## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## i \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# NERC©2024

# The Nigerian Electricity Regulatory Commission (NERC) quarterly report is prepared

# in compliance with Section 56(3) of the Electricity Act 2023, which mandates the

# Commission to submit quarterly reports of its activities to the President and the

# National Assembly. The report analyses the state of the Nigerian Electricity Supply

# Industry (NESI) covering the operational and commercial performance, regulatory

# functions, as well as consumer affairs. The report is directed at a wide spectrum of

# readers including energy economists, engineers, financial and market analysts,

# potential investors, government officials and institutions, the private sector as well as

# general readers. NERC quarterly report is freely available to stakeholders of the

**NESI, government agencies and corporations. Individuals can also access any issue freely from the Commission’s Website: [www.nerc.gov.ng](http://www.nerc.gov.ng/)**

# Please direct all inquiries, comments, and suggestions on the report to:

# The Commissioner Planning, Research and Strategy Division

# Nigerian Electricity Regulatory Commission Plot 1387, Cadastral Zone A00

# Central Business District P.M.B 136, Garki, Abuja

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

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

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

## ii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# Table of Contents

## 1.0 SUMMARY ... viii 2.0 STATE OF THE INDUSTRY ... 2

## 2.1 Operational Performance ... 2 2.1.1 Available Generation ... 2

## 2.1.2 Plant Availability Factor ... 4 2.1.3 Total Quarterly Generation ... 6

## 2.1.4 Generation Load Factor ... 8 2.1.5 Generation Mix ... 10

## 2.2 Grid Performance ... 11 2.2.1 Transmission Loss Factor ... 12

## 2.2.2 Grid Frequency ... 13 2.2.3 Voltage Fluctuation ... 15

## 2.2.4 System Collapse ... 16 2.3 Commercial Performance ... 18

## 2.3.1 Energy offtake performance ... 18 2.3.2 Energy Billed and Billing Efficiency ... 20

## 2.3.3 Revenue and Collection Efficiency ... 22 2.3.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss ... 24

## 2.3.5 Market Remittance ... 26 3.0 REGULATORY FUNCTIONS ... 34

## 3.1 Regulations, Orders and Directives ... 35 3.1.1 Regulations ... 35

## 3.1.2 Orders ... 35 3.1.3 Directives ... 41

## 3.2 Licences Issued or Renewed ... 41 3.3 Captive Power Generation Permits ... 42

## 3.4 Mini-grid Permits and Registration Certificates ... 42 3.5 Meter Service Providers/Meter Asset Providers ... 43

## 3.6 Hearings and Public Consultations ... 44 3.7 Compliance and Enforcement ... 45

## 3.8 Alternative Dispute Resolution ... 45 4.0 CONSUMER AFFAIRS ... 48

## 4.1 Consumer Enlightenment and Stakeholder Engagements ... 48 4.2 Metering End-Use Customers ... 49

## 4.3 Customer Complaints ... 51 4.3.1 NERC-CCU ... 53

## 4.3.2 DisCo-CCUs ... 54 4.3.3 Forum Offices ... 56

## 4.4 Health and Safety ... 58 5.0 Appendix ... 62

### iii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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List of Tables

List of Tables
Table 1: Plant Availability Factor (%) in 2024/Q1 vs. 2024/Q2................................... 5
Table 2: Average Hourly Generation (MWh/h) in 2024/Q1 vs. 2024/Q2.................... 8
Table 3: System Collapse in 2024/Q2 ..................................................................... 17
Table 4: DisCo energy offtake performance in 2024/Q1 vs. 2024/Q2........................ 20
Table 5: Energy Received and Billing Efficiency by DisCos in 2024/Q1 vs. 2024/Q2 ... 21
Table 6: Revenue Collection Performance (%) of DisCos in 2024/Q1 vs. 2024/Q2...... 23
Table 7: ATC&C Loss (%) by DisCos in 2024/Q1 vs. 2024/Q2.................................. 25
Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q2 ......... 28
Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q2..................... 31
Table 10: Invoices and Remittances of Other Customers in 2024/Q2........................... 32
Table 11: Reporting Requirements on the Operationalisation of MAF .......................... 40
Table 12: Licences issued by the Commission in 2024/Q2.......................................... 42
Table 13: Meter Service Providers certified in 2024/Q2 ............................................ 43
Table 14: Hearings conducted by the Commission in 2024/Q2................................... 44
Table 15: Compliance and Enforcement Actions of the Commission in 2024/Q2........... 45
Table 16: Metering Progress as of 2024/Q2 ............................................................ 49
Table 17: Meter Deployment by DisCos in 2024/Q1 vs. 2024/Q2............................. 50
Table 18: Complaints Received by DisCos in 2024/Q1 vs. 2024/Q2.......................... 54
Table 19: Appeals handled by Forum Offices in 2024/Q2......................................... 56
Table 20: Health and Safety (H&S) Reports in 2024/Q1 vs. 2024/Q2........................ 58
Table 21: Causes of casualties recorded in 2024/Q2................................................ 59

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### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# List of Figures

**Figure 1: Average Available Capacity (MW) in 2024/Q1 vs. 2024/Q2 ... 3**

**Figure 2: Average Hourly Generation (MWh/h) in 2024/Q1 vs. 2024/Q2 ... 7**

**Figure 3: Load Factor (%) in 2024/Q1 vs. 2024/Q2 ... 10**

**Figure 4: Electricity Generated by Energy Sources in 2024/Q1 vs. 2024/Q2 ... 11**

**Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) Jan-June 202413**

**Figure 6: Monthly System Frequency from Jan-June 2024 ... 14**

**Figure 7: Monthly System Voltage (kV) from Jan-June 2024 ... 16**

**Figure 8: DisCos Remittance Performances to NBET in 2024/Q2 ... 29 Figure 9: DisCos Remittance Performances to MO in 2024/Q2 ... 30**

**Figure 10: Category of complaints received at the Commission’s CCU in 2024/Q2 ... 54**

**Figure 11: Category of complaints received by DisCos in 2024/Q2 ... 55**

**Figure 12: Category of Complaints Received by Forum Offices in 2024/Q2 ... 57 Figure 13: Accident Report for 2024/Q2 ... 59**

### v \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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List of Abbreviations

| ADR | Alternative Dispute Resolution |
| --- | --- |
| AEDC | Abuja Electricity Distribution Company Plc |
| ATC&C | Aggregate Technical, Commercial & Collection Loss |
| BEDC | Benin Electricity Distribution Company Plc |
| CAPEX | Capital Expenditure |
| CCU | Customers Complaint Unit |
| CEET | Compagnie Energie Electrique du Togo |
| CTC | Competition Transition Charge |
| DisCos | Distribution Companies |
| DSOs | Distribution System Operators |
| EA | Electricity Act |
| ECR | Eligible Customer Regulations |
| EEDC | Enugu Electricity Distribution Company Plc |
| EKEDC | Eko Electricity Distribution Company Plc |
| EPSRA | Electric Power Sector Reform Act |
| GenCos | Generation Companies |
| GWh | Gigawatt hour |
| IBEDC | Ibadan Electricity Distribution Company Plc |
| IEDN | Independent Electricity Distribution Network |
| IE | Ikeja Electric Plc |
| JED | Jos Electricity Distribution Company Plc |
| KAEDC | Kaduna Electricity Distribution Company Plc |
| KEDCO | Kano Electricity Distribution Company Plc |
| kWh | Kilowatt hour |
| MAP | Meter Assets Provider |
| MDA | Ministries, Departments and Agencies |
| MO | Market Operator |
| MTS | MYTO Target Sales |
| MW | Megawatts |
| MWh | Megawatt hour |
| MYTO | Multi-Year Tariff Order |
| NBET | Nigerian Bulk Electricity Trading plc |
| NERC | Nigerian Electricity Regulatory Commission |
| NESI | Nigerian Electricity Supply Industry |
| NICE | Notices of Intention to Commence Enforcement |
| NIGELEC | Société Nigerienne d'electricite; Nigerien Electricity Society |
| NIPP | National Integrated Power Project |
| NMMP | National Mass Metering Program |
| PAC | Partial Activation of Contract |
| PCC | Partial Contracted Capacity |
| PHED | Port Harcourt Electricity Distribution Company Plc |
| PP | Percentage points |
| SBEE | Société Béninoise d'Energie Electrique |
| TCN | Transmission Company of Nigeria Plc |
| TLF | Transmission Loss Factor |
| YEDC | Yola Electricity Distribution Company Plc |

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## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## vii \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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1.0 SUMMARY

Pursuant to Section 34(1)(e) of the Electricity Act 2023 which states
that "the Commission shall ensure the safety, security, reliability, and
quality of service in the production and delivery of electricity to
consumers”, the Nigerian Electricity Regulatory Commission (NERC or
the Commission) continues to monitor the technical, operational, and
commercial performance of the Nigerian Electricity Supply Industry
(NESI). The Commission publishes quarterly reports to apprise the
public on the overall performance of the NESI.

The average
available generation
capacity in
2024/Q2 was
4,395.77MW

Operational Performance

The Operational performance parameters reported in 2024/Q2
include the available generation capacity, plant availability factor,
total quarterly generation, load factor, and generation mix of the
twenty-eight (28) grid-connected power plants. Other parameters
reported include the frequency, voltage, and overall stability
performance of the national grid during the quarter.

a. Available Generation Capacity: In 2024/Q2, the number of gridconnected plants increased by one (1) to twenty-eight (28) as a result
of the operationalisation of the Zungeru hydropower plant, which
began evacuating power to the grid on 29 April 2024. The twentyeight (28) grid-connected power plants consist of nineteen (19) gas,
five (5) hydro, two (2) steam, and two (2) gas/steam-powered plants.
For this quarter, the average available generation capacity of the gridconnected power plants was 4,395.77MW.

The average available generation capacity across the grid-connected
plants (excluding Zungeru) decreased from the 4,249.10MW
recorded in 2024/Q1 to 4,024.81MW in 2024/Q2 representing a -
5.28% decrease (-224.29MW) (Figure A). Twenty (20) power plants
recorded decreased available generation capacities in 2024/Q2
compared to 2024/Q1.

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## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

**4,700** **Average Available Capacity (2024/Q1) 4,249.10MW**

**4,500 4,459** **)** **4,331** **(MW 4,300** **4,184** **4,100** **4,026** **3,957** **3,900 3,864** **Average Available Capacity** **Average Available Capacity (2024/Q2) 4,024.81MW** **3,700**

**3,500** **Jan-24 Feb-24 Mar-24 Apr-24 May-24 Jun-24** **Months**

# Figure A: Available Generation Capacity (January-June 2024)

**b. Average Hourly Generation: The average hourly generation on the grid in 2024/Q2 was 4,018.57MWh/h, which translates to a total** **generation of 8,776.55GWh over the quarter. The average hourly generation of available power plants (excluding Zungeru) decreased** **by -9.52% (-387.56MWh/h) from 4,069.57MWh/h in 2024/Q1 to 3,682.02MWh/h (Figure B). The decrease in energy generation**

# during the quarter was primarily due to the decrease in the available

# generation capacities of the grid-connected power plants compared to 2024/Q1.

## ix \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

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Figure B: Average Hourly Generation (January - June 2024)

c. Grid Performance: In 2024/Q2, the average lower daily (49.13Hz)
and average upper daily (50.64Hz) system frequencies were outside
the normal operating limits (49.75Hz - 50.25Hz) but remained within
the lower and higher bound stress limits (48.75Hz - 51.25Hz). The
average lower daily (304.36kV) and average upper daily (355.13kV)
system voltages were however outside the prescribed regulatory limits
(313.50kV - 346.50kV). The Commission is aware of the system risk
posed by the continuous operation of the grid outside the normal
operating limits and continues to push the SO to improve its system
coordination activities accordingly.

During 2024/Q2, there was one (1) incident of partial collapse on the
national grid. The incident occurred on 15 April 2024. In line with
section 20.1 of the Grid Code, the SO is expected to submit to the
Commission, a detailed report containing the root causes of the
incidents along with mitigation plans to avoid future recurrence.

* * *

the financial performance of the NESI to ensure efficient and
commensurate cash flow along the value chain for the sustainability of
the industry.

A total of
₦431.16
billion was
collected by all
DisCos in
2024/Q2 out
of the ₦543.64
billion billed to
customers.

a. Energy Offtake Performance: In 2024/Q2, the average energy
offtake by DisCos at their trading points was 3,165.93MWh/h which
was a decrease of -3.59% (-119.9MWh/h) compared to the
3,283.87MWh/h recorded in 2024/Q1.

b. Billing Efficiency: The total energy received by all DisCos in
2024/Q2 was 6,914.39GWh while the energy billed to end -use
customers was 5,693.11GWh, translating into an overall billing
efficiency of 82.34%. This represents an increase of +1.89pp relative
to the 80.45% recorded in 2024/Q1.

c. Collection Efficiency: The total revenue collected by all DisCos in
2024/Q2 was ₦431.16 billion out of ₦543.64 billion billed to
customers. This translates to a collection efficiency of 79.31% which
represents an increase of +0.20pp when compared to 2024/Q1
(79.11%).

d. Aggregate Technical, Commercial and Collection (ATC&C) Loss: The
Aggregate Technical, Commercial and Collection (ATC&C) loss is a
summation of billing losses incurred by a DisCo due to its inability to
bill 100% of energy delivered to customers (technical and commercial
losses) and the collection losses arising from the DisCo’s inability to
collect 100% of the bills issued to customers.

The ATC&C loss in 2024/Q2 was 34.70% comprising - technical and
commercial loss (17.66%) and collection loss (20.69%). The ATC&C
loss improved by -1.66pp compared to 2024/Q1 (36.36%).

In 2024/Q2, Yola was the only DisCo that recorded a lower ATC&C
(48.04%) than its target (56.00%). The inability of DisCos to achieve
their respective ATC&C targets means that they are not able to recover
the full revenues they require to provide returns to investors and in
some instances – they may not even fully recover the cost of delivering
electricity to the customers. Ultimately, both cases may lead to the
erosion of their long-term financial sustainability.

* * *

e. Market remittance: In 2024/Q2, the cumulative upstream invoice
payable by DisCos was ₦399.53 billion, consisting of ₦343.76 billion
1
for DRO-adjusted generation costs from NBET and ₦55.77 billion for
transmission and administrative services by the Market Operator
(MO). Out of this amount, the DisCos collectively remitted a total sum
of ₦318.65 billion (₦271.87 billion for NBET and ₦46.78 billion for
MO) with an outstanding balance of ₦80.88 billion. This translates to
a remittance performance of 79.76% in 2024/Q2 compared to the
96.93% recorded in 2024/Q1. The disaggregated DisCos remittance
performance to the market for 2024/Q2 is presented in Figure C.

f. Remittance by Special and Bilateral Customers: In 2024/Q2, the four
(4) international bilateral customers serviced by the MO made a
cumulative payment of $9.81 million against the $15.60 million invoice
issued to them by the MO for services rendered in 2024/Q2. Similarly,
the domestic bilateral customers made a cumulative payment of
₦1,295.90 million against the cumulative invoice of ₦1,991.30 million
2
issued to them by the MO for services rendered in 2024/Q2 .

Figure C: DRO adjusted invoices and remittances in 2024/Q2

1
The NBET invoice payable by the DisCos for 2024/Q2 was only ₦343.76 billion because the FGN has taken
responsibility for ~52% (₦380.06 billion) of the total generation costs in the form of subsidies arising from the
freezing of end-use customer tariffs at the rates that became effective in December 2022.
2
It is noteworthy that both local and international bilateral customers made payments during 2024/Q 2 for

2
It is noteworthy that both local and international bilateral customers made payments during 2024/Q 2 for
outstanding MO invoices from previous quarters; the international bilateral customers paid $16.65 million while
the domestic bilateral customers paid ₦1,309.97 million. The details of these payments are contained in
Appendix VII.

* * *

The Commission
issued forty-two
(42) new
Orders and one
(1) directive in
2024/Q2.

Regulatory Functions

The EA 2023, section 34(2)(d), empowers the Commission to licence
and regulate persons engaged in the generation, transmission, system
operation, distribution, supply and trading of electricity in the NESI.
Additionally, the Commission regulates market entry or exit by sector
players and issues Regulations, Guidelines and Orders that guide the
operations of licensees, permit holders and registered operators in the
sector.

a. Orders and Directives: The Commission issued forty-two (42)
Orders and one (1) directive in 2024/Q2. They include:
• NERC/2024/027—NERC/2024/037 — April 2024

• NERC/2024/027—NERC/2024/037 — April 2024
Supplementary Order to the Multi-Year Tariff Order (MYTO)
2024 for the Distribution Companies

• NERC/2024/039 — Transfer of Regulatory Oversight of the
Electricity Market in Enugu State from NERC to Enugu State
Electricity Regulatory Commission (EERC).

• NERC/2024/040 — Order on the Deregulation of Meter
Prices for Meters Deployed under the Meter Asset Provider
Scheme.

• NERC/2024/041 and NERC/2024/042 — Transfer of
Regulatory Oversight of the Electricity Market in Ekiti State
from NERC to the Ekiti State Electricity Regulatory Bureau
(EERB).
• NERC/2024/043 — Transfer of Regulatory Oversight of the

• NERC/2024/043 — Transfer of Regulatory Oversight of the
Electricity Market in Ondo State from NERC to the Ondo
State Electricity Regulatory Bureau (OSERB).

• NERC/2024/044 — NESI Interim Order on Transmission
System Dispatch Operations, Cross-Border Supply and
Related Matters 2024.
• NERC/2024/045 — Order on the Establishment of the

• NERC/2024/046 -NERC/2024/057 — May 2024
Supplementary Order to the Multi-Year Tariff Order for the
DisCos.

* * *

• NERC/2024/059 - NERC/2024/068, NERC/2024/070 —
June 2024 Supplementary Order to the Multi-Year Tariff
Order for the DisCos.

• NERC/2024/072 — Order on the operationalisation of
Tranche A of the Meter Acquisition Fund (MAF).

• NERC/2024/073 — Transfer of Regulatory Oversight of the
Electricity Market in Imo State from NERC to the Imo State
Electricity Regulatory Commission (ISERC).

• NERC/2024/003 — Directive to Independent System
Operator for the utilisation of Zungeru Hydro Electricity
Generation Company Limited for managing grid imbalances
caused by insufficient generation.

Eighteen (18)
licences, permits
and certifications
were issued by
the Commission in
2024/Q2.

b. Licences and Permits: The Commission issued eighteen (18)
licences, permits and certifications in 2024/Q2. They include:

• Two (2) on-grid generation licences with a gross capacity of
66MW.

• Five (5) new off-grid generation licences with a total nameplate
capacity of 12.36MW.

• One (1) captive generation permit with a capacity of 5MW.

• Six (6) certifications for Meter Service Providers and two (2)
permits for Meter Asset Providers.

c. Hearings and Public Consultation: The Commission is
empowered by EA 2023 to perform a quasi-judicial role towards
the resolution of disputes between stakeholders in the NESI. One of
the ways by which the Commission performs this role include
3
hearings . During the quarter (2024/Q2) the Commission
conducted three (3) hearings to consider the petitions filed by
different stakeholders on issues pertaining to the provision and
utilisation of electricity services. Furthermore, the NERC business
rules allows the Commission to undertake public consultations

3
Hearings are proceedings pursuant to the provisions of the Act through which the Commission seeks additional
information on petitions or any matter filed before it by market participants or consumers in order to make a
final decision.

* * *

through which the Commission aggregates input/opinions on
licensee applications and/or regulatory instruments which are
being drafted or reviewed.

d. Compliance and Enforcement: The Commission issued five (5)
Rectification Directives (RD), five (5) Notices of Intention to
Commence Enforcement (NICE) and three (3) fines, to licensees for
different breaches/defaults during the quarter.

Consumer Affairs

a. Consumer Enlightenment and Stakeholder Engagement: The
Commission’s main consumer education and enlightenment
mechanisms are town hall meetings and customer complaints
resolution meetings. In April 2024, the Commission convened a
town hall meeting in Enugu where issues around service-based
tariffs, capping, metering, and customer redress mechanisms were
discussed.

