022 | 2021 | 2020 | 2019 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Remittances to NBET | Amount in (N'Billion) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Abuja | 4.58 | 8.32 | 7.11 | 7.89 | 9.31 | 7.60 | 8.02 | 7.49 | 8.52 | 10.63 | 9.41 | 10.10 | 98.96 | 83.07 | 64.90 | 34.23 | 34.98 |
| Benin | 4.54 | 5.31 | 5.58 | 5.27 | 5.09 | 3.84 | 3.96 | 2.84 | 2.07 | 4.69 | 3.54 | 3.90 | 50.64 | 46.64 | 33.09 | 19.70 | 14.10 |
| Eko | 6.71 | 5.92 | 6.85 | 5.67 | 8.62 | 4.87 | 6.42 | 6.60 | 7.33 | 9.07 | 10.20 | 11.50 | 89.75 | 72.37 | 64.12 | 35.60 | 31.92 |
| Enugu | 4.90 | 5.50 | 5.32 | 5.49 | 6.51 | 4.63 | 2.70 | 2.74 | 3.43 | 3.60 | 4.01 | 3.97 | 52.80 | 51.08 | 42.26 | 19.74 | 12.45 |
| Ibadan | 5.24 | 6.65 | 7.01 | 6.71 | 7.42 | 5.04 | 3.52 | 3.72 | 4.50 | 4.97 | 4.71 | 6.37 | 65.75 | 64.18 | 53.36 | 30.31 | 22.74 |
| Ikeja | 9.81 | 10.79 | 9.06 | 11.27 | 11.68 | 8.82 | 9.69 | 9.83 | 9.69 | 9.74 | 11.46 | 8.19 | 120.03 | 102.95 | 93.37 | 47.99 | 34.37 |
| Jos | 2.26 | 2.45 | 2.69 | 2.25 | 2.78 | 1.54 | 0.78 | 0.94 | 1.50 | 1.16 | 1.90 | 1.57 | 21.82 | 21.05 | 13.13 | 4.66 | 2.12 |
| Kaduna | 0.54 | 0.97 | 0.37 | 0.64 | 0.92 | 0.42 | 0.47 | 0.09 | 0.52 | 0.32 | 0.42 | 0.48 | 6.14 | 10.11 | 14.28 | 12.42 | 6.92 |
| Kano | 2.22 | 2.30 | 1.63 | 2.08 | 2.06 | 1.94 | 1.41 | 2.36 | 2.02 | 2.17 | 2.59 | 2.42 | 25.20 | 27.72 | 31.72 | 13.02 | 10.20 |
| Port Harcourt | 3.88 | 2.73 | 2.98 | 4.36 | 4.67 | 1.91 | 3.69 | 3.36 | 2.75 | 3.53 | 3.35 | 4.53 | 41.74 | 31.96 | 24.62 | 8.93 | 8.55 |

NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively.

* * *

Table F.6: Annual shortfalls to NBET and MO by DisCos, 2019-2023

|  | Jan23 | Feb23 | Mar23 | Apr23 | May23 | Jun23 | Jul23 | Aug23 | Sep23 | Oct23 | Nov23 | Dec23 | 2023 | 2022 | 2021 | 2020 | 2019 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Amount in (N³ Billion) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Abuja | -6.56 | -2.61 | -5.69 | -3.85 | -5.77 | -11.32 | -11.38 | -11.94 | -11.05 | -11.92 | -14.82 | -6.50 | -103.41 | -26.54 | -36.43 | -55.68 | -52.89 |
| Benin | -2.04 | -1.14 | -1.49 | -1.55 | -4.22 | -6.73 | -6.40 | -7.35 | -9.01 | -7.54 | -9.20 | -2.95 | -59.62 | -28.26 | -39.77 | -45.22 | -40.18 |
| Eko | -1.52 | -1.48 | -1.53 | -1.47 | -1.62 | -7.46 | -6.80 | -7.00 | -7.77 | -9.61 | -10.80 | -0.9 | -57.96 | -12.06 | -28.89 | -48.52 | -46.07 |
| Enugu | -1.91 | -1.47 | -1.71 | -1.38 | -2.49 | -5.93 | -7.45 | -7.48 | -7.26 | -9.30 | -9.22 | -4.5 | -60.10 | -23.93 | -32.79 | -43.14 | -40.49 |
| Ibadan | -3.53 | -2.12 | -2.85 | -2.08 | -4.61 | -8.43 | -9.95 | -10.27 | -11.00 | -12.35 | -14.67 | -2.79 | -84.64 | -36.27 | -54.72 | -67.41 | -60.47 |
| Ikeja | -1.59 | -0.74 | -4.09 | -0.38 | -4.20 | -10.52 | -10.81 | -10.95 | -10.81 | -12.36 | -12.78 | -7.48 | -86.71 | -14.95 | -29.13 | -59.20 | -55.14 |
| Jos | -2.30 | -1.97 | -1.98 | -2.12 | -2.82 | -3.91 | -5.88 | -5.59 | -5.56 | -7.17 | -6.75 | -1.86 | -47.91 | -24.51 | -28.20 | -32.78 | -27.34 |
| Kaduna | -4.69 | -4.11 | -4.97 | -3.92 | -4.51 | -5.46 | -6.87 | -7.26 | -6.79 | -9.80 | -10.32 | -4.48 | -73.18 | -50.33 | -49.69 | -45.92 | -38.77 |
| Kano | -3.12 | -2.79 | -4.19 | -2.76 | -4.19 | -4.22 | -5.61 | -5.04 | -6.06 | -7.60 | -8.02 | -2.79 | -56.39 | -29.87 | -26.94 | -39.41 | -31.07 |
| Port Harcourt | -1.87 | -3.20 | -2.97 | -1.37 | -3.23 | -6.68 | -5.24 | -6.08 | -6.64 | -6.78 | -7.80 | -2.00 | -53.86 | -25.32 | -29.66 | -39.46 | -37.22 |