As part of its routine activities, the Commission also engages
relevant stakeholders and the wider public to apprise them of the
Commission’s activities. The details of these engagements and other
educative content on pertinent industry issues are shared with the
public via the Commission’s social media accounts (LinkedIn, X and
Instagram).

A total of 49,188
meters were
installed in
2024/Q2.

b. Metering: A total of 49,188 meters were installed in 2024/Q2,
representing a decrease of -60.86% compared to the 125,664
meters installed in 2024/Q1. The new installations increased the
net end-user metering rate in the NESI by 0.64pp between
2024/Q1 (44.79%) and 2024/Q2 (45.43%). During the quarter,
35,985 meters (73.16% of the total installations) were installed
under the MAP framework while 264 meters were installed under
the NMMP framework. The Vendor Financed framework accounted
for 12,843 meter installations while 96 meter installations were
recorded under the DisCo Financed framework. The metering by
the respective DisCos in the quarter under review is presented in
Figure D.

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## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# The Commission expects DisCos to utilise a combination of the five

**(5) meter financing frameworks that have been provided in the Meter Asset Provider and National Mass Metering**

# Regulations (NERC – R – 113 – 2021) to close their respective

# metering gaps. As a safeguard for customers against exploitation

# due to the lack of meters, the Commission has continued to issue

# monthly energy caps for all feeders in each DisCo. This sets the

# maximum amount of energy that may be billed to an unmetered

**customer for the respective month based on gross energy received by the DisCo and the consumption by metered customers.**

**Customer number as at June 2024 Metered customers as at June 2024**

**2,500** **2,498** **Average Metering rate as at** **June 2024 45.43%** **)** **2,000**

**(thousand** **1,500** **1,370 1,396** **1,244 1,209** **1,179** **1,069** **1,000** **873** **926 878 882** **773 747 818** **675 635** **Number of Customers** **502** **500 438** **199 252 210 212** **129** **71** **0** **Aba Abuja Benin Eko Enugu Ibadan Ikeja Jos aduna ano Port Yola** **Harcourt** **Performance 36 % 70 % 49 % 57 % 45 % 43 % 77 % 34 % 24 % 24 % 43 % 16 %**

# Figure D: Status of Customer metering as of June 2024

**c. Customer Complaints: The number of complaints received at the NERC-CCU in 2024/Q2 was 4,469 and 1,000 complaints** **were resolved by DisCos (22.38% resolution rate). The number of complaints received across all DisCo-CCUs was 287,441** **which translates to a -1.35% decrease compared to the 291,380 received in 2024/Q1. Metering, billing, service**

# interruption and tariff band complaints were the prevalent issues of customer complaints during the quarter.

# In 2024/Q2, the Forum Offices d. Forum Offices: Pursuant to the provisions of its Customer

**resolved 54.90% of the active appeals in Protection Regulations 2023 (CPR 2023), the Commission set up**

**seventy-five (75) Forum Offices across the country to review unresolved disputes sittings. from the DisCos’ Complaint Handling Units (DisCos-CCU). The**

## xvi \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

total number of active appeals across the Forum Offices in
2024/Q2 was 2,625 made up of 1,720 new appeals in
2024/Q2 and 905 pending appeals from 2024/Q1. During the
period, the forum panels held seventy-five (75) sittings and
resolved 1,441 (54.90%) of the appeals filed at Forum Offices
nationwide; the resolution rate was 2.65pp lower than the
57.55% achieved in 2024/Q1.

Investigations have
been launched into
all reported
accidents in the
NESI.

The Commission continues to take measures that will ensure a
more efficient customer complaint resolution process starting
with improvements in the quality of complaint resolution at the
DisCo-CCU. To this end, the CPR 2023 contains updates to the
customer service standards expected from the DisCos in line with
international best practices.

e. Health & Safety: The total number of accidents in 2024/Q2
was sixty-three (63) which resulted in seventeen (17) injuries
and thirty-four (34) fatalities. The Commission has launched
investigations into all the accidents and will continue to work
with all sector stakeholders to improve the overall health and
safety of the NESI.

* * *

ey Facts on NESI Performance in Q2 of 2024

| 4,024.81MW | Average Available Generation Capacity;-224.29MW(-5.28%) decrease compared to 4,249.10MW in 2024/Q1 |
| --- | --- |
| 8,041.50GWh | Total Quarterly Generation;-846.43GWh(-9.52%) decrease compared to 8,887.93GWh in 2024/Q1 |
| 3,682.02MWh/h | Average Hourly Generation;-387.56MWh/h(-9.52%) decrease compared to 4,069.57MWh/h in 2024/Q1 |
| 91.48% | Load Factor;-4.29pp decrease compared to 95.77% in 2024/Q1 |
| 26.98% | Share of total quarterly generation from Hydropower Plants;+1.02pp increase compared to 25.95% in 2024/Q1 |
| 7.79% | Transmission Loss Factor;-0.69pp decrease compared to 8.48% in 2024/Q1 |
| 3,165.93MWh/h | Total energy received by the DisCos;-117.94MWh/h(-3.59%) decrease compared to 3,283.87MWh/h in 2024/Q1 |
| 5,693.11GWh | Energy billed to customers;-76.41GWh(-1.32%) decrease compared to 5,769.52GWh in 2024/Q1 |
| 431.16 billion | Total Revenue collected by the DisCos;¥139.54 billion(+47.85%) increase compared to ¥291.62 billion in 2024/Q1 |
| 82.34% | Cumulative billing efficiency across all DisCos;+1.89pp increase compared to 80.45% in 2024/Q1 |
| 79.31% | Cumulative collection efficiency across all DisCos;+0.20pp increase compared to 79.11% in 2024/Q1 |
| 34.70% | Aggregate Technical, Commercial and Collection Loss;-1.66 pp decrease compared to 36.36% in 2024/Q1 |
| 399.53 billion | Combined invoice from NBET(DRO-adjusted) and MO to DisCos;+¥285.41 billion(+250.10%) increase compared to ¥114.12 billion in 2024/Q1 |

* * *

| 318.65 billion | Total amount remitted by DisCos;+208.03 billion(+188.06%)increase compared to110.62 billion in2024/Q1 |
| --- | --- |
| 79.76% | DisCos' overall remittance performance;-17.47pp decreasecompared to96.93%in2024/Q1 |
| 49,188 | Number of new meters Installed;76,476 fewer installations(-60.86%)compared to the125,664 meters installed in2024/Q1 |
| 287,441 | Total complaints received at theDisCo-CCU;-1.35%decreasecompared to291,280complaints received in2024/Q1 |
| 54.90% | Forum Office complaint resolution rate;-2.65pp decreasecompared to57.55%in2024/Q1 |
| 34 | Number of fatalities;11more deathscompared to23in2024/Q1 |
| 17 | Number of injuries;14fewer injuriescompared to31in2024/Q1 |

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

#### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# 2.0 STATE OF THE INDUSTRY

### Pursuant to Section 34(1)(e) of the Electricity Act 2023 which states that "the

### Commission shall ensure the safety, security, reliability, and quality of service in the

**production and delivery of electricity to consumers”, the Nigerian Electricity Regulatory Commission (NERC) continues to monitor the technical, operational, and**

### commercial performance of the Nigerian Electricity Supply Industry (NESI).

**The Commission’s evaluation of the state of the NESI for 2024/Q2 covers the following key areas –**

- **Operational performance: a measure of how effectively available resources are utilised to generate electricity**
- **Grid performance: a measure of the technical performance of the national** **grid relative to the standards set out in the extant codes**
- **Commercial performance: a measure of the flow of funds from customers to upstream electricity industry players**

## 2.1 Operational Performance

### The operational performance of the NESI is a measure of how effectively available

### resources are utilised to generate electricity. Optimum operational performance is

### essential to ensure the generation, wheeling, and supply of adequate, affordable

### and safe electricity. In evaluating the operational performance of the NESI in

### 2024/Q2, the following Key Performance Indicators (KPIs) were considered:

- **Available generation**
- **Plant availability factor**
- **Total quarterly generation**
- **Generation load factor**
- **Generation mix**

### 2.1.1 Available Generation

### In 2024/Q2, the number of grid-connected plants increased by one (1) to twenty-

### eight (28) as a result of the operationalisation of the Zungeru hydropower plant,

### which began evacuating power to the grid on 29 April 2024. For this quarter, the

#### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

average available generation capacity of the grid-connected power plants was
4,395.77MW.

In comparison to 2024/Q1, the average available generation capacity of the grid-
4
connected power plants (excluding Zungeru ) decreased by -5.28% (-224.29MW)
from the 4,249.10MW recorded in 2024/Q1 to 4,024.81MW; this was driven by
the decrease in the available capacity of twenty (20) grid-connected power plants.

The average available generation capacity of selected power plants in 2024/Q2
relative to 2024/Q1 is presented in Figure 1. The most significant increases in
average available capacity were recorded in Egbin ST (Gas) (+52.92%), Rivers IPP
(+51.70%), Geregu NIPP (+49.23%), and Sapele ST (+30.47%) power plants.
Conversely, significant decreases in average available capacities during the period
were recorded in Sapele GT NIPP (-98.64%), Ihovbor NIPP (-97.64%), Olorunsogo
NIPP (-78.49%), Dadin owa (-74.86%), Afam IV – V (-56.30%) and Geregu (-
33.24%) power plants.

4
Zungeru has been excluded from the inter-quarterly comparison because it only became operational in
2024/Q2.

* * *

2.1.2 Plant Availability Factor

The availability factor of a plant is measured as a ratio of the maximum rated output
of the plant declared by the operator (available capacity) relative to the maximum
rated output specified by the manufacturer (installed capacity). The available
capacity of a plant may change from time to time due to several factors including i)
atmospheric conditions at the plant; ii) mechanical availability of the plant (planned
and unplanned outages); iii) feedstock availability, etc. The formula for the plant
availability factor (PAF) is represented by equation 1:

{\\mathsf{P l a n t\ a v a i i a b l i t i\\}c c a c r o r{{=}\\frac{{\\mathsf{a v e r a g e\ a v a i i a b b e c}a p a c i t y\ }a p c a c i(}\\mathsf{M W})}{{\\mathsf{i n s t a l l e d\ c a p o c i t y\ }(\\mathsf{M W})}}},\\times,100

(1)

The plant availability factor (PAF) is a critical parameter for evaluating the overall
health of the upstream segment of the NESI. In 2024/Q2, the average plant
availability factor for all grid-connected plants was 32.30% which shows that more
than 67% of the installed capacity in the NESI was unavailable.

Overall, only four (4) plants had availability factors above 50% with the Azura IPP
plant recording the highest availability factor - 98.05%. On the other end of the
spectrum, Omotosho NIPP, Ihovbor NIPP, Alaoji NIPP, and Sapele GT NIPP all
recorded 0% PAF in 2024/Q2.

This is the second consecutive quarter where all four (4) power plants; Alaoji NIPP,
Ihovbor NIPP, Omotosho NIPP, and Sapele GT NIPP have recorded <5% PAF due
to gas issues. As reported in the 2024/Q1 report (section 2.1.2), the management
of the Niger Delta Power Holding Company (NDPHC) is working with its gas
supplier and other relevant stakeholders to implement measures to resolve the issues
hindering gas supply to these power plants.

The PAF of all the grid-connected plants is contained in Table 1. The hydropower
plants; Dadin owa (-47.80pp), ainji (-17.34pp), Shiroro (-13.59pp), and Jebba
(-5.46pp) recorded decreases in PAF in 2024/Q2 compared to 2024/Q1. The
decrease in the PAF of the hydropower plants is consistent with the expected impact
of seasonality on river flows. The capacities of hydropower plants are constrained
by water availability from January to July every year.

* * *

Table 1: Plant Availability Factor (%) in 2024/Q1 vs. 2024/Q2

| Plant | Installed capacity(MW) | Average Available Capacity(MW) |  | Plant Availability Factor(%) |  |
| --- | --- | --- | --- | --- | --- |
|  |  | 2024/Q1 | 2024/Q2 | 2024/Q1 | 2024/Q2 |
| Azura IPP | 461 | 442.49 | 452.00 | 95.98 | 98.05 |
| Paras | 95 | 88.50 | 92.78 | 93.16 | 97.66 |
| Zungeru Hydro | 700 | 0.00 | 370.96 | NA | 52.99 |
| Jebba | 578 | 328.24 | 296.68 | 56.79 | 51.33 |
| Egbin ST(Gas) | 1,320 | 431.12 | 659.27 | 32.66 | 49.94 |
| Odukpani | 625 | 278.42 | 300.96 | 44.55 | 48.15 |
| Ibom | 190 | 113.50 | 91.67 | 59.74 | 48.25 |
| Okpai | 480 | 272.54 | 206.98 | 56.78 | 43.12 |
| Afam VI | 650 | 316.20 | 275.72 | 48.65 | 42.42 |
| Geregu NIPP | 435 | 122.80 | 183.26 | 28.23 | 42.13 |
| Kainji | 760 | 432.41 | 300.65 | 56.90 | 39.56 |
| Delta GS | 900 | 349.18 | 347.33 | 38.80 | 38.59 |
| Shiroro | 600 | 306.39 | 224.89 | 51.07 | 37.48 |
| Rivers IPP | 180 | 43.10 | 65.38 | 23.94 | 36.32 |
| Geregu | 435 | 225.30 | 150.42 | 51.79 | 34.58 |
| Taopex Energy | 45 | 9.53 | 18.78 | 21.18 | 41.73 |
| Omoku | 150 | 51.58 | 46.14 | 34.39 | 30.76 |
| Olorunsogo | 335 | 79.91 | 79.53 | 23.85 | 23.74 |
| Omotosho | 335 | 84.59 | 75.97 | 25.25 | 22.68 |
| Trans Amadi | 100 | 26.03 | 18.78 | 26.03 | 18.78 |
| Dadin Kowa Hydro | 40 | 25.54 | 6.42 | 63.85 | 16.05 |
| Sapele ST | 720 | 74.41 | 97.08 | 10.33 | 13.48 |
| Afam IV-V | 726 | 43.90 | 19.19 | 6.05 | 2.64 |
| Olorunsogo NIPP | 750 | 66.37 | 14.28 | 8.85 | 1.90 |
| Sapele GT NIPP | 500 | 17.41 | 0.24 | 3.48 | 0.05 |
| Alaoji NIPP | 500 | 0.00 | 0.18 | 0.00 | 0.04 |
| Ihovbor NIPP | 500 | 5.54 | 0.13 | 1.11 | 0.03 |
| Omotosho NIPP | 500 | 14.09 | 0.11 | 2.82 | 0.02 |
| Total | 13,610 | 4,249.09 | 4,395.78 | 31.22 | 32.30 |

\*Red PAF <50, Amber PAF 51≤80, Green PAF >80

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# 2.1.3 Total Quarterly Generation

**The hourly output produced by all the units in a power plant fluctuates based on grid**

# demand, mechanical operability of the unit(s), and the availability of feedstock.

**Plants are only dispatched when the load on the grid is sufficient to offtake the energy** **while operating within acceptable technical limits. The factors that determine the dispatch of a plant include:**

- **Plant availability (mechanical and feedstock)** • **Load offtake on the grid**
- **Financial competitiveness of the plant in the economic merit order dispatch**

# The average hourly generation on the grid in 2024/Q2 was 4,018.57MWh/h,

# which translates to a total generation of 8,776.55GWh (equation 2).

## Total generation Ave. hourly generation (MWh/h)×24hrs× number of days in the quarter (2)

# Both the hourly generation and total generation of the grid-connected power plants

**5** **(excluding Zungeru) decreased by -9.52% respectively in 2024/Q2 compared to generation in 2024/Q1; the hourly generation decreased from 4,069.57MWh/h**

**recorded in 2024/Q1 to 3,682.02MWh/h in 2024/Q2 (-387.56MWh/h) while the total generation decreased from 8,887.93GWh generated in 2024/Q1 to**

# 8,041.50GWh in 2024/Q2 (-846.43GWh). The significant decrease in generation

# is attributable to the decrease in the available capacity of many power plants during

# the quarter as explained in section 2.1.1.

# The most significant decreases in average hourly generation were recorded in

**Olorunsogo NIPP (-78.72%), Dadin owa Hydro (-75.12%), Afam IV-V (-61.12%), Geregu (-36.58%) and Shiroro (-36.34%) power plants. The average hourly**

# generation of ainji (-31.82%), Afam VI (-17.40%), Delta GS (-2.98%), and Azura

# IPP (-0.41%) power plants also decreased in 2024/Q2 compared to 2024/Q1

# (Figure 2). Conversely, the average hourly generation of Egbin ST (Gas)

**5** **The percentage change in total generation and average hourly generation is the same across Q 2/2024 vs** **Q1/2024 because the number of days in each of the quarters is the same (92 days). When there is a difference** **between the number of the days of the quarters being compared, the percentage in total generation will be** **different from the percentage change in average hourly generation. For ease of comparison with other sections** **of the report, the average hourly generation is used in the subsequent analyses.**

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

**(+48.64%), Geregu NIPP (+28.18%), Rivers IPP (+26.16%) and Paras (+16.55%) increased in 2024/Q2 compared to 2024/Q1.**

**Variance** **1,800** **2024/Q1 2024/Q2**

**) 1,600** **/h** **Mh 1,400** **(** **1,200** **1,000** **800** **600** **400** **Average Hourly Generation** **200** **0** **Egbin ST(Gas) Azura IPP Delta GS ainji Odukpani Afam VI Jebba Others** **Generation Companies**

**Figure 2: Average Hourly Generation (MWh/h) in 2024/Q1 vs. 2024/Q2**

# Cumulatively, the average hourly generation of the Jebba, Shiroro, and ainji

**hydropower plants reduced by -28.09% (741.28MWh/h in 2024/Q2 relative to 1,030.88MWh/h in 2024/Q1). This decrease is consistent with the expectations**

# associated with seasonal variation which occurs from January to July as explained in Section 2.1.2.

# The cumulative average hourly generation from thermal plants also decreased by -

# 2.62% (2,934.46MWh/h in 2024/Q2 relative to 3,013.56MWh/h in 2024/Q1)

**with sixteen (16) out of the twenty-three (23) thermal plants recording decreases in generation (Table 2).**

# Average hourly generation from the Olorunsogo NIPP, Afam IV – V, and Geregu

**power plants dropped to 14.54MWh/h, 16.91MWh/h, and 143.08MWh/h respectively in 2024/Q2, compared to 68.32MWh/h, 43.49MWh/h, and**

**225.59MWh/h generated in 2024/Q1 (-78.72%,-61.12%, and-36.58% respectively), driven by gas constraints and mechanical faults.**

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

Table 2: Average Hourly Generation (MWh/h) in 2024/Q1 vs. 2024/Q2

| Plant | Average Hourly Generation(MWh/h) |  | Change(MWh/h) | Change(%) |
| --- | --- | --- | --- | --- |
| 2024/Q1 | 2024/Q2 |  |  |  |
| Egbin ST(Gas) | 418.23 | 621.66 | 203.44 | 48.64 |
| Geregu NIPP | 122.47 | 156.98 | 34.51 | 28.18 |
| Rivers IPP | 43.27 | 54.59 | 11.32 | 26.16 |
| Paras | 74.28 | 86.57 | 12.29 | 16.55 |
| Sapele ST | 74.19 | 83.97 | 9.78 | 13.18 |
| Odukpani | 267.57 | 276.98 | 9.41 | 3.52 |
| Zungeru Hydro | 0.00 | 336.56 | 336.56 | 0.00 |
| Alaoji NIPP | 0.00 | 0.00 | 0.00 | 0.00 |
| Azura IPP | 400.31 | 398.65 | -1.66 | -0.41 |
| Taopex Energy | 10.79 | 10.56 | -0.23 | -2.13 |
| Delta GS | 345.85 | 335.55 | -10.30 | -2.98 |
| Ibom | 65.54 | 63.57 | -1.98 | -3.02 |
| Olorunsogo | 81.69 | 77.39 | -4.30 | -5.27 |
| Omotosho | 84.62 | 77.02 | -7.60 | -8.99 |
| Jebba | 302.77 | 258.93 | -43.84 | -14.48 |
| Omoku | 67.36 | 55.83 | -11.53 | -17.12 |
| Afam VI | 322.00 | 265.96 | -56.04 | -17.40 |
| Okpai | 237.28 | 172.97 | -64.31 | -27.10 |
| Kainji | 417.28 | 284.49 | -132.80 | -31.82 |
| Trans Amadi | 32.84 | 21.69 | -11.15 | -33.95 |
| Shiroro | 310.82 | 197.87 | -112.95 | -36.34 |
| Geregu | 225.59 | 143.08 | -82.51 | -36.58 |
| Afam IV - V | 43.49 | 16.91 | -26.58 | -61.12 |
| Dadin Kowa Hydro | 25.16 | 6.26 | -18.90 | -75.12 |
| Olorunsogo NIPP | 68.32 | 14.54 | -53.79 | -78.72 |
| Sapele GT NIPP | 11.05 | 0.00 | -11.05 | -100.00 |
| Omotosho NIPP | 11.91 | 0.00 | -11.91 | -100.00 |
| Ihovbor NIPP | 4.88 | 0.00 | -4.88 | -100.00 |
| Total | 4,069.57 | 4,018.57 | -51.00 | -1.25 |

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

2.1.4 Generation Load Factor the dispatch rate) reflects both the demand for energy and a plant’s ability to supply
it. The formula for load factor is represented by equation 3:

× 100 (3)

The overall load factor for all grid-connected power plants in 2024/Q2 was
91.42%; meaning that on average, 8.58% of available energy (MWh) was not
dispatched during the quarter. The load factor of grid-connected plants (excluding
Zungeru) was 91.48% which is a -4.29pp decrease compared to the 95.77% load
factor recorded in 2024/Q1. When combined with the reduction in the average
available capacity of these plants as indicated in section 2.1.1, this indicates a
decrease in the utilisation of available capacity and the total energy delivered to
the National Grid in 2024/Q2.

The load factors of the seven (7) power plants with the highest dispatch rates in
2024/Q2 are presented in Figure 3. Four (4) power plants (Omoku, Trans Amadi,
Olorunsogo NIPP, and Omotosho) recorded dispatch rates of 100% with ten (10)
other power plants recording dispatch rates above 90%. While ainji and Dadin
owa hydropower plants recorded dispatch rates >90%,
recorded dispatch rates of 87.98% and 87.28% respectively. This is inconsistent
with the Commission’s Order No: NERC/182/2019
being undertaken by the Commission to determine if sanctions should be issued
against relevant market participants.

The load factors of the seven (7) power plants with the highest dispatch rates in
2024/Q2 are presented in Figure 3. Four (4) power plants (Omoku, Trans Amadi,
Olorunsogo NIPP, and Omotosho) recorded dispatch rates of 100% with ten (10)
other power plants recording dispatch rates above 90%. While ainji and Dadin
owa hydropower plants recorded dispatch rates >90%, Shiroro and Jebba
recorded dispatch rates of 87.98% and 87.28% respectively. This is inconsistent
6
with the Commission’s Order No: NERC/182/2019 and further investigations are
being undertaken by the Commission to determine if sanctions should be issued
against relevant market participants.

6
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

* * *

Figure 3: Load Factor (%) in 2024/Q1 vs. 2024/Q2

2.1.5 Generation Mix

The electricity generation mix refers to the combination of fuels used to generate
electricity over a period. The composition of the generation mix varies across
countries and is influenced by factors such as natural resource availability,
government policies, environmental considerations, type of power plants, energy
demand, and seasonal fluctuations. An ideal energy mix must balance the three key
2 3
elements of the energy trilemma: i) Energy Security ; ii) Energy Sustainability ; and
4
iii) Energy Affordability/Equity . The formula for the share of electricity generated
by fuel source is given by equation 4:

\\mathsf{S h a r e\ o f\ t t u e!\ =\\frac}{mathsf{T o u l\ e l e c t i c y\ g e n e r o t e d\ f r o m\ t h e:\ M(u W)}}{\\mathsf{T o l l\ e l e r t i i y y\ g e n e r a t e d\ f r o m\ a l f\ l e e l\ s o u r c e s\ (M W h)}}\\times100\ \ (4

The share of electricity generated from different fuel sources in 2024/Q1 and
2024/Q2 are presented in Figure 4. The contribution from hydropower plants to
total generation (2,367.68GWh) increased by +2.66% (+61.29GWh) in 2024/Q2
compared to 2024/Q1 (2,306.39GWh). This translated to a +1.02pp increase in
the contribution of hydropower to the energy mix over the same period; 25.95%
(2,306.39GWh) in 2024/Q1 to 26.98% (2,367.68GWh) in 2024/Q2. The
increase in the contribution of hydropower plants to total generation during the
quarter, despite decreases in the plant availability factor of the existing hydropower plants reported in section 2.1.2, can be attributed to the Zungeru hydropower plant
which began evacuating power onto the grid on 29 April 2024.

Figure 4: Electricity Generated by Energy Sources in 2024/Q1 vs. 2024/Q2

The Transmission Company of Nigeria (TCN) which has the responsibility of
transporting energy from power plants to DisCos holds two licenses; Transmission
Service Provider (TSP) and System Operator (SO). The TSP owns and maintains the
transmission infrastructure while the SO is responsible for maintaining system
stability, load balance, load dispatch, and undertaking market operations
responsibilities. To assess the performance of the grid, the Commission focuses on
the following four (4) ey Performance Indicators ( PIs) that relate to power
transmission:

• Transmission loss factor

• Incidence of system collapse

• Voltage fluctuation
• Incidence of system collapse

* * *

2.2.1 Transmission Loss Factor

Transmission Loss Factor (TLF) refers to the proportion of the total energy sent out
by the power plants that was either lost in transmission or utilised in the transmission
station i.e., neither delivered to the DisCos nor exported to international customers.
There is an inverse relationship between the TLF and the efficiency of the transmission
system; i.e. a decline in the TLF indicates an improvement in transmission efficiency
over a given period. The formula for TLF is represented by equation 5:

\\mathsf{T}\\mathsf{L}\\mathsf{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\\pm E n e r g y\ E x x o r t e d}}{\\mathsf{E n e r g y\ S e n t\ o v l\ y y\ a l l\ G e n C o s}}\\right)\ \\times\\mathsf{l100}

×100 (5)

7
The average TLF in 2024/Q2 was 7.79% (Figure 5). A TLF of 7.79% indicates that
for every 100MWh of energy injected into the grid, 7.79MWh of energy is
undelivered to DisCos and international customers due to losses in the transmission
network or consumption at the transmission substations. The TLF recorded in
2024/Q2 represents a decrease (improvement) of -0.69pp relative to the 8.48%
recorded in 2024/Q1.

The 7.79% TLF recorded in 2024/Q2 represents an underperformance of 0.79pp
relative to the MYTO target for 2024 – 7.00%. The TLF target represents the
maximum efficient loss in transmission that is 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 the excess (inefficient) losses.

7
This represents the average TLF recorded in April and June only – May has been excluded because of the
extraordinarily low TLF recorded in the month as a result of the fact that energy injected into the grid by Zungeru
between 29 April to 15 May 2024 was not apportioned to DisCos and thus was used to net off transmission
losses on the grid during the period.

* * *

Figure 5: Actual Transmission Loss Factor (%) vs. MYTO TLF Target (%) Jan - June
2024

2.2.2 Grid Frequency

Frequency is a crucial power quality parameter that industrial customers are
particularly concerned about due to the sensitivity of their heavy-duty machinery. In
industrial production assembly lines, the machines are designed to operate only
within pre-set frequency 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 tolerance of
±2.5% i.e. system frequency may reach a lower bound stress limit of 48.75Hz and
an upper bound stress limit of 51.25Hz.

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# During 2024/Q2, the average upper daily system frequency was 50.64Hz, while

# the average lower daily system frequency was 49.13Hz, which translates to a range

# of 1.51Hz. Comparatively, in 2024/Q1, the average upper daily system frequency

# was 50.68Hz, while the average lower system frequency was 49.00Hz, with a

# range of 1.68Hz. The -10.12% (-0.17Hz) decrease in the average quarterly

**frequency range recorded in 2024/Q2 relative to 2024/Q1 indicates an improvement in the operational performance of the National Grid.**

**Figure 6: Monthly System Frequency from Jan-June 2024**

# It is noteworthy that in May, the average upper frequency (50.06Hz) was lower

**than the upper range allowed in the grid code – this is the first month in over seven**

# (7) years where the national grid has operated at an average upper frequency

# within 50.25Hz limit for steady-state operation. While the average lower frequency

# (49.23Hz) was outside of the steady state limit contained in the grid code

# (49.75Hz), it was the closest average to the target recorded in over five (5) years

# further verifying the improved performance of the grid in May 2024 (Figure 6).

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

The operation of the grid outside the normal frequency limits indicates an imbalance
in the supply and demand of electricity on the grid. This imbalance is primarily
caused by the lack of a Supervisory Control and Data Acquisition (SCADA) system.
The System Operator (SO) has invested in an IoT-based solution to improve realtime visibility into the operations of the Grid. However, the inability to remotely
operate the entire system as would be possible under the SCADA system continues
to pose challenges to the SO’s ability to operate the grid within the normal frequency
limits provided in the grid code.

2.2.3 Voltage Fluctuation

To guarantee the quality of electricity delivered to end users, the Grid Code specifies
a nominal system voltage of 330kV with a tolerance range of ±5% (313.50kV to
346.50kV in the lower and upper bounds respectively). Fluctuations in grid voltage,
including spikes, dips, flickers, and brownouts, can cause significant harm to
consumers and result in substantial commercial losses. Extreme cases of voltage
fluctuations, particularly at the distribution network level can cause severe damage
to industrial machines thereby compelling the industrial customers to seek alternative
sources of power outside of the National Grid.

The system voltage pattern from Jan - June 2024 is illustrated in Figure 7. The
average upper and lower operating voltage bounds for the transmission network in
2024/Q2 were 355.13kV and 304.36kV respectively; both values are outside the
respective allowable limits specified in the Grid Code.

By way of comparison, the range between the Grid’s average upper and lower
operating voltage for 2024/Q2 was 50.77kV which is lower than the 55.58kV
(average upper and lower voltages of 353.18kV and 297.60kV respectively) that
was recorded in 2024/Q1. This finding confirms the conclusion from section 2.2.2
that there was an improvement in the operational efficiency of the National Grid in
2024/Q2 relative to 2024/Q1.

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

**Figure 7: Monthly System Voltage (kV) from Jan-June 2024**

# 2.2.4 System Collapse

# The national power grid is a vast network of electrical transmission lines that link

# power stations to end-use customers across the nation and is designed to function

# within specific stability boundaries, including voltage (330kV ± 5.0%) and frequency

# (50Hz ± 0.5%). Any deviation from these stability ranges can result in decreased

# power quality and, in severe cases, cause widespread power outages ranging from

# a partial collapse of a section of the grid to a full system-wide blackout.

# While the SO is responsible for ensuring that all parameters are maintained within

# their respective tolerance thresholds, the primary parameter that the SO tracks to

# avoid system disturbances is frequency. When the electricity demand is higher than

# the supply, the grid frequency drops. Conversely, if supply surpasses demand, the

# frequency increases. In reaction to the grid operating at a frequency outside of the

# normal operation range (especially when the frequency is too low), safety settings

# on generation units can cause the units to shut down. This often exacerbates the

# frequency imbalance on the grid thereby leading even more generation units to shut

# down causing a full or partial system collapse.

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# One (1) incident of partial collapse on the national grid occurred in 2024/Q2. The

**incident happened on 15 April 2024. The details of the events leading to the incident are contained in Table 3.**

|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | Table 3: System Collapse in 2024/Q2 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
|  | SN | 1 |  |  |  |  |  | 15 2024 at 02:41hours |  |  | Date th |  | April |  |  |  |  |  |  |  |  |  | The cascading tripping of generating power load–generation imbalance frequency 50.01Hz which system collapse of Island |  |  |  | Immediate Cause |  |  |  | led | stations |  |  | to | units decline to | inducing |  | 8 | a | 48.75Hz | caused | at Partial |  | from |  | 12 | a |  |  | A Afam Station tripping of Afam VI and Afam III with a load loss of 305MW and 25MW respectively triggering the split of the operations |  |  |  | fire | Remote Cause |  |  |  | incident |  | caused |  | Transmission of | while |  |  | the |  | at |  | also grid | the the |  |  |  |  | The cause(s) of the fire incident Transmission should be investigated to avert future occurrences. The cascaded units on Island 2 should be |
|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 2 . |  | 9 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | into two (2) islands – island 1 (Ibom power) and Island 2. |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | rectified future occurrences. |

## Inference

## at Afam Station

## cause(s) of the tripping of

## investigated and to forestall

8 **The power plants are Delta, Odukpani G.S, Okpai, Olorunsogo Gas, Jebba G.S, Kainji G.S, Geregu gas** **and NIPP, Sapele steam, Shiroro G.S, Azura, and Paras Energy** **9** **Island 2 consist of Kainji, Jebba, Shiroro, Dadin Kowa, Egbin, Delta, Sapele Steam, Geregu 1, Geregu** **Nipp, Omotosho 1, Olorunsogo Gas & Nipp, Azura-Edo, Paras Energy, Okpai, Afam Vi, Rivers Ipp,** **Odukpani, Taopex, Mepp, and Omoku power plants**

### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

2.3 Commercial Performance

The commercial performance of the NESI is a measure of the flow of funds from
customers to upstream electricity industry players. The financial performance is
critical because funds are required to keep all the players along the value chain
operational. In evaluating the commercial performance of the NESI for 2024/Q2,
the following parameters were considered:

• Energy offtake performance

• Energy billed and billing efficiency

• Revenue and collection efficiency

• Aggregate Technical, Commercial and Collection (ATC&C) loss

• Remittances to the Market Operator (MO) and the Nigerian Bulk Electricity
Trading Company (NBET).

2.3.1 Energy offtake performance

The Partial Activation of Contract (PAC) regime, which took effect in July 2022,
defines the target volume of energy to be off-taken by DisCos at any time as their
Partially Contracted Capacity (PCC). As explained in prior reports, under the PAC
regime, DisCos have take-or-pay obligations on their PCC which means that they
must pay for available capacity irrespective of their offtake. This structure is
consistent with international best practices for long-term contract-based power
procurement and ensures that GenCos earn capacity payments to compensate them
for availability.

The PAC regime also mandates GenCos or TCN to compensate DisCos through
Liquidated Damages (LDs) in the event of capacity shortfalls. Under the single-buyer
model being operated in the NESI, when there is a shortfall in generation, LDs from
GenCos are treated as net-offs in the invoices issued to NBET thereby reducing the
net payables due from DisCos.

10
Commencing 2023/Q3, the Commission developed a mechanism whereby Abuja, Eko and Ikeja DisCos get
their full allocation provided that generation is above 4,100MW which is the minimum grid stability requirement;
the rest of the capacity is pro-rated based on PCC for the remaining DisCos. When available generation is below
4,100MW, generation allocation to all the DisCos is pro-rated based on PCC.

* * *

– “Available PCC”. The ratio between a DisCo’s energy offtake and the available
PCC is known as the “energy offtake performance”. The formula for determining a
DisCo’s energy offtake performance is represented by equation 6 :

\\mathsf{E n e r g y\ O H f i b e\ p e r f o r m a n c e%r00}\\quad=\\quad\\left(\\begin{matrix}{\\mathsf{E n e r g y\ O O f h a k e}}\ {\\mathsf{A v a l i a b l e\ P C C}}\\end{}\\right)\ \\times100

×100 (6)

Considering the large disparity between energy on the national grid and customer
demand, it is expected that DisCos will offtake 100% of their available PCC at all
times. However, the Commission continues to observe with concern that many DisCos
do not take their full PCC due to a combination of technical limitations as well as
load rejection by the DisCos largely due to commercial reasons i.e., high commercial
and collection losses in certain areas.

It is noteworthy that when DisCos have offtake ratios below 100%, this means that
they incur increased wholesale energy costs as they still have to pay NBET/GenCos
for unused capacity. The tariff methodology utilised by the Commission does not
allow DisCos to recover the resultant additional wholesale energy costs (relative to
the volume of energy offtaken) from customers.

In 2024/Q2, the average energy offtake by DisCos at their trading points was
3,165.93MWh/h, which represents a decrease of -3.59% (-117.94MWh/h) when
compared to 3,283.87MWh/h off-take in 2024/Q1. The reduction in the average
energy offtake at trading points was because of the reduction in energy available
for offtake (PCC) driven by the reduced generation explained in section 2.1.3.

The cumulative energy offtake performance of DisCos during the quarter was
99.29% which is +6.94pp greater than the 92.35% achieved in 2024/Q1.
Disaggregated DisCo performance shows that all the DisCos except Jos DisCo took
more than 90% of its PCC during the quarter. Nine (9) DisCos recorded increases
in their offtake performances between 2024/Q1 and 2024/Q2 with Port Harcourt,
Benin and Eko DisCos recording the most significant improvements of +12.21pp,
+9.31pp and +9.00pp respectively. Conversely, Jos and Yola DisCos recorded
decreases of –2.57pp and -0.38pp respectively, in their energy offtake performance
between 2024/Q1 and 2024/Q2 (Table 4).

* * *

Table 4: DisCo energy offtake performance in 2024/Q1 vs. 2024/Q2

| DisCos | 2024/Q1 |  |  | 2024/Q2 |  |  |
| --- | --- | --- | --- | --- | --- | --- |
| Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance% | Energy Offtake(MWh/h) | Available PCC(MWh/h) | Offtake Performance% |  |
| Abuja | 512.36 | 555.63 | 92.21 | 498.63 | 509.26 | 97.91 |
| Benin | 263.71 | 287.03 | 91.88 | 257.81 | 254.79 | 101.19 |
| Eko | 433.15 | 485.76 | 89.17 | 431.32 | 439.35 | 98.17 |
| Enugu | 252.54 | 270.77 | 93.27 | 225.27 | 235.48 | 95.66 |
| Ibadan | 383.51 | 398.90 | 96.14 | 373.68 | 364.16 | 102.61 |
| Ikeja | 511.83 | 555.53 | 92.13 | 520.53 | 516.06 | 100.87 |
| Jos | 181.15 | 199.79 | 90.67 | 152.33 | 172.91 | 88.10 |
| Kaduna | 203.25 | 216.09 | 94.06 | 202.69 | 201.31 | 100.69 |
| Kano | 201.61 | 218.00 | 92.48 | 203.45 | 202.48 | 100.48 |
| PH | 243.14 | 260.52 | 93.33 | 243.24 | 230.48 | 105.54 |
| Yola | 97.61 | 106.03 | 92.06 | 56.99 | 62.16 | 91.68 |
| All DisCos | 3,283.87 | 3,556.05 | 92.35 | 3,165.93 | 3,188.59 | 99.29 |

The Commission will continue to undertake regulatory activities that will compel
DisCos to improve their operational capacities to facilitate the maximum utilisation
of energy that is made available by the GenCos.