Notes of the table:

1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operators respectively.

Notes of the table:

1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operators respectively.

* * *

Table F.7: Market invoice, remittance and shortfall by DisCos, 2019-2023

\| \| Invoice
(¥' Billion) \| \| \| \| \| Remittances

(¥' Billion) \| \| \| \| \|
\| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \| \-\-\- \|
\| DisCos \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \|
\| Abuja \| 158.12 \| 118.96 \| 126.93 \| 109.57 \| 102.99 \| 119.76 \| 100.53 \| 92.68 \| 50.91 \| 46.07 \|
\| Benin \| 68.25 \| 78.00 \| 93.08 \| 78.44 \| 63.61 \| 62.87 \| 57.01 \| 48.32 \| 33.34 \| 21.19 \|
\| Eko \| 104.85 \| 89.64 \| 116.44 \| 102.14 \| 91.37 \| 107.90 \| 87.55 \| 87.05 \| 53.58 \| 43.94 \|
\| Enugu \| 79.78 \| 82.33 \| 95.47 \| 75.96 \| 62.03 \| 62.66 \| 61.10 \| 58.32 \| 32.81 \| 19.21 \|
\| Ibadan \| 91.29 \| 101.76 \| 137.1 \| 118.53 \| 97.50 \| 82.33 \| 82.72 \| 74.61 \| 50.58 \| 33.98 \|
\| Ikeja \| 151.81 \| 123.19 \| 154.67 \| 128.80 \| 104.82 \| 144.47 \| 122.90 \| 116.88 \| 69.60 \| 47.72 \|
\| Jos \| 35.03 \| 38.53 \| 53.65 \| 44.84 \| 34.52 \| 28.29 \| 27.33 \| 22.34 \| 11.70 \| 5.70 \|
\| Kaduna \| 45.70 \| 60.65 \| 79.82 \| 70.20 \| 53.58 \| 7.30 \| 13.39 \| 19.3 \| 21.64 \| 12.62 \|
\| Kano \| 50.70 \| 58.61 \| 71.5 \| 62.52 \| 48.38 \| 30.79 \| 34.18 \| 40.22 \| 22.21 \| 15.12 \|
\| Port Harcourt \| 63.29 \| 57.76 \| 67.57 \| 58.53 \| 53.63 \| 51.25 \| 39.18 \| 34.92 \| 18.39 \| 14.28 \|
\| Yola \| 9.23 \| 6.81 \| 31.59 \| 33.20 \| 31.07 \| 9.11 \| 6.37 \| 4.4 \| 5.59 \| 6.88 \|
\| Total \| 858.03 \| 816.25 \| 1,027.83 \| 882.73 \| 743.50 \| 706.73 \| 632.25 \| 599.04 \| 370.34 \| 266.71 \|
\| Average \| 78.00 \| 74.20 \| 93.44 \| 80.25 \| 67.59 \| 64.25 \| 57.48 \| 54.46 \| 33.67 \| 24.25 \|
\| \| Shortfalls
(¥' Billion) \| \| \| \| \| Remittance Performance
(%) \| \| \| \| \|
\| DisCos \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \| 2023 \| 2022 \| 2021 \| 2020 \| 2019 \|
\| Abuja \| -38.36 \| 18.43 \| -34.25 \| 58.66 \| 56.92 \| 75.74 \| 84.51 \| 73.02 \| 46.46 \| 44.73 \|
\| Benin \| -5.38 \| 21.00 \| -44.75 \| 45.10 \| 42.42 \| 92.12 \| 73.08 \| 51.91 \| 42.51 \| 33.31 \|

1times4^{\\prime}

Notes of the table:

1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively.

Notes of the table:

1. NBET and MO are Nigeria Bulk Electricity Trader and Market Operator respectively.

2. 2023 and 2022 market data are based on MRO.

3. 2023 and 2022 market data are based on MRO.


* * *

NIGERIAN ELECTRICITY REGULATORY COMMISSION

Plot 1387 Cadastral Zone A00, Central Business Disreict, PMB 136, Garki Abuja