2.3.2 Energy billed and billing efficiency

Billing efficiency measures the proportion of energy billed to customers (including
metered and unmetered customers) relative to the total energy supplied to a given
area over a period. The key drivers of billing losses are i) technical - energy loss in
distribution lines; ii) commercial - DisCo's inability to account for 100% of the energy
supplied. Commercial losses could either be a result of theft on the part of the
customer i.e. a meter bypass, or other factors under the DisCo’s control such as poor
customer enumeration, and the proliferation of inaccurate meters. A billing efficiency
of 70% means that only ₦70.00 worth of electricity is billed out of ₦100.00 worth
of electricity distributed by DisCos. The formula for billing efficiency is represented
by equation 7:

\\mathtt{S i l l i n g\ E E f f c i e n c y y\ }Bigl\\\ (\ \\frac{\\mathtt{T o t a l\ e n e r g y\ b i l l e d\ t o\ c u s t o m e r s\ (G W h)}}{\\mathtt{T o t a l\ e n e r g y\ r e c e i v e d\ b y\ t h e\ N e e t w o r k\ (G W h)}}\\Bigr)\ \\times100

×100 (7)

The total energy offtake by all DisCos in 2024/Q2 was 6,914.39GWh and the total
energy billed was 5,693.11GWh, which translates to a billing efficiency of 82.34%.

* * *

A billing efficiency of 82.34% implies that for every ₦100 worth of energy received
by DisCos in 2024/Q2, ₦17.66 was not billed to end users. Comparatively, the
total energy received and billed in 2024/Q1 were 7,171.93GWh and
5,769.52GWh respectively, which translated to a billing efficiency of 80.45%. This
means that at the aggregated level, the NESI recorded a +1.89pp increase in billing
efficiency between 2024/Q1 and 2024/Q2.

Disaggregated performance of the DisCos shows that Enugu recorded the highest
billing efficiency of 95.33%, while aduna recorded the lowest billing efficiency of
63.07%. A quarter-on-quarter comparison of billing efficiency showed that six (6)
DisCos recorded improvements in their billing efficiencies in 2024/Q2 relative to
2024/Q1 with Enugu, Yola and aduna recording the most significant increases of
+14.87pp, +7.31pp and +6.41pp respectively. Conversely, five (5) DisCos
recorded decreases in billing efficiency with Jos (-3.28pp) DisCo recording the most
significant decrease (Table 5).

Table 5: Energy received and billing efficiency by DisCos in 2024/Q1 vs.
2024/Q2

| DisCos | 2024/Q1 |  |  | 2024/Q2 |  |  |
| --- | --- | --- | --- | --- | --- | --- |
| Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) | Energy Offtake(GWh) | Energy Billed(GWh) | Billing Efficiency(%) |  |
| Abuja | 1,119.00 | 846.00 | 75.60 | 1,089.00 | 835.00 | 76.68 |
| Benin | 575.95 | 488.82 | 84.87 | 563.05 | 469.29 | 83.35 |
| Eko | 964.00 | 849.00 | 89.75 | 942.00 | 845.00 | 89.70 |
| Enugu | 551.55 | 443.77 | 80.46 | 492.00 | 469.00 | 95.33 |
| Ibadan | 837.59 | 716.51 | 85.54 | 816.11 | 724.29 | 88.75 |
| Ikeja | 1,117.83 | 908.33 | 81.26 | 1,136.83 | 937.49 | 82.47 |
| Jos | 395.62 | 300.84 | 76.04 | 332.68 | 242.05 | 72.76 |
| Kaduna | 443.90 | 251.51 | 56.66 | 442.67 | 279.20 | 63.07 |
| Kano | 440.32 | 329.93 | 74.93 | 444.34 | 331.59 | 74.63 |
| Port Harcourt | 531.01 | 451.40 | 85.01 | 531.25 | 444.02 | 83.58 |
| Yola | 213.19 | 183.40 | 86.03 | 124.46 | 116.17 | 93.34 |
| All DisCos | 7,171.93 | 5,769.52 | 80.45 | 6,914.39 | 5,693.11 | 82.34 |

DisCos have the responsibility of developing strategies to improve their billing
efficiencies. These can include reinforcing DisCos’ infrastructure to reduce technical
losses, improving consumer enumeration and customer service, improving the
metering rate and rolling out initiatives to curb energy theft.

* * *

2.3.3 Revenue and collection efficiency

Collection efficiency is the ratio of the amount that has been collected from customers
relative to the amount billed to them by the DisCos. The significant under-recovery
of the invoices issued to customers by DisCos is driven by a lack of willingness of
customers to pay bills when due, unsatisfactory DisCos’ services and inadequate
customer metering among other challenges. A collection efficiency of 70% for
instance implies that for every ₦100.00 worth of energy billed to customers by
DisCos, approximately ₦30.00 remained unrecovered from the billed customers.
The formula for collection efficiency is represented by equation 8:

{\\sf C o l l e c t i o n\ E f f h c i e n c y=}\ \ \\left(({{\\frac{\\sf o r t l l\ R e v e n v e\ C o l l e c t e d\ (H)}{\\sf T o l a l\ B i l l e d\ A m o u u r t\ (H)}}}\\right)\ \\times100

×100 (8)

The total revenue collected by all DisCos in 2024/Q2 was ₦431.16 billion out of
the ₦543.64 billion that was billed to customers. This translates to a collection
efficiency of 79.31%. In comparison, the total revenue collected by all DisCos in
2024/Q1 was ₦291.62 billion out of the ₦368.65 billion billed to customers which
translated to a 79.11% collection efficiency. The 79.31% collection efficiency
recorded in 2024/Q2 is +0.20pp higher than the collection efficiency recorded in
2024/Q1 (79.11%).

The total revenue collected by all DisCos in 2024/Q2 was ₦431.16 billion out of
the ₦543.64 billion that was billed to customers. This translates to a collection
efficiency of 79.31%. In comparison, the total revenue collected by all DisCos in
2024/Q1 was ₦291.62 billion out of the ₦368.65 billion billed to customers which
translated to a 79.11% collection efficiency. The 79.31% collection efficiency
recorded in 2024/Q2 is +0.20pp higher than the collection efficiency recorded in

2024/Q1 (79.11%).

The summary of the revenue collection performance of all DisCos is contained in
Table 6. Ikeja and Eko DisCos recorded the highest collection efficiencies of 94.67%
and 88.03% respectively, conversely, Yola DisCo recorded the lowest collection
efficiency of 55.67%. A comparison of DisCos performance in 2024/Q1 and
2024/Q2 showed that six (6) DisCos recorded improvements in collection efficiency
in 2024/Q2 when compared to 2024/Q1 with Yola DisCo recording the highest
increase of +12.64pp. Conversely, five (5) DisCos recorded declines in collection
efficiency with aduna having the most significant decrease (-10.04pp) during the
period.

* * *

Table 6: Revenue Collection Performance (%) of DisCos in 2024/Q1 vs. 2024/Q2

| DisCos | 2024/Q1 |  |  | 2024/Q2 |  |  |
| --- | --- | --- | --- | --- | --- | --- |
| Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) | Total Billings(N' Billion) | Revenue Collected(N' Billion) | Collection Efficiency(%) |  |
| Abuja | 58.30 | 48.60 | 83.36 | 84.49 | 70.19 | 83.07 |
| Benin | 29.40 | 22.46 | 76.39 | 41.24 | 33.96 | 82.35 |
| Eko | 56.52 | 48.74 | 86.24 | 85.46 | 75.23 | 88.03 |
| Enugu | 26.40 | 21.24 | 80.45 | 40.88 | 30.39 | 74.35 |
| Ibadan | 44.79 | 30.35 | 67.78 | 63.01 | 44.27 | 70.25 |
| Ikeja | 55.86 | 57.88 | 103.61 | 92.28 | 87.36 | 94.67 |
| Jos | 21.85 | 13.29 | 60.81 | 24.07 | 15.74 | 65.37 |
| Kaduna | 13.59 | 9.60 | 70.66 | 24.25 | 14.71 | 60.62 |
| Kano | 21.58 | 13.62 | 63.09 | 37.33 | 21.92 | 58.71 |
| Port Harcourt | 27.69 | 20.39 | 73.66 | 42.02 | 32.61 | 77.59 |
| Yola | 12.68 | 5.46 | 43.03 | 8.63 | 4.78 | 55.67 |
| All DisCos | 368.65 | 291.62 | 79.11 | 543.64 | 431.16 | 79.31 |

The increase in billing efficiency (+1.89pp) and collection efficiency (+0.20pp)
recorded in 2024/Q2 compared to 2024/Q1 despite a significant reduction in the
energy offtake (-3.59%) continues a trend that has been observed previously. There
is an inverse relationship between energy offtake and billing/collection efficiencies
whereby a decrease in energy offtake would result in an increase in
billing/collection efficiency. One driving factor behind this trend is that when there
is lower energy offtake, DisCos often allocate the energy to areas where they record
reduced billing and collection inefficiencies.

The most proven method to improve energy accountability and revenue recovery is
accurate customer enumeration and the installation of end-use customer meters. The
Commission issued the Order on the Operationalisation of Tranche A of the Meter
Acquisition Fund (MAF) during the quarter. The Order which became effective on
th
24 June 2024 directed DisCos to utilise the first tranche of disbursement from the
MAF scheme to procure and install meters for unmetered Band A customers within
their franchise areas. DisCos are also still expected to continue to utilise one or more
metering frameworks provided for in the NERC MAP and NMMP metering
regulation (2021) to improve end-use customer metering in their franchise area. This

2d^{t+h} will reduce commercial and collection losses thereby improving the flow of funds to
upstream market participants in the NESI.

Furthermore, DisCos must continue to evaluate options for improving the
optimisation of their energy delivery in line with the Service Based Tariff (SBT) regime
to ensure that sufficient energy is supplied to customer groups/clusters with the
highest collection efficiencies.

2.3.4 Aggregate Technical, Commercial and Collection (ATC&C) Loss

The Aggregate Technical, Commercial and Collection (ATC&C) loss is a summation
of billing losses incurred by a DisCo due to its inability to bill 100% of energy
delivered to customers (technical and commercial losses) and the collection losses
arising from the DisCo’s inability to collect 100% of the bills issued to customers. The
ATC&C loss is a critical performance-setting parameter for tariff computation as the
MYTO makes allowance for target ATC&C loss levels for each DisCo.

The target ATC&C reflects the efficient operational losses which the DisCo is
expected to incur in its operations and this is recoverable from the allowed tariffs.
The target ATC&C usually reduces over time as DisCos make investments that are
geared towards improving operational efficiency. ATC&C loss is made up of the
following components:

a. Technical Loss: heat loss due to load flow in electrical lines and transformation
loss in transformers.

b. Commercial Loss: due to discrepancy in meter reading, erroneous billing,
unmetered consumption, or energy theft;

c. Collection Loss: unpaid bills.

The formula for ATC&C loss is represented by equation 9 :

Any DisCo that can outperform its allowed ATC&C (i.e., has a lower actual ATC&C
than the target used to compute its cost-reflective tariff) will earn more returns on its
set tariffs. Conversely, any DisCo that fails to meet its allowed ATC&C (i.e., has a
higher actual ATC&C than the target), will be unable to earn the expected returns
on its set tariffs and could risk long-term financial challenges.

ATC&C Loss \[1-(billing efficiency × collection efficiency)\] ×100 (9)

ATC&C Loss \[1-(billing efficiency × collection efficiency)\] ×100 (9)

* * *

The aggregate ATC&C loss recorded across all 11 DisCos in 2024/Q2 was
34.70%, which comprised 17.66% in technical and commercial losses, and 20.69%
in collection loss (Table 7). The aggregate ATC&C loss of 34.70% recorded in
2024/Q2 is 9.97pp higher than the allowed aggregate efficient loss target
(24.73%) applied in the computation of the tariffs in the MYTO. This means that
cumulatively, DisCos recorded losses that are 9.97pp higher than what was allowed
to be recovered from the customers – these inefficient losses that are not recoverable
from customers will adversely affect DisCos' profitability.

The ATC&C loss for 2024/Q2 (34.70%) reduced by -1.66pp compared to 36.36%
recorded in 2024/Q1. Eight (8) DisCos recorded improvements in ATC&C loss
performance in 2024/Q2 compared to 2024/Q1 with the highest improvements
recorded by Yola (-14.32pp) and Enugu (-6.49pp). Conversely, Ikeja (+6.12pp),
ano (+3.46pp) and aduna (+1.80pp) DisCos recorded worse ATC&C loss
performances in 2024/Q2 compared to 2024/Q1 (Table 7).

Yola DisCo outperformed its allowed ATC&C in 2024/Q2 by achieving an actual
ATC&C of 48.04% which is lower than the set target of 56.00%. This means that
during the quarter, Yola DisCo was able to earn 100% of its revenue requirement
for the period which should allow it to cover all market obligations as well as
operational costs. The other DisCos did not achieve their target ATC&C in 2024/Q2
with the widest variance (target – actual) being recorded by aduna (-36.76pp)
and ano (-31.19pp). The failure of the DisCos to meet their allowed loss targets
means they are unable to meet revenue requirements, thereby compromising their
long-term financial position. The Commission is working with all the DisCos to take
remedial actions through customer enumeration and increased revenue assurance
to improve their ATC&C loss.

| DisCo | MYTO Target(%) | ATC&C(%) |  | Variance(pp) |  |
| --- | --- | --- | --- | --- | --- |
| 2024 | 2024/Q1 | 2024/Q2 | 2024/Q1 | 2024/Q2 |  |
| Abuja | 25.00 | 36.98 | 36.30 | -11.98 | -11.30 |
| Benin | 25.00 | 35.17 | 31.36 | -10.17 | -6.36 |
| Eko | 20.07 | 22.61 | 21.03 | -2.52 | -0.96 |
| Enugu | 25.00 | 35.61 | 29.12 | -10.61 | -4.12 |
| Ibadan | 25.00 | 42.02 | 37.66 | -17.02 | -12.66 |
| Ikeja | 18.73 | 15.81 | 21.93 | 2.92 | -3.20 |
| 2024 | 2024/Q1 | 2024/Q2 | 2024/Q1 | 2024/Q2 |  |
| Jos | 32.72 | 53.76 | 52.44 | -21.04 | -19.72 |
| Kaduna | 25.00 | 59.96 | 61.76 | -34.96 | -36.76 |
| Kano | 25.00 | 52.73 | 56.19 | -27.73 | -31.19 |
| Port Harcourt | 25.00 | 37.39 | 35.15 | -12.39 | -10.15 |
| Yola | 56.00 | 62.36 | 48.04 | -6.98 | 7.96 |
| All DisCos |  |  |  |  |  |
| MYTO Level | 24.73 |  |  |  |  |
| Total Technical, Commercial&Collection losses | - | 36.36 | 34.70 |  |  |
| Technical&Commerciallosses | - | 19.55 | 17.66 |  |  |
| Collection losses | - | 20.83 | 20.69 |  |  |

2.3.5 Market Remittance

Under the account administration mechanism set up by the CBN in 2013 as part of
the Nigerian Electricity Market Stabilisation Facility (NEMSF) intervention, all the
collections of the DisCos are escrowed. The DisCos only have access to their
revenues after relevant deductions towards their loan obligations have been made.
This escrow mechanism also provides visibility into the financial performance of the
DisCos with respect to collections.

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.

2.3.5.1 Market Remittance to NBET

Prompt payment of upstream invoices is critical for securing the availability of
generation and transmission capacities. The waterfall regime pushes DisCos to boost
their collections because most of their allowed revenues rank below the payment of
market obligations in the waterfall.

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# cost payable by DisCos to NBET at source in the form of a DisCo’s Remittance

# Obligation (DRO). The DRO represents the total GenCo invoice that is billed to the

# DisCos by NBET based on what the allowed DisCo tariffs can cover.

# As explained in the 2024/Q1 report, the DRO regime replaced the Minimum

**12**

# Remittance Obligation (MRO) framework in January 2024 and DisCos are

# expected to pay 100% of their DROs. The transition to the DRO regime was

# necessitated by the risk of unpaid tariff subsidy debts encumbering the balance

# sheets of the DisCos thereby preventing them from raising finance to undertake

# critical investments. Furthermore, DisCos are expected to remit 100% of the invoices

# received from the MO for transmission and administrative service costs.

# The total NBET invoices and final obligation for each DisCo (based on DRO) during

**2024/Q2 are summarised in Table 8. It is important to note that due to the absence**

# of cost-reflective tariffs across all DisCos, the Government incurred a subsidy

# obligation of ₦380.06 billion (52.51% of total NBET invoice) in 2024/Q2 (average

# of ₦126.69 billion per month). Between 2024/Q1 and 2024/Q2, the subsidy

# obligation of the government reduced by - ₦253.24 billion, from ₦633.30 billion

# (90.57% of total GenCo invoice) to ₦380.06 billion (52.51% of total GenCo

# invoice). The significant decrease in the subsidy obligation of the FGN is a result of

# the policy directive of the Government to implement reviews of tariffs charged to

**Band A customers while the tariffs for Band B-E customers remain frozen at the rates payable since December 2022.**

# In 2024/Q2, the DRO-adjusted invoice from NBET to the DisCos was ₦343.76

**13**

# billion while the total remittance made was ₦271.87 billion, which translates to a

# 79.09%% remittance performance. Comparatively, in 2024/Q1, the DRO-adjusted

# invoice from NBET to DisCos was ₦65.96 billion and the total remittance was

# ₦65.52 billion, which translated to a 99.33% remittance performance. This means

# that the remittance performance of DisCos to NBET decreased by –20.24pp in

**11** **The outstanding portion of GenCo invoice not covered by allowed tariffs and thus not billed to the DisCos is** **to be covered by the FGN in the form of tariff subsidies.** **12** **For the MRO framework, DisCos are invoiced 100% of energy cost but only expected to pay MRO share of** **the invoice. The outstanding balance is only cleared from the DisCo’s record when the FGN subsidy is paid to** **NBET** **13** **Total NBET invoice for 2024/Q2 without adjustment for DRO (total bill issued by GenCos) is ₦723.82** **billion**

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

2024/Q2 compared to 2024/Q1; largely attributable to the +₦277.80 billion
(+421.16%) increase in the cumulative DisCo obligation between the quarters.

Table 8: Total NBET Invoice and Final Obligation (DRO) of DisCos for 2024/Q2

| DisCos | Total NBET Invoice (N' billion) | Final Obligation(N' billion) |
| --- | --- | --- |
| Abuja | 114.05 | 57.71 |
| Benin | 58.43 | 27.48 |
| Eko | 98.57 | 54.31 |
| Enugu | 54.85 | 24.18 |
| Ibadan | 84.01 | 38.76 |
| Ikeja | 117.39 | 65.06 |
| Jos | 36.74 | 11.88 |
| Kaduna | 46.18 | 19.24 |
| Kano | 46.22 | 20.30 |
| Port Harcourt | 53.52 | 23.73 |
| Yola | 13.86 | 0.88 |
| All DisCos | 723.82 | 343.76 |

Disaggregated remittance performance of the DisCos to NBET in 2024/Q2 showed
that only Yola DisCo recorded a remittance performance ≥100%, conversely,
aduna and Jos DisCos recorded the lowest remittance performances of 29.28%
and 66.03% respectively (Figure 8). A quarter-on-quarter analysis showed that ten
(10) DisCos recorded declines in remittance performance to NBET in 2024/Q2
compared to 2024/Q1. Only Yola (+10.33pp) recorded an improvement in their
remittance performance to NBET.

As indicated above, the reduction in the remittance performance (-20.24pp) of
DisCos to NBET during the quarter (2024/Q2) is directly attributable to the fact that
the DisCos share of the GenCo invoice increased from 9.43% in 2024/Q1 to
47.49% in 2024/Q2.

* * *

### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

**NBET Invoice NBET Remittance**

**)** **Billion** **(₦**

**Remittances**

**88 97**

**0\. 0.** **Abuja Benin Eko Enugu Ibadan Ikeja Jos aduna ano P/Harcourt Yola** **Performance 83% 80% 99% 79% 76% 79% 66% 29% 70% 81% 111%**

**Figure 8: DisCos Remittance Performances to NBET in 2024/Q2**

# 2.4.5.2 Market Remittance to MO

## The Market Operator issues invoices to DisCos for energy transmission and

## administrative services. In 2024/Q2, DisCos made a total remittance of ₦46.78

## billion against the cumulative invoice of ₦55.77 billion issued by the MO. This

## payment translates to 83.88% remittance performance and is a -9.76pp decrease

## when compared to 93.64% remittance performance recorded in 2024/Q1 where

## DisCos remitted ₦45.09 billion out of ₦48.16 billion invoice issued by the MO.

### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

Figure 9: DisCos Remittance Performances to MO in 2024/Q2

Disaggregated remittance performance of the DisCos to MO showed that Yola and
14
Eko DisCos recorded the highest remittance performances of 149.99% and
95.92% respectively while aduna had the lowest remittance performance of
15
21.84% (Figure 9). Between 2024/Q1 and 2024/Q2, only Yola (+103.60pp)
and Eko DisCos (+0.32pp) recorded improvements in their remittance performances
to MO. The remaining nine (9) DisCos recorded declines in MO remittance
performance with Jos (-32.77pp), aduna (-25.70pp), and ano (-22.40pp)
recording the most significant reductions.

2.4.5.3 Market Remittance to NBET and MO

The cumulative DisCos’ remittance to NBET and MO in 2024/Q2 is presented in
Table 9.

14
Remittances above 100% are due to payment of outstanding invoices from previous quarters
15
In May 2024, Yola made payment against all outstanding MO invoices from Jan – May 2024

* * *

Table 9: DisCos Remittance Performances to NBET and MO in 2024/Q2

| DisCos | DRO Adjusted Invoice(NE' Billion) |  |  | Actual Remittance(NE' Billion) |  |  | RemittancePerformance(%) |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| NBET | MO | NBET+MO | NBET | MO | NBET+MO | 2024/Q1 | 2024/Q2 |  |
| Abuja | 57.71 | 9.15 | 66.86 | 47.98 | 8.51 | 56.49 | 99.35 | 84.49 |
| Benin | 27.48 | 4.52 | 32.01 | 21.93 | 3.87 | 25.80 | 96.65 | 80.61 |
| Eko | 54.53 | 6.92 | 61.45 | 53.86 | 6.64 | 60.50 | 98.55 | 98.45 |
| Enugu | 24.18 | 4.18 | 28.36 | 19.04 | 3.51 | 22.55 | 98.06 | 79.51 |
| Ibadan | 38.76 | 6.49 | 45.25 | 29.50 | 5.58 | 35.08 | 100.37 | 77.52 |
| Ikeja | 65.06 | 9.14 | 74.20 | 51.70 | 8.10 | 59.80 | 102.27 | 80.59 |
| Jos | 11.88 | 3.17 | 15.04 | 7.84 | 1.99 | 9.83 | 97.50 | 65.34 |
| Kaduna | 19.24 | 3.61 | 22.85 | 5.61 | 0.79 | 6.40 | 49.54 | 28.01 |
| Kano | 20.30 | 3.49 | 23.79 | 14.20 | 2.51 | 16.71 | 96.52 | 70.24 |
| P/Harcourt | 23.73 | 4.06 | 27.79 | 19.24 | 3.72 | 22.96 | 97.72 | 82.63 |
| Yola | 0.88 | 1.04 | 1.93 | 0.97 | 1.57 | 2.54 | 54.78 | 131.89 |
| All DisCos | 343.76 | 55.77 | 399.53 | 271.87 | 46.78 | 318.65 | 96.93 | 79.76 |

2.4.5.4 Market Remittance by Other Customers

The remittances made by bilateral customers (domestic and international) and
special customers for invoices issued in 2024/Q2 by the MO are detailed in Table
10\. The four (4) international bilateral customers being supplied by GenCos in the
NESI made a payment of $9.81 million against the cumulative invoice of $15.60
million issued by the MO for services rendered in 2024/Q2, translating to a
remittance performance of 62.88% (Table 10). The domestic bilateral customers
made a payment of ₦1,295.90 million against the cumulative invoice of ₦1,991.30
million issued to them by the MO for services rendered in 2024/Q2 translating to
65.07% remittance performance (Table 10).

It is however noteworthy that some bilateral customers (both domestic and
international customers) made payments during 2024/Q2 for outstanding MO
invoices from previous quarters. Cumulatively, the international bilateral customers
paid a total of $16.65 million; Transcorp-SBEE and Mainstream-NIGELEC have
made payments towards all outstanding invoices from previous quarters. Similarly,
the MO received ₦1,309.97 million from the domestic bilateral customers towards
outstanding invoices from previous quarters; Mainstream Energy Solutions has made
payment towards all outstanding invoices from previous quarters. The details of
these payments are contained in Appendix VII.

* * *

The special customer (Ajaokuta Steel Co. Ltd and the host community) did not make
any payment towards the ₦1.39 billion (NBET) and ₦0.11 billion (MO) invoices
received in 2024/Q2. This continues a longstanding trend of non-payment by this
customer and the Commission has communicated the need for intervention on this
issue to the relevant FGN authorities. A continuation of the non-payment could
trigger total disconnection from the grid.

Table 10: Invoices and Remittances of Other Customers in 2024/Q2

| International Customers | NBET |  |  | MO |  |  |
| --- | --- | --- | --- | --- | --- | --- |
| Invoice(Million)2024/Q2 | Remittance(Million)2024/Q2 | Performance(%)2024/Q2 | Invoice(Million)2024/Q2 | Remittance(Million)2024/Q2 | Performance(%)2024/Q2 |  |
|  |  |  |  |  |  |  |
| PARAS-SBEE($) | - | - | - | 4.29 | 3.06 | 71.21 |
| TRANSCORP-SBEE($) | - | - | - | 4.25 | 4.25 | 100.00 |
| MAINSTREAM-NIGELEC($) | - | - | - | 3.59 | 2.50 | 69.72 |
| ODUKPANI-CEET($) | - | - | - | 3.47 | 0.00 | 0.00 |
| Total | - | - | - | 15.60 | 9.81 | 62.88 |
| Bilateral Customers |  |  |  |  |  |  |
| MSTM/INNER GALAXY(N)MSTM/KAM IND.(N)MSTM/KAM INT.(N)MAINSTREAM/PRISM(N)MSTM ZEBERCED(N)MSTM/ADFV(N) | - | - | - | 1,209.77 | 1,209.77 | 100.00 |
| NDPHC/WEEWOOD(N) | - | - | - | 99.80 | 0.00 | 0.00 |
| NORTH SOUTH/STAR P(N) | - | - | - | 31.57 | 17.69 | 56.03 |
| TRANS AMADI/OAU(N)TRANS AMADI(FMPI)(N) | - | - | - | 34.74 | 0.73 | 2.10 |
| NDPHC/SUNFLAG(N)OMOTOSHO II/PULKIT(N) | - | - | - | 42.28 | 0.00 | 0.00 |
| ALAOJI GENCO/APLE(N) | - | - | - | 451.56 | 0.00 | 0.00 |
| TAOPEX/KAM INT(N)TAOPEX/KAM STEEL(N) | - | - | - | 106.10 | 67.71 | 63.82 |
| SAPELE/PHOENIX |  |  |  | 15.48 | 0.00 | 0.00 |
| Total | - | - | - | 1,991.30 | 1,295.90 | 65.07 |
| Special Customer |  |  |  |  |  |  |
| AJAOKUTA STEEL(N) | 1,394.38 | 0 | 0 | 116.11 | 0 | 0 |

1. NBET, MO, SBEE, CEET and NIGELEC are Nigeria Bulk Electricity Trader, Market Operator, Société Beninoise d’Energie
   Electrique, Compagnie Energie Electrique du Togo and Société Nigerienne d’electricite

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

3.0 REGULATORY FUNCTIONS

Section 34 (2)(d) of the EA 2023 provides that the Commission is empowered to
“licence and regulate persons engaged in the generation, transmission, system
operation, distribution, supply and trading of electricity” in the NESI. In exercising
the powers conferred on it by the EA 2023, the Commission primarily engages with
participants in the NESI through selected regulatory instruments as prescribed by
law. Some of the regulatory instruments utilised by the Commission include –

• Regulations: Regulations are detailed legal rules, and bye-laws formulated
by the Commission pursuant to sections 46(2), 64, 215 and 226 of the
Electricity Act, to govern and conduct operations within the electricity sector,
ensure adherence to statutory requirements, and give effect to the
implementation of the Act.

• Orders: Orders are authoritative commands, legally binding instructions, and
directions issued by the Commission pursuant to sections 47, 64 and 215 of
the Electricity Act, requiring licensees to perform certain actions, cease, desist
from specific activities, or act in a particular way.

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

• Licences: Licences are authorisations granted by the Commission pursuant to
sections 34(2)(d), 63(1), 64, and 215 of the Electricity Act, that allow entities
to operate in activities such as the generation, transmission, trading and
distribution of electricity under specified terms and conditions.

• Permits: Permits are authorisations issued by the Commission pursuant to
sections 63(2), 64 and 215 of the Electricity Act, for specific activities, such
as the generation of electricity for own use or authorisation to participate as
a meter service provider.

* * *

### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# 3.1 Regulations, Orders and Directives

## 3.1.1 Regulations

## The Commission did not issue any new Regulation for the NESI in 2024/Q2.

## 3.1.2 Orders

## During the quarter, the Commission issued forty-two (42) Orders to guide the

## activities of licensees. The details of the Orders are outlined below:

**A. Order Nos: NERC/2024/027—NERC/2024/037 (11 Orders issued to 11 DisCos) — April 2024 Supplementary Order to the Multi-Year Tariff Order**

## (MYTO) 2024 for the Distribution Companies. Pursuant to Section 23 of the

## MYTO 2024 (details of the MYTO 2024 are contained in section 3.1.2 of the

## 2024/Q1 report), the April supplementary Orders which became effective on

## the 3rd of April 2024 sought to reflect the changes in the pass-through indices

## outside the control of licensees including inflation rates, ₦/US$ exchange rate,

## available generation capacity and gas price for the determination of cost- reflective tariffs.

## Pursuant to Section 116 of the EA and extant regulations, the Commission

## considered and approved cost-reflective tariffs for DisCos effective 03 April

**2024\. The approved tariffs were to remain in place subject to monthly adjustments for pass-through indices including inflation rates, NGN/US$**

## exchange rates and gas-to-power prices.

## However, in line with the policy direction of the FGN on electricity subsidy, the

## allowed tariffs for Band B-E customer categories remained frozen at the rates

## payable in December 2022 subject to further policy direction by the government.

## This implies that, vide the April 2024 supplementary Order, only the Band A

## customer category experienced changes in their tariffs relative to March 2024.

## The April supplementary Orders also obligated DisCos to procure a minimum of

## 10% of their 2024 load allocation from embedded generation to improve supply

## reliability and sustain the delivery of Service-Based Tariff (SBT) minimum service

## level commitments. The Orders further provided that DisCos must source a

## minimum of 50% of the embedded generation capacity from renewable energy sources.

### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# B. Order No: NERC/2024/039 — Transfer of Regulatory Oversight of the Electricity

# Market in Enugu State from the Nigerian Electricity Regulatory Commission to

# the Enugu State Electricity Regulatory Commission (EERC). The Order became

# effective on the 1st of May 2024 and has the following objectives;

# i. Commence the process of the transfer of regulatory oversight for the

# intrastate electricity market in Enugu State from the Commission to EERC

# in accordance with the Constitution of the Federal Republic of Nigeria (CFRN) and EA.

# ii. Provide a transition plan for the transfer of regulatory oversight for the

**intrastate electricity market in Enugu State from the Commission to EERC in accordance with the CFRN and the EA.**

# iii. Address ensuing transitional matters arising from the transfer of regulatory

# oversight for the intrastate electricity market in Enugu State from the Commission to EERC.

**The Order mandates Enugu Electricity Distribution Company (EEDC) to incorporate within 60 days, a subsidiary under the Companies and Allied**

**Matters Act (CAMA) for the assumption of its responsibilities for intrastate supply and distribution of electricity in Enugu State.**

# C. Order No: NERC/2024/040 — Order on the Deregulation of Meter Prices for

# Meters Deployed under the Meter Asset Provider Scheme. The Order became

**effective on the 1st of May 2024 and sought to deregulate the prices of meters deployed under the MAP scheme.**

# The Order provides that prices of meters under the MAP scheme shall be

# determined through a competitive bidding process and customers will be

# provided with a choice of authorised meter vendors. Meters to be deployed

# under the MAP scheme may include basic electronic meters, Internet of Things

# (IoT) meters, DIN Rail meters and Current Limiters but are subject to full

# compliance with the NESI Metering Code and the requirements/specifications of the DisCos.

# D. Order Nos: NERC/2024/041 and NERC/2024/042 — Transfer of Regulatory

# Oversight of the Electricity Market in Ekiti State from the Nigerian Electricity

# Regulatory Commission to the Ekiti State Electricity Regulatory Bureau (EERB).

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# The Orders became effective on the 1st of May 2024 and have the following objectives;

# i. Commence the process of the transfer of regulatory oversight for the

**intrastate electricity market in Ekiti State from the Commission to EERB in accordance with the CFRN and EA.**

# ii. Provide a transition plan for the transfer of regulatory oversight for the

**intrastate electricity market in Ekiti State from the Commission to EERB in accordance with the CFRN and the EA.**

# iii. Address ensuing transitional matters arising from the transfer of regulatory

# oversight for the intrastate electricity market in Ekiti State from the Commission to EERB.

**The Orders mandate Benin Electricity Distribution Company (NERC/2024/041) and Ibadan Electricity Distribution PLC (NERC/2024/042) to incorporate within**

# 60 days, a subsidiary each under the CAMA for the assumption of responsibilities

# for intrastate supply and distribution of electricity in their respective franchise areas in Ekiti State.

# E. Order No: NERC/2024/043 — Transfer of Regulatory Oversight of the Electricity

# Market in Ondo State from the Nigerian Electricity Regulatory Commission to the

# Ondo State Electricity Regulatory Bureau (OSERB). The Order became effective

# on the 1st of May 2024 and has the following objectives;

# i. Commence the process of the transfer of regulatory oversight for the

**intrastate electricity market in Ondo State from the Commission to OSERB in accordance with the CFRN and EA.**

# ii. Provide a transition plan for the transfer of regulatory oversight for the

**intrastate electricity market in Ondo State from the Commission to OSERB in accordance with the CFRN and the EA.**

# iii. Address ensuing transitional matters arising from the transfer of regulatory

# oversight for the intrastate electricity market in Ondo State from the Commission to OSERB.

# The Order mandates Benin Electricity Distribution Company (BEDC) to

# incorporate within 60 days, a subsidiary under the CAMA for the assumption of

# its responsibilities for intrastate supply and distribution of electricity in Ondo State.

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# F. Order No: NERC/2024/044 — NESI Interim Order on Transmission System

# Dispatch Operations, Cross-Border Supply and Related Matters 2024. The Order

# became effective on the 1st of May 2024 and sought to;

# i. Serve as an interim measure to guide the operations of the System

# Operator (SO) and the TCN to implement SOPs, operational support tools

# and other requirements to improve transparency and fairness of grid

# operations in delivering better services to all customers of the transmission system.

# ii. Place interim caps on capacities supplied to international customers for 6

# months from the effective date of the Order thus minimising the

# displacement and impact on domestic supply obligations by GenCos and

# overall risks to the Nigerian Electricity Market, even when there is a limitation in generation.

**Following the implementation of the April 2024 Supplementary Order, the Commission observed the sub-optimal grid dispatch operation which**

# compromised DisCo’s ability to deliver on the SBT committed service levels. The

**Commission noted the SO’s practice of managing generation availability by limiting DisCos load offtake/allocation while prioritising international off-takers**

# and eligible customers. This Order thus sought to ensure an equitable adjustment

# to load allocation for all off-takers (DisCos, international customers and eligible

**customers) in the event of a drop in generation and other under-frequency related grid imbalances necessitating critical grid management.**

# G. Order No: NERC/2024/045 — Order on the Establishment of the Independent

**System Operator (ISO). The Order became effective on the 1st of May 2024 and has the following objectives;**

# i. Ensure compliance with the provisions of the EA on the incorporation of the ISO.

# ii. Provide clear directives on the timelines for the incorporation of the ISO.

# iii. Outline the procedure for the transfer of the assets and liabilities of the

**market and system operations portion of the business that currently vests in the TCN to the ISO.**

# The Order mandates the Bureau of Public Enterprises (BPE) to incorporate a

# private company limited by shares to carry out market and system operation

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## functions stipulated in the EA. The name of the company shall be the Nigerian

## Independent System Operator of Nigeria Limited (NISO) which will manage all

## assets and liabilities pertaining to market and system operation as well as carry

## out all market and system operation-related contractual rights and obligations

**novated to it by the TCN. The initial subscribers to the NISO shall be the BPE and**

## the Ministry of Finance Incorporated (MOFI).

## H. Order Nos: NERC/2024/046 -NERC/2024/057 (11 Orders issued to 11

## DisCos) — May 2024 Supplementary Order to the Multi-Year Tariff Order for the

## DisCos. Pursuant to Section 7 of the April 2024 supplementary Orders which

## provides for monthly tariff reviews, the May 2024 supplementary Orders which

## became effective on the 6th of May 2024 sought to reflect the changes in the

## pass-through indices outside the control of licensees including inflation rates,

## ₦/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff.

# Due to the subsistence of the policy direction of the FGN on electricity subsidy

# which mandates that tariffs for Band B-E customer categories shall remain frozen

# at the rates payable in December 2022, subject to further policy direction by the

**government, only customers in Band A experienced any change in their May tariffs relative to April 2024.**

## I. Order No: NERC/2024/059 - NERC/2024/068, NERC/2024/070 (11 Orders

## issued to 11 DisCos) — June 2024 Supplementary Order to the Multi-Year Tariff

## Order for the DisCos. Pursuant to Section 7 of the May 2024 supplementary

## Order which provides for the monthly review of tariffs, the June 2024

## supplementary Orders which became effective on the 1st of June 2024 sought

## to reflect the changes in the pass-through indices outside the control of licensees

**including inflation rates, NGN/US$ exchange rate, available generation capacity and gas price for the determination of cost-reflective tariff.**

# Due to the subsistence of the policy direction of the FGN on electricity subsidy,

# which mandates that tariffs for Band B-E customer categories shall remain frozen

# at the rates payable in December 2022, subject to further policy direction by the

**government, only customers in Band A experienced any change in their June tariffs relative to May 2024.**

### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

J. Order No: NERC/2024/072 — Order on the Operationalisation of Tranche A
of the Meter Acquisition Fund (MAF). The Order became effective on the 24th
of June 2024 and has the following objectives;

i. Provide a transparent and functional framework for operationalising the
first tranche of metering under the MAF scheme.

ii. Provide the eligibility conditions for access to the first tranche of funding
under MAF.

iii. Provide the terms of payment, monitoring and evaluation, and other
conditions for manufacturers and MAPs participating in the scheme.

The Order provided that DisCos shall utilise the first tranche of disbursement from
the MAF scheme based on contributions made by DisCos as at the April 2024 market
settlement to procure and install meters for unmetered Band A customers within their
franchise areas. The Order also specified the reporting requirements of the various
parties to the Commission with respect to the operationalisation of the MAF (Table
11).

Table 11: Reporting requirements on the Operationalisation of MAF

| Reporting Party | Type of Report | Frequency | Receiving Party |
| --- | --- | --- | --- |
| Fund Manager(FM) | Fund Performance Report | Quarterly | NERC |
| Risk Management Report | One-off | NERC |  |
| DisCo | Meter Deployment Plan | One-off | NERC/FM |
| Monthly Meter Deployment Report | Monthly | NERC/FM |  |
| MAPs/LMMAs | Meter Installation Report | Weekly | DisCo/FM/NERC |

LMMAs - Local meter manufacturer or assembler

i. Commence the process of the transfer of regulatory oversight for the
intrastate electricity market in Imo State from the Commission to ISERC in
accordance with the CFRN and EA.

* * *

ii. Provide a transition plan for the transfer of regulatory oversight for the
intrastate electricity market in Imo State from the Commission to ISERC in
accordance with the CFRN and the EA.

iii. Address ensuing transitional matters arising from the transfer of regulatory
oversight for the intrastate electricity market in Imo State from the
Commission to ISERC.

The Order mandates EEDC to incorporate within 60 days, a subsidiary under the
CAMA for the assumption of its responsibilities for intrastate supply and distribution
of electricity in Imo State.

3.1.3 Directives

In 2024/Q2, the Commission issued one (1) Directive for managing grid imbalances
caused by insufficient generation. The details of the Directive are outlined below;

A. NERC/2024/003 — Directive to Independent System Operator for the utilisation
of Zungeru Hydro Electricity Generation Company Limited for managing grid
imbalances caused by insufficient generation. The directive was to be effective
from 16th May 2024 until 31st August 2024.

The Directive was issued further to the Commission’s Order on the Transmission
System Dispatch Operation, Cross-Border Supply and Related Matters
(NERC/2024/044) and in the overriding public interest of ensuring continuous
improvement in electricity supply to Nigerians. The Directive was issued to
ensure that the Zungeru power plant continued to inject power to improve
service delivery to electricity consumers pending the finalisation of its long-term
contractual arrangements with prospective off-takers.

The Commission continued to monitor compliance with the provisions of other
existing regulations, orders, and standards governing the NESI during the quarter.

3.2 Licences Issued or Renewed

* * *

Table 12: Licences issued by the Commission in 2024/Q2

| SN | Licensee | Location | Capacity(MW) | License Type | Fuel Type |
| --- | --- | --- | --- | --- | --- |
|  | New |  |  |  |  |
| 1 | Auro Nigeria Private Limited | Kaduna State | 1.50 | Off-grid | Gas |
| 2 | Daybreak Power SolutionsLimited | Ogun State | 2.00 | Off-grid | Solar |
| 3 | Daybreak Power SolutionsLimited | Ogun State | 2.25 | Off-grid | Solar |
| 4 | Daybreak Power SolutionsLimited | Ogun State | 2.41 | Off-grid | Solar |
| 5 | Daybreak Power SolutionsLimited | Lagos State | 4.20 | Off-grid | Solar |
| 6 | Water Resources AssetHolding Co.Ltd | Taraba State | 40.00 | On-grid | Hydro |
| 7 | Bogi Power GenerationCo.Limited | Cross RiverState | 26.00 | On-grid | Gas |
| 8 | Golden Triangle ElectricPowerSolutionsCo.Ltd | Lagos State | NA | Trading | NA |
| 9 | Nigeria Independent SystemOperatorLimited | FCT,Abuja | NA | SystemOperator | NA |

3.3 Captive Power Generation Permits

Captive power generation permits are issued to entities that intend to own and
maintain power plants exclusively for their own consumption i.e. no sale of electricity
generated from the plant to any third party. The Commission issued one (1) captive
power generation permit in 2024/Q2 to Nestle Nigeria in Lagos State with a
nameplate capacity of 5MW.

3.4 Mini-grid Permits and Registration Certificates

Pursuant to section 165(1)(m) of the EA 2023 which states that the Commission
shall “award licence of mini-grid concessions to renewable energy companies to
exclusively serve a specific geographical location indicating aggregate electricity
to be generated and distributed from a site with obligation to serve customers to
request service”, the Commission continues to encourage the development and
utilisation of renewable energy by issuing permits and registration certificates for
mini-grid development.

* * *

A permit is issued to a mini-grid developer for the construction, operation, and
maintenance of mini-grids with distribution capacity above 100kW and generation
capacity up to 1MW. The Commission also issues registration certificates to a mini -
grid developer for one or more systems with distribution capacity below 100kW.
The Commission did not issue any mini-grid permit or registration certificate in
2024/Q2.

3.5 Meter Service Providers/Meter Asset Providers

A Meter Service Provider (MSP) is an entity certified by the Commission as a
manufacturer, supplier, vendor, or installer of electric energy meters and/or
metering systems. A Meter Asset Provider (MAP) is an entity that is granted a permit
by the Commission to provide metering services with roles that may include meter
financing, procurement, supply, installation, maintenance, and replacement.

The Commission certified six (6) MSPs – three (3) meter installer companies, and
three (3) meter manufacturers in 2024/Q2. The Commission also issued 2 (two)
permits for MAP. Details of the certified MSPs and MAP are contained in Table 13.

Table 13: Meter Service Providers certified in 2024/Q2

| S/N | Name | Authorisation Type |
| --- | --- | --- |
|  | Meter Service Providers |  |
| 1 | Mojec Meter Asset Management | Installer A1 |
| 2 | Omelus Integrated Solutions Limited | Installer A1 |
| 3 | Unistar Hi-Tech Systems Limited | Installer A1 |
| 4 | Mojec Meter Asset Management Co Limited | Manufacturer |
| 5 | MBH Power Limited | Manufacturer |
| 6 | Amal Technologies Limited | Manufacturer |
|  | Meter Asset Providers |  |
| 1 | Smart Meters Asset Provider Limited | MAP |
| 2 | Deep Vision Business Venturers Limited | MAP |

Class “A1” Certification authorises a holder to undertake installations of (i) Low Voltage single -phase and three-phase
Metering systems for installation exceeding 750 metering Systems/Contract, and (ii) Installations at grid voltages exceeding
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.

* * *

3.6 Hearings and Public Consultations

determination by the Commission and file appeal against the decisions of the
Commission’’. One of the ways by which the Commission performs this quasi-judicial
16
role towards the resolution of disputes between stakeholders is through hearings.
During the quarter (2024/Q2) the Commission conducted hearings to consider the
petitions filed by different stakeholders on issues pertaining to the provision and

petitions filed by different stakeholders on issues pertaining to the provision and
utilisation of electricity services. The details of the hearings are contained in Table
14\. Furthermore, the NERC business rules allow the Commission to undertake public
consultations through which the Commission aggregates input/opinions on licensee
applications and/or regulatory instruments which are being drafted or reviewed.

petitions filed by different stakeholders on issues pertaining to the provision and
utilisation of electricity services. The details of the hearings are contained in Table
14\. Furthermore, the NERC business rules allow the Commission to undertake public
consultations through which the Commission aggregates input/opinions on licensee
applications and/or regulatory instruments which are being drafted or reviewed.

Table 14: Hearings conducted by the Commission in 2024/Q2

| S/N | Parties | Petition | Date of Hearing | Update |
| --- | --- | --- | --- | --- |
| 1 | CCECC SUK Power Company & SUK Distribution Plc | Petition for a review of fines imposed by the commission for operating undertakings without requisite licensees | 8 May 2024 | Subjudiced by suite no: FHC/LF/CS/4/2024 |
| 2 | Manufacturers Association of Nigeria | Petition for the reversal/indefinite suspension of the implementation of the new electricity tariff rate implemented in the Supplementary Multi-Year Tariff Order of 3rd April 2024 and 6th May 2024 | 23 May 2024 | Subjudiced by suite no: FHC/L/CS/881/2024 |
| 3 | Ibadan DisCo | Petition for a review of April Supplementary Order to MYTO 2024&non-compliance with the procedure for tariff review | 30 May 2024 | The ruling has been communicated |

16
Hearings are proceedings pursuant to the provisions of the Act through which the Commission seeks additional
information on petitions or any matter filed before it by market participants or consumers in order to make a
final decision.

* * *

3.7 Compliance and Enforcement

Section 64(1) of the EA 2023 mandates all licensees to comply with the provisions
of their licences, regulations, codes, orders and other requirements issued by the
Commission. The Commission is responsible for evaluating the compliance of all its
licensees/permit-holders and carrying out enforcement actions against infractions
based on the provisions of the Act and other extant regulatory instruments.

Pursuant to the provisions of Section 76 of the EA 2023, the Commission issued five
(5) Rectification Directives (RD), five (5) Notices of Intention to Commence
Enforcement (NICE) and three (3) fines for different breaches/defaults in 2024/Q2
(full list and further details can be found in Table 15). The Commission is committed
to ensuring that all licensees comply with the codes and standards of the NESI as
well as the provisions of their respective licences.

3.8 Alternative Dispute Resolution

Pursuant to the provisions of section 42.3.7 of the Market Rule, the Commission has
established an Alternative Dispute Resolution (ADR) process to resolve disputes

Pursuant to the provisions of section 42.3.7 of the Market Rule, the Commission has
established an Alternative Dispute Resolution (ADR) process to resolve disputes

established an Alternative Dispute Resolution (ADR) process to resolve disputes
between market participants in the NESI. This includes the constitution of a Dispute

Resolution Panel (DRP) and the appointment of a Dispute Resolution Counsellor
(DRC). No disputes were brought before the DRP during this quarter.

Resolution Panel (DRP) and the appointment of a Dispute Resolution Counsellor
(DRC). No disputes were brought before the DRP during this quarter.

| SN | RD/NICE/Fine | Licensee | Date of Issuance | Deadline |
| --- | --- | --- | --- | --- |
| Rectification Directive |  |  |  |  |
| 1 | Failure to submit the Annual Compliance Report on the 2023 Outage Scheduling Programme | TCN | 19 April 2024 | 03 May 2024 |
| 2 | Failure to replace faulty prepaid meter | Abuja DisCo | 28 March 2024 | 04 April 2024 |
| 3 | Directive to reconcile the difference in the amount owed by a customer | Abuja DisCo | 07 May 2024 | 21 May 2024 |
| 4 | Non-metering of Maximum Demand (MD) customers and estimated billing of MD customers | All DisCos except Kaduna and Kano | 31 May 2024 | 14 June 2024 |

* * *

SECOND QUARTER 2024

NERC QUARTERLY REPORTS

| 5 | Non-compliance with the Commission's directives regarding Angwan Magaji Community | Abuja DisCo | 08 May 2024 | 22 May 2024 |
| --- | --- | --- | --- | --- |
| Notice of Intention to Commence Enforcement(NICE) |  |  |  |  |
| 6 | Failure to comply with the HSE Code and NESIS regulations | Abuja,Eko,Jos and Ikeja DisCos | 03 April 2024 | 16 April 2024 |
| 7 | Breach of Eligible Customer Regulations 2017 | TCN | 8 April 2024 | 22 April 2024 |
| 8 | Failure to comply with forum decision in favour of New Haven Community | Abuja DisCo | 05 April 2024 | 19 April 2024 |
| 9 | Health and safety infractions | TCN | 03 April 2024 | 17 April 2024 |
| 10 | Non-compliance/health and safety infractions | TCN | 21 June 2024 | 5 July 2024 |
| Fines |  |  |  |  |
| 14 | A fine of NGN2,250,000 and USD450,000(or its naira equivalent) for partaking in the NESI without a licence | CCETC SUK Power Limited | 03 April 2024 | 7 May 2025 |
| 15 | A fine of NGN1,000,000 and USD200,000(or its naira equivalent) for partaking in the NESI without a licence | SUK Distribution Company Limited | 03 April 2024 | 7 May 2025 |
| 16 | A fine of NGN200,000,000 for non-compliance with the supplementary Order to the April 2024 MYTO (NERC/2024/027) | Abuja DisCo | 25 April 2024 | 31 July 2024 |

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

#### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# 4.0 CONSUMER AFFAIRS

## 4.1 Consumer Enlightenment and Stakeholder Engagements

### The Commission’s main consumer education and enlightenment mechanisms are

**town hall meetings and customer complaints resolution meetings. These are used to enlighten consumers/stakeholders on the Commission’s activities, regulations,**

### consumer rights and obligations as well as to ensure swift resolution of complaints.

### These fora also provide avenues for the Commission to gather feedback from

### consumers which is beneficial to the Commission in its decision-making processes.

### As part of its routine activities, the Commission also engages relevant stakeholders

### as well as the wider public to apprise them of the Commission’s activities. The main

### avenues for the interface between the Commission and stakeholders are:

- **NESI stakeholder meetings** • **Trainings/Workshops**
- **General stakeholder engagement activities**

### The details of these engagements are shared with the public via the Commission’s

### social media accounts (LinkedIn, X and Instagram). In addition to the update on the

### engagement activities, the Commission also uses these channels to address relevant issues including:

- **Consumer rights and obligations** • **Service delivery standards**
- **NESI performance factsheets** • **Regulatory instruments issued by the Commission**
- **Summary of the statutory reports of the Commission**

### In 2024/Q2, the Commission held one (1) town hall meeting in Enugu between

**18th-20th April 2024. Some of the major issues that were discussed at the town hall meeting include:**

- **Serviced Based Tariff (SBT) provisions**
- **Capping of estimated bills for unmetered customers**
- **Electricity customer rights and obligations**
- **Electricity customer redress mechanisms**

#### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

• Unauthorised electricity access

• Strategies by the Commission to ensure improved overall service delivery
to customers.

The Commission also continued to sponsor radio jingles across radio stations
throughout the country. These jingles educate customers on complaint redress
mechanisms and provide addresses of NERC Forum Offices.

4.2 Metering End-Use Customers

As of 30th June 2024, 5,993,340 (45.43%) out of the 13,192,573 registered
electricity customers across the twelve (12) DisCos were metered (breakdown
contained in Table 16).

Table 16: Metering Progress as of 2024/Q2

| DisCos | Total No.of Registered Customers | No. of Metered Customers | Metering Rate |
| --- | --- | --- | --- |
| Aba | 198,531 | 71,135 | 35.83% |
| Abuja | 1,244,245 | 873,083 | 70.17% |
| Benin | 1,369,840 | 675,092 | 49.28% |
| Eko | 773,171 | 438,462 | 56.71% |
| Enugu | 1,396,440 | 635,042 | 45.48% |
| Ibadan | 2,498,224 | 1,069,201 | 42.80% |
| Ikeja | 1,208,581 | 926,272 | 76.64% |
| Jos | 747,162 | 251,689 | 33.69% |
| Kaduna | 877,528 | 210,229 | 23.96% |
| Kano | 881,922 | 212,016 | 24.04% |
| Port Harcourt | 1,179,194 | 502,409 | 42.61% |
| Yola | 817,735 | 128,710 | 15.74% |
| Total | 13,192,573 | 5,993,340 | 45.43% |

\*Metering rate: Red <50, Amber 50≤70, Green ≥70

During 2024/Q2, 49,188 end-user customers were metered with Abuja, Ikeja and
Aba DisCos recording the highest number of meter installations accounting for
23.85%, 18.45% and 17.86% respectively, of the total installations. Relative to
2024/Q1, this translates to a -60.86% decrease in the total number of customers
metered during the quarter (125,664).

* * *

Only ano (+138.19%) and Aba (+12.37%) DisCos recorded improvements in the
number of meter installations. All other DisCos recorded a decline in meter
installations with Jos (-87.48%), Eko (-82.53%) and Ibadan (-77.19%) DisCos
recording the biggest decline in the number of meters installed in 2024/Q2
compared to 2024/Q1 (Table 17).

Table 17: Meter Deployment by DisCos 2024/Q1 vs. 2024/Q2

| DisCos | Total No.of metered customers as of2024/Q2 | No.of customers metered in2024/Q2 | No.of customers metered in2024/Q1 | Change in metering(%) |
| --- | --- | --- | --- | --- |
| Aba | 71,135 | 8,784 | 7,817 | 12.37% |
| Abuja | 873,083 | 11,733 | 21,493 | -45.41% |
| Benin | 675,092 | 3,510 | 10,455 | -66.43% |
| Eko | 438,462 | 810 | 4,637 | -82.53% |
| Enugu | 635,042 | 4,241 | 13,932 | -69.56% |
| Ibadan | 1,069,201 | 5,828 | 25,551 | -77.19% |
| Ikeja | 926,272 | 9,076 | 27,795 | -67.35% |
| Jos | 251,689 | 457 | 3,649 | -87.48% |
| Kaduna | 210,229 | 2,450 | 3,027 | -19.06% |
| Kano | 212,016 | 474 | 199 | 138.19% |
| Port Harcourt | 502,409 | 1,825 | 6,278 | -70.93% |
| Yola | 128,710 | - | 831 | - |
| Total | 5,993,340 | 49,188 | 125,664^{17}$ | -60.86% |

Out of the 49,188 end-use customers metered in 2024/Q2, 73.16% of customers
were metered under the MAP framework, 26.11% were metered under Vendor
Financed framework, 0.54% were metered under the NMMP framework and 0.20%
18
were metered under the DisCo Financed framework. Further details on the

17
Upon data reconciliation, the number of meters installed across all metering schemes in 202 4/Q1 was
125,664 as against 123,604 reported in the 2024/Q1 report.
18
There are 5 metering frameworks contained in the Commission’s updated MAP & NMMP Regulations (NERC -

18
There are 5 metering frameworks contained in the Commission’s updated MAP & NMMP Regulations (NERC -
R-113-2021). They are:
• Meter Asset Provider: This framework aims to provide for the provision and maintenance of end-user

• Meter Asset Provider: This framework aims to provide for the provision and maintenance of end-user
meters as a service by third-party investors on which customers benefitting from such meters pay a
Metering Service Charge (MSC) to cover the cost of metering service.
• National Mass Metering Programme: This is a policy intervention with support from the CBN for the

• 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.

* * *

### SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## metering progress under the NMMP, MAP as well as Vendor and DisCo financed

## frameworks are presented in appendices IX, X and XI respectively.

## Under the MAP framework, a total of 35,985 meters were installed in 2024/Q2

## representing a -68.46% decrease compared to the 114,082 MAP meter installations

## recorded in 2024/Q1. Abuja (10,717), Ibadan (5,828) and Ikeja (5,732) DisCos

## recorded the highest number of installations under the MAP framework during the

## quarter with 29.78%, 16.20% and 15.93% of the total installations respectively.

## Since October 2023, only aduna DisCo has metered customers under the NMMP

## framework; 264 customers were metered in 2024/Q2. Abuja, Eko, Ibadan, Ikeja,

## Jos and Port Harcourt DisCos have exhausted their meter allocations under the

## NMMP phase 0 and hence have achieved a 100% utilisation rate. Benin, aduna

## and Yola still have significant allocations under the NMMP which they are yet to utilise.

## A total of 12,843 customers were metered under the Vendor financed framework in

## 2024/Q2. Aba, Abuja, Benin and Ikeja are the only DisCos that have taken

## advantage of this metering framework. During the quarter, Aba and Ikeja DisCos

## installed 8,483 and 3,344 respectively, under the framework. These correspond to

## +31.09% and +33.02% change respectively compared to the 6,471 and 2,514

**installations in 2024/Q1. Only ano DisCo (96) recorded meter installations under the DisCo financed framework in 2024/Q2.**

# 4.3 Customer Complaints

## In furtherance of its mandate as contained in section 119(1)(c) of the EA 2023 which

## states that “the Commission shall develop in consultation with licensees, the customer

## complaints handling standard and procedure”, the Commission provides various

- **Vendor Finance: This is a mutual agreement between a DisCo and a Local Meter** **Manufacturer/Assembler (LMMA) or Meter Asset Provider (MAP) on a deferred payment arrangement** **where the base cost of meters shall not exceed the regulated price approved by the Commission.**
- **Self-funded by DisCos: This involves procurement of meters from other sources outside the MAP and** **NMMP framework. The allowable costs of meters, accessories, installation and warranties should not** **exceed the regulated pricing approval by the Commission and the terms of supply should not be in** **conflict with terms of existing MAP and NMMP contracts.**
- **Other External Efficient Meter Financing: The Commission has also approved other external meter** **financing that are efficient, cost-effective, and in tune with the terms of existing MAP and NMMP** **contracts.**

### \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

# channels for customers to lodge complaints against their service providers. The

# primary channels available for customers to lodge complaints in the NESI are:

# A. NERC Customer Complaint Unit (NERC-CCU): This is a unit at the Consumer

# Affairs Division of the Commission dedicated to the 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).

# B. DisCo Customer Complaint Unit (DisCo-CCU): This is a department in a DisCo that

# is dedicated to the receipt and resolution of complaints from customers. DisCos

**submit monthly customer complaints reports which the Commission reviews to identify cases where regulatory intervention is necessary.**

# C. NERC Forum Offices: Forum offices serve as the “court of second instance” for

# customers not happy with the resolution of their complaints at the DisCo-CCU. The

# Commission set up Forum Offices to hear and resolve customer complaints not

# satisfactorily resolved at the DisCo-CCUs. As of 30th June 2024, 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 XV.**

# The Forum Office is managed by the forum secretariat while the hearings are

# conducted by five (5) forum panel members who are not staff of the Commission, as

# stipulated in the Customer Protection Regulation (CPR) 2023. The forum panels hear

**and resolve customer complaints in the state in which it is situated, if there is no**

# Forum Office in a state, the Commission determines which neighbouring Forum

**Office will oversee customer complaints from the state. The composition of the forum panel is as follows:**

**1\. A legal practitioner with experience in alternative dispute resolution nominated by the Nigerian Bar Association (NBA).** **2\. A financial expert nominated by either the Manufacturers Association of Nigeria, Nigerian Association of Chambers of Commerce, Industry, Mines** **and Agriculture (NACCIMA) or any other reputable organisation. 3. A qualified electrical engineer nominated by either the Council for Regulation**

# of Engineering in Nigeria (COREN) or the Nigerian Society of Engineers (NSE).

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

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

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

# D. Power Outage Reporting System (PORS): This is a mobile application designed

# for electricity customers to report outages in real time. The pilot phase for the

# operationalisation of the PORS has already started with AEDC and there are clear

**timelines for the extension of the system to other DisCos once the pilot phase is completed.**

# 4.3.1 NERC-CCU

# In 2024/Q2, 4,469 complaints were received at the Commission’s CCU and 1,000

# were resolved corresponding to a 22.38% resolution rate. Customers of Ikeja and

# Eko DisCos lodged 1,704 and 1,052 complaints accounting for 38.13% and

# 23.54% respectively of the total complaints lodged at NERC-CCU. Conversely, Aba

# Power had the lowest number of complaints with 16 (0.36%).

# During the quarter, customer complaints about billing constituted 30.90% of the total

**complaints. Other common issues among the 4,469 complaints received were complaints about tariff band (24.70%), service interruption (17.92%) and metering**

# (17.72%). These four (4) complaints categories cumulatively accounted for 91.25%

# of the total complaints in the quarter (Figure 10). The complaints on billing that were

# resolved during the quarter resulted in a credit adjustment on customers' bills to the

# tune of ₦134,127,040.25 (Appendices XIII and XIV).

# The Commission notes the poor resolution rate (22.38%) of complaints lodged at

# the NERC-CCU in 2024/Q2 and is taking steps to improve the speediness of

**complaints resolution by DisCos. The complaint resolution meetings organised by the Commission between DisCos and customers provide for “on-the-spot” resolution**

# of customer complaints by DisCos. If the complaints raised at the meetings cannot

# be resolved on the spot, the Commission provides reasonable timelines for resolution

# and has put in place a tracking mechanism to monitor DisCos’ compliance.

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

Figure 10: Category of complaints received at the Commission’s CCU in 2024/Q2

4.3.2 DisCo-CCUs

The number of complaints received by DisCos in 2024/Q1 and 2024/Q2 are
contained in Table 18. The total number of complaints received in 2024/Q2 was
287,441 across all DisCos; this translates to a -1.35% decrease compared to the
291,380 received in 2024/Q1. Port Harcourt DisCo received the highest number
of complaints (56,928) representing 19.81% of total complaints received. Yola
DisCo received the least number of complaints (2,038) representing 0.71% of total
complaints received.

Table 18: Complaints Received by DisCos in 2024/Q1 vs. 2024/Q2

|  | No. of complaints received in 2024/Q1 | No. of complaints received in 2024/Q2 | Change in No. of complaints received | Change in No. of complaints received(%) |
| --- | --- | --- | --- | --- |
| Aba | 3,328 | 4,279 | 951 | 28.58% |
| Abuja | 27,476 | 25,893 | -1,583 | -5.76% |
| Benin | 6,877 | 6,020 | -857 | -12.46% |
| Eko | 47,900 | 53,377 | 5,477 | 11.43% |
| Enugu | 35,584 | 22,020 | -13,564 | -38.12% |
| Ibadan | 53,737 | 51,718 | -2,019 | -3.76% |
| Ikeia | 22,995 | 20,536 | -2,459 | -10.69% |

* * *

| DisCos | No. of complaints received in2024/Q1 | No. of complaints received in2024/Q2 | Change in No.of complaints received | Change in No.of complaints received(%) |
| --- | --- | --- | --- | --- |
| Jos | 18931 | 20013 | 1082 | 5.72% |
| Kaduna | 6900 | 6546 | -354 | -5.13% |
| Kano | 11413 | 18073 | 6660 | 58.35% |
| PH | 53454 | 56928 | 3474 | 6.50% |
| Yola | 2785 | 2038 | -747 | -26.82% |
| Total | 291380 | 287441 | -3939 | -1.35% |

ano (+58.35%) and Aba (+28.58%) DisCos recorded the most significant increase
in the number of customer complaints received in 2024/Q2 compared to 2024/Q1.
Conversely, Enugu (-38.12%) and Yola (-26.82%) DisCos recorded the most
significant decrease in the number of customer complaints received.

The most common issues among the 287,441 complaints received by DisCos in
2024/Q2 were metering (48.85%), billing (14.29%), and service interruption
(9.80%). These three (3) complaints categories cumulatively accounted for 72.95%
of the total complaints in the quarter (Figure 11).

Figure 11: Category of complaints received by DisCos in 2024/Q2

* * *

4.3.3 Forum Offices

The summary of the appeals received across the Forum Offices is presented in Table
19\. Through 2024/Q2, there were 2,625 active appeals (905 pending appeals
from 2024/Q1 and 1,720 new appeals in 2024/Q2) across the 32 Forum Offices.
This represents a +8.07% increase compared to the 2,429 active appeals in the
previous quarter (2024/Q1). Compared to 2024/Q1, the pending appeals carried
over in the quarter (2024/Q2) increased by 129 (+16.62%) while new appeals
increased by 67 (+4.05%). The Forum Offices serving Ibadan DisCo have the
highest number of active appeals (717) while the Forum Office serving Yola DisCo
has the fewest (8) in 2024/Q2.

The total number of Forum sittings in 2024/Q2 increased by +4.17% from 72 sittings
in 2024/Q1 to 75. Cumulatively, the Forum Offices recorded a decrease of -2.65pp
in appeal resolution rate between 2024/Q1 and 2024/Q2; 57.55% vs. 54.90%.
The decrease in complaint resolution rate despite an increase in forum sitting can be
attributed to the number of active appeals during the quarter compared to
2024/Q1. The Commission will continue efforts to ensure that the forum panels sit
regularly to increase the resolution rate and reduce the number of pending appeals
carried over across quarters.

Table 19: Appeals handled by Forum Offices in 2024/Q2

| DisCos | Forum Offices | Appeals Received¹ | Appeals Resolved² | Appeals Pending³ | No. of Sittings |
| --- | --- | --- | --- | --- | --- |
| Abuja | Abuja, Lafia & Lokoja | 60 | 37 | 23 | 6 |
| Aba | Umuahia | 5 | 2 | 3 | 0 |
| Benin | Asaba & Benin | 130 | 98 | 30 | 7 |
| Eko | Eko | 218 | 155 | 63 | 6 |
| Enugu | Abakaliki, Akwa, Enugu, Owerri, & Umuahia | 457 | 252 | 154 | 16 |
| Ibadan | Ibadan, Abeokuta, Ilorin & Osogbo | 717 | 314 | 328 | 15 |
| Ikeja | Ikeja | 642 | 320 | 322 | 8 |
| Jos | Bauchi, Gombe, Jos & Makurdi | 44 | 24 | 17 | 3 |
| Kaduna | Gusau, Kaduna, Kebbi & Sokoto | 52 | 35 | 6 | 5 |
| Kano | Jigawa, Kano & Katsina | 31 | 22 | 3 | 2 |

* * *

SECOND QUARTER 2024

| DisCos | Forum Offices | Appeals Received¹ | Appeals Resolved² | Appeals Pending³ | No. of Sittings |
| --- | --- | --- | --- | --- | --- |
| P/Harcourt | Calabar, Port Harcourt & Uyo | 261 | 180 | 79 | 7 |
| Yola | Yola | 8 | 2 | 6 | 0 |
| All DisCos | All Forum Offices | 2625 | 1441 | 1034 | 75 |

1 2.
Appeals received include outstanding appeals from the preceding quarter. Appeals resolved excludes 63 appeals
3\.
withdrawn and 87 appeals rejected. Appeals are still within the regulatory timeframe of 2 months to resolve.

The breakdown of the various categories of active appeals at the Forum Offices in
2024/Q2 is contained in Figure 12. Similar to 2024/Q1, appeals related to billing
were the most prevalent, accounting for 55.93% of the total appeals received
(2024/Q1 – 59.59%). Appeals related to metering and disconnection represented
25.23% and 6.22% of the appeals, respectively. The Commission is working on
interventions to improve the quality of customer complaint resolution at the DisCo-
CCU to resolve effectively and reduce the number of appeals filed at the Forum
Offices.

The breakdown of the various categories of active appeals at the Forum Offices in
2024/Q2 is contained in Figure 12. Similar to 2024/Q1, appeals related to billing
were the most prevalent, accounting for 55.93% of the total appeals received
(2024/Q1 – 59.59%). Appeals related to metering and disconnection represented
25.23% and 6.22% of the appeals, respectively. The Commission is working on
interventions to improve the quality of customer complaint resolution at the DisCo-
CCU to resolve effectively and reduce the number of appeals filed at the Forum

In addition to establishing additional Forum Offices and other customer complaint
resolution channels, the Commission will continue to explore strategies to improve
the operational efficiency of Forum Offices.

Figure 12: Category of Complaints Received by Forum Offices in 2024/Q2

* * *

4.4 Health and Safety

Pursuant to Section 34(1)(e) of the EA 2023 which mandates the Commission to
“ensure the provision of safe and reliable electricity to consumers”, the Commission
monitors the health and safety performance of the NESI. Licensees are mandated to
submit monthly Health and Safety reports to the Commission in accordance with the
requirements of their licence. In 2024/Q2, out of the 99 mandatory health and
19
safety reports expected to be received from licensees, only 91 reports were
received.

The Commission will continue to enforce 100% reporting compliance by licensees
as contained in the terms and conditions of their respective licences, and apply
sanctions where applicable.

Statistics of accidents in the NESI for 2024/Q2 are presented in Table 20. Relative
to 2024/Q1, the number of accidents increased by +14.55% (55 to 63), the number
of fatalities increased by +47.83% (23 to 34) but the number of injuries decreased
by -45.16% (31 to 17).

Table 20: Health and Safety (H&S) Reports in 2024/Q1 vs. 2024/Q2

| Item | 2024/Q1 | 2024/Q2 | Net Change |
| --- | --- | --- | --- |
| Number of Accidents | 55 | 63 | +8 |
| Number of fatalities (employees&third parties) | 23 | 34 | +11 |
| Number of Injuries | 31 | 17 | -14 |

During the quarter (2024/Q2), no casualty was recorded among the GenCos while
20
NESCO and Yola were the only DisCos that did not record casualties. Out of the
fifty-one (51) casualties reported in the quarter, the licensees with the highest number
of casualties were Ibadan (13), Eko (8), Jos (7) and Enugu (6) which represented
25.49%, 15.69%, 13.73% and 11.76% of the total respectively.

As observed in previous quarters, DisCos continue to account for the majority of the
safety challenges experienced in NESI. Cumulatively, they accounted for 100% of

19
The licensees with outstanding reports are Paras Energy (3), FIPL (2); Benin (1), Ibadan (1) and Jos (1)
DisCos
20Casualty refers to the count of injuries and deaths arising from any safety accident/incident.

20Casualty refers to the count of injuries and deaths arising from any safety accident/incident.

* * *

causalities recorded in 2024/Q2 having accounted for 98.48% and 96.30% in
2023/Q4 and 2024/Q1 respectively.

Furthermore, TCN (23), Ibadan (2) and Eko (1) recorded damage to
property/infrastructure due to explosions, fire outbreaks or acts of vandalism in
2024/Q2. The accident report showing all licensees with casualties during the
quarter is detailed in Figure 13.

Figure 13: Accident Report for 2024/Q2

The breakdown of the causes of causalities arising from the accidents reported in
2024/Q2 is contained in Table 21.

Table 21: Causes of casualties recorded in 2024/Q2

| Cause of Casualty | Number of Fatalities | Number of Injuries |
| --- | --- | --- |
| Wire snaps | 8 | 1 |
| Illegal/unauthorised access | 11 | 1 |
| Vandalism | 4 | 0 |
| Unsafe acts/conditions | 10 | 14 |
| Falls from height | 0 | 2 |

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

**The Commission has initiated investigations into all reported accidents and will enforce appropriate actions against licensees where necessary. Furthermore, the**

# Commission continues to closely monitor the implementation of licensees’ accident

# reduction strategy for the NESI. The Commission also implements various programs

# aimed at improving the health and safety performance of the NESI.

# In June 2024, the biannual Health and Safety Manager’s Meeting was held with

# compliance and regulatory officers of licensees 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. The Commission shall continue to ensure that all licensees comply with the subsisting performance standards in the NESI.**

# In addition, the Commission oversees settlement processes between licensees and

# families of accident victims in the NESI. This is to ensure transparency of the

# settlement process and to help the victim’s family secure fair compensation for losses

# suffered. In 2024/Q2, the Commission oversaw the successful conclusion of three

# (3) compensation negotiations between licensees and families of victims of accidents.

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]

* * *

5.0 Appendix

Appendix I: Definition of Terms

| Term | Definition |
| --- | --- |
| Accident | This is an incident that happens unexpectedly and unintentionally, typically resulting in damage, injury, or fatality |
| Available Capacity | This is the maximum rated output (MW) of a power plant over a specified period declared by the operator when restricted by factors such as feedstock availability, mechanical availability, environmental conditions, etc. |
| Bilateral customers | These are customers who purchase electricity directly from GenCos without a middleman(e.g.,bulk trader). |
| Cost-reflective tariff | This is a tariff that if charged to consumers will allow for 100% recovery of the costs incurred in the production, transmission, distribution,and supply of electricity as well as guaranteeing regulatory approved profit margin for the operators. |
| Energy offtake | This is the process by which distribution companies receive and supply energy to end-use consumers |
| Feedstock | This refers to the type of fuel(e.g.,gas,water)required to power a generating plant |
| Installed capacity | This is the maximum rated output of a power plant under specific conditions designated by the manufacturer |
| Load factor | This is a measure of the utilisation of a power plant's capacity,calculated as the ratio of the average electricity generated over a period to the maximum possible generation(assuming all the available capacity is utilised). |
| Mini-grid | This is an electricity supply system with its own power generation capacity,supplying electricity to more than one customer and which can operate in isolation from or be connected to a distribution network |
| Orders | A series of directives/instructions issued by the Commission to Licensees in response to a particular event/situation |
| Plant Availability Factor | This is a parameter that measures the proportion of a plant's installed capacity which is available for the generation of electric energy. |
| Regulations | A set of rules that the Commission may issue from time to time to optimise the performance of licensees to give effect to the object of the EA 2023 |
| Service-based tariff | Service-based tariff is a pricing system under which consumers are charged varying tariffs dependent on the average number of hours of supply they receive per day. |
| Total Energy Generated | This refers to the total energy generated(GWh)by a power plant during the period under review |

* * *

Appendix II: Energy Generation in 2024/Q1 vs. 2024/Q2

| GenCos | Available Capacity(MW) |  | Average Daily Generation(MWh) |  | Quarterly Generation(GWh) |  |
| --- | --- | --- | --- | --- | --- | --- |
| 2024/Q1 | 2024/Q2 | 2024/Q1 | 2024/Q2 | 2024/Q1 | 2024/Q2 |  |
| Afam IV-V | 43.90 | 19.19 | 1,043.75 | 405.84 | 94.98 | 36.93 |
| Afam VI | 316.20 | 275.72 | 7,727.88 | 6,383.00 | 703.24 | 580.85 |
| Alaoji NIPP | 0.00 | 0.18 | 0.00 | 0.00 | 0.00 | 0.00 |
| Azura IPP | 442.49 | 452.00 | 9,607.38 | 9,567.64 | 874.27 | 870.65 |
| Dadin Kowa Hydro | 25.54 | 6.42 | 603.96 | 150.24 | 54.96 | 13.67 |
| Delta GS | 349.18 | 347.33 | 8,300.36 | 8,053.25 | 755.33 | 732.85 |
| Egbin ST(Gas) | 431.12 | 659.27 | 10,037.42 | 14,919.90 | 913.40 | 1,357.71 |
| Gbarain | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 | 0.00 |
| Geregu | 225.30 | 150.42 | 5,414.13 | 3,433.86 | 492.69 | 312.48 |
| Geregu NIPP | 122.80 | 183.26 | 2,939.19 | 3,767.40 | 267.47 | 342.83 |
| Ibom | 113.50 | 91.67 | 1,573.01 | 1,525.56 | 143.14 | 138.83 |
| Ihovbor NIPP | 5.54 | 0.13 | 117.24 | 0.00 | 10.67 | 0.00 |
| Jebba | 328.24 | 296.68 | 7,266.51 | 6,214.26 | 661.25 | 565.50 |
| Kainiji | 432.41 | 300.65 | 10,014.77 | 6,827.68 | 911.34 | 621.32 |
| Odukpani | 278.42 | 300.96 | 6,421.78 | 6,647.56 | 584.38 | 604.93 |
| Okpai | 272.54 | 206.98 | 5,694.73 | 4,151.31 | 518.22 | 377.77 |
| Olorunsogo | 79.91 | 79.53 | 1,960.59 | 1,857.32 | 178.41 | 169.02 |
| Olorunsogo NIPP | 66.37 | 14.28 | 1,639.76 | 348.90 | 149.22 | 31.75 |
| Omoku | 51.58 | 46.14 | 1,616.69 | 1,339.92 | 147.12 | 121.93 |
| Omotosho | 84.59 | 75.97 | 2,031.00 | 1,848.49 | 184.82 | 168.21 |
| Omotosho NIPP | 14.09 | 0.11 | 285.72 | 0.00 | 26.00 | 0.00 |
| Paras | 88.50 | 92.78 | 1,782.68 | 2,077.68 | 162.22 | 189.07 |
| Rivers IPP | 43.10 | 65.38 | 1,038.57 | 1,310.25 | 94.51 | 119.23 |
| Sapele GT NIPP | 17.41 | 0.24 | 265.17 | 0.00 | 24.13 | 0.00 |

* * *

Appendix III: Monthly energy offtake and energy billed by DisCos in 2024/Q1 and 2024/Q2

| DisCos | Energy Offtake(GWh) |  |  |  |  |  | Energy Billed(GWh) |  |  |  |  | Billing Efficiency |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1(%) | 2024/Q2(%) |  |
| Jan | Feb | Mar | Apr | May | June | Jan | Feb | Mar | Apr | May | June |  |  |  |
| Abuja | 403 | 329 | 387 | 361 | 399 | 329 | 290 | 277 | 279 | 277 | 276 | 282 | 75.60 | 76.68 |
| Benin | 213 | 174 | 189 | 170 | 202 | 191 | 183 | 145 | 161 | 143 | 167 | 160 | 84.87 | 83.35 |
| Eko | 357 | 262 | 327 | 302 | 353 | 287 | 322 | 236 | 291 | 273 | 314 | 258 | 89.75 | 89.70 |
| Enugu | 209 | 161 | 182 | 163 | 169 | 160 | 165 | 138 | 141 | 149 | 167 | 153 | 80.46 | 95.33 |
| Ibadan | 265 | 291 | 282 | 243 | 310 | 264 | 254 | 220 | 242 | 211 | 276 | 237 | 85.54 | 88.75 |
| Ikeja | 414 | 317 | 387 | 373 | 417 | 347 | 321 | 267 | 321 | 308 | 336 | 293 | 81.26 | 82.47 |
| Jos | 137 | 118 | 140 | 114 | 107 | 112 | 111 | 92 | 97 | 83 | 79 | 80 | 76.04 | 72.76 |
| Kaduna | 154 | 135 | 155 | 140 | 157 | 146 | 81 | 84 | 86 | 86 | 101 | 93 | 56.66 | 63.07 |
| Kano | 155 | 133 | 152 | 143 | 167 | 134 | 116 | 103 | 111 | 103 | 122 | 106 | 74.93 | 74.63 |
| Port Harcourt | 195 | 165 | 171 | 171 | 187 | 173 | 163 | 138 | 150 | 144 | 155 | 145 | 85.01 | 83.56 |
| Yola | 75 | 67 | 71 | 48 | 28 | 48 | 66 | 58 | 59 | 46 | 26 | 44 | 86.03 | 93.94 |
| All DisCos | 2,577 | 2,149 | 2,444 | 2,227 | 2,497 | 2,190 | 2,072 | 1,759 | 1,938 | 1,824 | 2,019 | 1,851 | 80.45 | 82.34 |

* * *

Appendix IV: Monthly revenue performance and collection efficiency by DisCos in 2024/Q1 and 2024/Q2

| DisCos | Total Billing(N'Billion) |  |  |  |  |  | Revenue Collected(N'Billion) |  |  |  |  | Collection Efficiency |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1(%) | 2024/Q2(%) |  |
| Jan | Feb | Mar | Apr | May | June | Jan | Feb | Mar | Apr | May | June |  |  |  |
| Abuja | 19.03 | 18.66 | 20.60 | 28.70 | 27.84 | 27.94 | 15.55 | 16.28 | 16.77 | 22.92 | 22.97 | 24.29 | 83.36 | 83.07 |
| Benin | 10.89 | 8.82 | 9.67 | 13.29 | 14.23 | 13.71 | 7.61 | 7.31 | 7.53 | 11.03 | 10.65 | 12.27 | 76.39 | 82.35 |
| Eko | 21.25 | 15.83 | 19.43 | 27.41 | 30.87 | 27.16 | 16.30 | 15.71 | 16.72 | 24.93 | 23.92 | 26.37 | 86.24 | 88.05 |
| Enugu | 9.75 | 8.15 | 8.48 | 12.02 | 15.09 | 13.75 | 7.37 | 6.95 | 6.90 | 9.09 | 10.18 | 11.11 | 80.45 | 74.35 |
| Ibadan | 15.28 | 14.03 | 15.46 | 18.27 | 23.91 | 20.82 | 10.03 | 10.26 | 10.05 | 14.50 | 14.74 | 15.02 | 67.78 | 70.25 |
| Ikeja | 20.13 | 17.08 | 18.63 | 29.99 | 32.31 | 29.96 | 17.59 | 19.58 | 20.70 | 29.40 | 26.92 | 31.02 | 103.61 | 94.67 |
| Jos | 8.11 | 6.68 | 7.05 | 8.92 | 7.15 | 7.99 | 3.88 | 4.88 | 4.52 | 6.05 | 4.71 | 4.96 | 60.81 | 65.37 |
| Kaduna | 4.50 | 4.31 | 4.77 | 8.07 | 8.63 | 7.54 | 3.24 | 3.16 | 3.19 | 5.01 | 4.67 | 5.01 | 70.66 | 60.62 |
| Kano | 7.39 | 6.90 | 7.28 | 12.53 | 13.25 | 11.54 | 5.05 | 4.35 | 4.19 | 6.66 | 6.83 | 8.41 | 63.09 | 58.71 |
| Port Harcourt | 10.04 | 8.50 | 9.14 | 14.01 | 14.36 | 13.64 | 6.62 | 6.52 | 7.24 | 10.78 | 10.35 | 11.46 | 73.66 | 77.59 |
| Yola | 4.42 | 4.04 | 4.10 | 3.54 | 1.98 | 3.08 | 1.99 | 1.95 | 1.50 | 1.10 | 1.81 | 1.87 | 43.03 | 55.67 |
| All DisCos | 130.83 | 113.05 | 124.66 | 176.79 | 189.65 | 177.18 | 95.26 | 97.01 | 99.33 | 141.51 | 137.80 | 151.83 | 79.11 | 79.31 |

* * *

Appendix V: DisCos monthly invoices & remittances to NBET in 2024/Q1 and 2024/Q2

| DisCos | Invoice(N' Billion) |  |  |  |  |  | Remittance(N' Billion) |  |  |  |  | Remittance Performance |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1(%) | 2024/Q2(%) |  |
| Jan | Feb | Mar | Apr | May | June | Jan | Feb | Mar | Apr | May | June |  |  |  |
| Abuja | 5.67 | 4.62 | 5.31 | 18.14 | 19.76 | 19.81 | 5.69 | 4.62 | 5.31 | 15.59 | 16.20 | 16.18 | 100 | 83 |
| Benin | 1.73 | 1.44 | 1.56 | 7.93 | 9.32 | 10.23 | 1.75 | 1.44 | 1.56 | 7.21 | 6.38 | 8.32 | 100 | 80 |
| Eko | 4.63 | 3.46 | 4.19 | 16.59 | 19.13 | 18.82 | 4.64 | 3.46 | 4.19 | 16.59 | 18.09 | 19.17 | 100 | 99 |
| Enugu | 1.02 | 0.69 | 0.76 | 6.77 | 8.23 | 9.17 | 1.04 | 0.69 | 0.76 | 5.21 | 6.31 | 7.51 | 100 | 79 |
| Ibadan | 2.82 | 2.42 | 2.60 | 11.07 | 13.74 | 13.95 | 2.86 | 2.42 | 2.60 | 9.87 | 9.44 | 10.18 | 100 | 76 |
| Ikeja | 4.75 | 3.66 | 4.38 | 20.29 | 22.38 | 22.39 | 4.79 | 3.66 | 4.38 | 16.57 | 17.04 | 18.08 | 100 | 79 |
| Jos | 0.81 | 0.73 | 0.81 | 4.48 | 3.40 | 4.00 | 0.81 | 0.73 | 0.81 | 3.59 | 2.17 | 2.08 | 100 | 66 |
| Kaduna | 0.43 | 0.40 | 0.44 | 5.69 | 6.63 | 6.92 | 0.26 | 0.27 | 0.15 | 1.81 | 1.81 | 1.99 | 54 | 29 |
| Kano | 0.79 | 0.69 | 0.76 | 6.11 | 7.37 | 6.82 | 0.80 | 0.69 | 0.74 | 4.17 | 4.11 | 5.92 | 100 | 70 |
| Port Harcourt | 1.51 | 1.30 | 1.39 | 7.34 | 7.88 | 8.50 | 1.52 | 1.30 | 1.39 | 6.15 | 6.76 | 6.32 | 100 | 81 |
| Yola | 0.06 | 0.05 | 0.06 | 0.80 | 0.02 | 0.05 | 0.66 | 0.55 | 0.58 | 0.27 | 0.14 | 0.55 | 100 | 111 |
| All DisCos | 24.23 | 19.46 | 22.26 | 105.21 | 117.88 | 120.67 | 24.24 | 19.33 | 21.95 | 87.02 | 88.50 | 96.34 | 99 | 79 |

Notes: 1. Where the remittance by a DisCo for a given period is more than the invoice received (Remittance performance >100%), it reflects payment for outstanding bills/arrears
2\. All data is based on MRO/DRO

* * *

Appendix VI: DisCos monthly invoices & remittances to MO in 2024/Q1 and 2024/Q2

| DisCos | Invoice(N' Billion) |  |  |  |  |  | Remittance(N' Billion) |  |  |  |  |  | Remittance Performance2024Q1(%) | 2024Q2(%) |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| 2024/Q1 |  |  | 2024/Q2 |  |  | 2024/Q1 |  |  | 2024/Q2 |  |  |  |  |  |
| Jan | Feb | Mar | Apr | May | June | Jan | Feb | Mar | Apr | May | June |  |  |  |
| Abuja | 2.33 | 2.29 | 2.86 | 3.07 | 3.54 | 2.53 | 2.28 | 1.77 | 3.27 | 2.64 | 3.95 | 1.93 | 98 | 93 |
| Benin | 1.26 | 1.18 | 1.48 | 1.44 | 1.77 | 1.31 | 1.16 | 0.84 | 1.62 | 1.31 | 1.59 | 0.97 | 92 | 86 |
| Eko | 2.10 | 1.81 | 2.45 | 2.64 | 2.14 | 2.14 | 2.01 | 1.34 | 2.73 | 2.55 | 3.21 | 0.87 | 96 | 96 |
| Enugu | 1.23 | 1.11 | 1.38 | 1.38 | 1.61 | 1.20 | 1.18 | 0.84 | 1.56 | 1.06 | 1.56 | 0.89 | 96 | 84 |
| Ibadan | 1.83 | 1.79 | 2.15 | 2.02 | 2.64 | 1.83 | 1.83 | 1.42 | 2.52 | 1.81 | 2.60 | 1.18 | 100 | 86 |
| Ikeja | 2.42 | 2.15 | 2.85 | 3.15 | 3.53 | 2.45 | 2.35 | 1.64 | 3.88 | 2.58 | 3.67 | 1.85 | 106 | 89 |
| Jos | 0.83 | 0.91 | 1.09 | 1.00 | 1.24 | 0.94 | 0.79 | 0.61 | 1.23 | 0.80 | 0.90 | 0.21 | 95 | 63 |
| duna | 0.92 | 0.93 | 1.19 | 1.18 | 1.40 | 1.03 | 0.53 | 0.49 | 0.42 | 0.38 | 0.31 | 0.10 | 46 | 22 |
| Kano | 0.90 | 0.87 | 1.16 | 1.19 | 1.44 | 0.87 | 0.84 | 0.63 | 1.28 | 0.81 | 1.00 | 0.70 | 94 | 72 |
| Port Harcourt | 1.17 | 1.14 | 1.37 | 1.44 | 1.49 | 1.13 | 1.10 | 0.85 | 1.54 | 1.20 | 1.78 | 0.74 | 95 | 92 |
| Yola | 0.88 | 0.36 | 0.52 | 0.40 | 0.20 | 0.43 | 0.89 | 0.27 | 0.93 | 0.13 | 1.10 | 0.33 | 46 | 150 |
| All DisCos | 15.10 | 14.71 | 18.50 | 18.90 | 21.01 | 15.86 | 14.16 | 10.78 | 20.16 | 15.26 | 21.66 | 9.86 | 93 | 84 |

Notes: 1. Where the remittance by a DisCo for a given period is more than the invoice received (Remittance performance >100%), it reflects payment for outstanding bills/arrears

* * *

Appendix VII: Domestic and international bilateral customers invoices & remittances to MO in 2024/Q2

|  | April-24 |  | May-24 |  | June-24 |  | 2024/Q2 |  | 2024/Q2 | Other Remittances(million) |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | Invoice(million) | Remittance(million) | RemittancePerformance(%) |  |  |
| International Customers |  |  |  |  |  |  |  |  |  |  |
| ARAS-SBEE($) | 1.21 | 1.21 | 1.85 | 1.85 | 1.23 | 0.00 | 4.29 | 3.06 | 71.21 | 3.73 |
| ANSCORP-SBEE($) | 1.96 | 1.96 | 1.57 | 1.57 | 0.70 | 0.70 | 4.25 | 4.25 | 100.00 | 4.45 |
| AINSTREAM-NIGELEC($) | 1.20 | 1.20 | 1.30 | 1.30 | 1.09 | 0.00 | 3.59 | 2.50 | 69.72 | 4.71 |
| DUKPANI-CEET($) | 1.47 | 0.00 | 1.14 | 0.00 | 0.85 | 0.00 | 3.47 | 0.00 | 0.00 | 3.76 |
| Total | 5.86 | 4.38 | 5.89 | 4.75 | 3.90 | 0.71 | 15.60 | 9.81 | 62.88 | 16.65 |
| Maternal Customers |  |  |  |  |  |  |  |  |  |  |
| STM/INNER GALAXY(N) | 369.27 | 369.27 | 449.20 | 449.20 | 391.31 | 391.31 | 1,209.78 | 1,209.78 | 100.00 | 1,147.67 |
| STM/KAM IND.(N) |  |  |  |  |  |  |  |  |  |  |
| STM/KAM INT.(N) |  |  |  |  |  |  |  |  |  |  |
| AINSTREAM/PRISM(N) |  |  |  |  |  |  |  |  |  |  |
| STM ZEBERCED(N) |  |  |  |  |  |  |  |  |  |  |
| STM/ADFV(N) |  |  |  |  |  |  |  |  |  |  |
| DPHC/WEEWOOD(N) | 32.72 | 0.00 | 37.45 | 0.00 | 29.61 | 0.00 | 99.78 | 0.00 | 0.00 | 0.00 |
| ORTH SOUTH/STAR P(N) | 8.18 | 8.12 | 13.88 | 0.00 | 9.51 | 9.51 | 31.57 | 17.69 | 56.03 | 23.55 |
| ANS AMADI/OAU(N) | 11.82 | 0.73 | 13.47 | 0.00 | 9.45 | 0.00 | 34.74 | 0.73 | 2.10 | 95.33 |
| ANS AMADI(FMPI)(N) |  |  |  |  |  |  |  |  |  |  |
| DPHC/SUNFLAG(N) | 13.77 | 0.00 | 15.59 | 0.00 | 12.92 | 0.00 | 42.28 | 0.00 | 0.00 | 0.00 |
| MOTOSHO II/PULKIT(N) |  |  |  |  |  |  |  |  |  |  |
| LAOJI GENCO/APLE(N) | 140.45 | 0.00 | 169.31 | 0.00 | 141.80 | 0.00 | 451.56 | 0.00 | 0.00 | 0.00 |
| AOPEX/KAM INT(N) | 26.39 | 26.39 | 41.33 | 41.33 | 38.39 | 0.00 | 106.11 | 67.72 | 63.82 | 0.00 |
| AOPEX/KAM STEEL(N) |  |  |  |  |  |  |  |  |  |  |

* * *

Appendix VIII: Meter installation for all Frameworks (MAP, NMMP, Vendor and DisCo Financed)

| DisCos | Meters contracted | Meters installed in 2019 | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Total installations since 2019 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Aba | 24,000 | - | - | - | - | 9,917 | 7,817 | 8,784 | 26,518 |
| Abuja | 1,000,475 | 63,925 | 105,253 | 87,987 | 83,494 | 105,154 | 21,493 | 11,733 | 479,039 |
| Benin | 664,646 | 1,169 | 11,154 | 72,838 | 6,771 | 34,344 | 10,455 | 3,510 | 140,241 |
| Eko | 283,178 | 5,422 | 32,353 | 64,618 | 44,577 | 36,484 | 4,637 | 810 | 189,260 |
| Enugu | 713,926 | 17,410 | 54,603 | 96,836 | 57,751 | 73,256 | 13,932 | 4,241 | 318,279 |
| Ibadan | 1,106,294 | 4,771 | 38,403 | 94,309 | 146,044 | 139,138 | 25,551 | 5,828 | 477,576 |
| Ikeja | 1,186,114 | 22,876 | 160,469 | 125,460 | 145,364 | 151,197 | 27,795 | 9,076 | 642,921 |
| Jos | 606,096 | 15 | 4,673 | 88,827 | 19,190 | 12,937 | 3,649 | 457 | 128,895 |
| Kaduna | 519,152 | 43 | 8,258 | 17,942 | 34,385 | 10,039 | 3,027 | 2,450 | 76,945 |
| Kano | 562,747 | 22 | 3,314 | 80,969 | 3,476 | 2,056 | 199 | 474 | 90,510 |
| Port Harcourt | 220,044 | 7,775 | 36,546 | 92,543 | 33,549 | 48,989 | 6,278 | 1,825 | 227,504 |
| Yola | 749,376 | - | 478 | 5,955 | 30,386 | 19,295 | 831 | - | 56,555 |
| Total | 7,612,048 | 123,428 | 455,504 | 828,284 | 604,987 | 642,806 | 125,664 | 49,188 | 2,854,243 |

* * *

Appendix IX: Meter installation through the NMMP Framework as of 2024/Q2

| DisCos | Meters contracted | Meters installed in 2019 | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Total installations since 2020 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Aba | - | - | - | - | - | - | - | - | - |
| Abuja | 100,475 | - | 17,777 | 82,698 | - | - | - | - | 100,475 |
| Benin | 90,870 | - | - | 71,734 | 6,108 | 2,314 | - | - | 80,156 |
| Eko | 79,178 | - | 69 | 56,915 | 15,694 | 6,328 | - | - | 79,010 |
| Enugu | 92,381 | - | - | 91,238 | 274 | - | - | - | 91,512 |
| Ibadan | 117,379 | - | 4,985 | 93,761 | 18,626 | 7 | - | - | 117,379 |
| Ikeja | 111,703 | - | 24 | 111,679 | - | - | - | - | 111,703 |
| Jos | 96,096 | - | - | 86,474 | 8,709 | 529 | - | - | 95,765 |
| Kaduna | 69,152 | - | 1,621 | 15,175 | 30,724 | 99 | 24 | 264 | 47,907 |
| Kano | 87,747 | - | 11 | 80,969 | 2,500 | - | - | - | 83,480 |
| Port | 82,720 | - | 14,212 | 68,508 | - | - | - | - | 82,720 |
| Harcourt |  |  |  |  |  |  |  | - |  |
| Yola | 85,376 | - | 88 | 5,955 | 30,386 | 16,574 | - | - | 53,003 |
| Total | 1,013,076 | - | 38,787 | 765,106 | 113,021 | 25,851 | 24 | 264 | 943,110 |

* * *

Appendix X: Meter installation through the MAP Framework as of 2024/Q2

| DisCos | Meters contracted | Meters installed in 2019 | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Total installations since 2019 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Aba | 12,000 | - | - | - | - | 8,475 | 1,346 | 301 | 10,122 |
| Abuja | 900,000 | 63,925 | 87,476 | 5,289 | 82,293 | 103,200 | 21,440 | 10,717 | 374,340 |
| Benin | 573,776 | 1,169 | 11,154 | 1,104 | 422 | 29,181 | 10,419 | 3,510 | 56,959 |
| Eko | 204,000 | 5,422 | 32,298 | 7,703 | 28,883 | 30,156 | 4,637 | 810 | 110,248 |
| Enugu | 621,545 | 17,212 | 54,752 | 5,405 | 57,372 | 73,256 | 13,932 | 4,241 | 226,170 |
| Ibadan | 988,915 | 4,771 | 33,418 | 548 | 127,418 | 125,752 | 25,551 | 5,828 | 323,286 |
| Ikeja | 1,074,411 | 23,265 | 160,616 | 13,781 | 145,364 | 147,741 | 25,281 | 5,732 | 521,904 |
| Jos | 500,000 | 13 | 3,769 | 27 | 3,317 | 12,151 | 1,165 | 457 | 20,899 |
| Kaduna | 450,000 | 129 | 7,352 | 2,767 | 3,565 | 9,887 | 3,003 | 2,186 | 28,889 |
| Kano | 475,000 | 22 | 3,303 | - | 976 | 2,056 | 199 | 378 | 6,934 |
| Port Harcourt | 137,324 | 7,775 | 22,334 | 24,035 | 33,549 | 48,989 | 6,278 | 1,825 | 144,784 |
| Yola | 664,000 | - | - | - | - | 2,721 | 831 | - | 3,512 |
| Total | 6,588,971 | 123,703 | 416,472 | 60,659 | 483,159 | 593,565 | 114,082 | 35,985 | 1,828,047 |

* * *

Appendix XI: Meter installation through Vendor and DisCo Finance Frameworks as of 2024/Q2

| DisCos | Vendor Finance |  |  |  |  | DisCo Finance |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Total installations | Meters installed in 2019 | Meters installed in 2020 | Meters installed in 2021 | Meters installed in 2022 | Meters installed in 2023 | Meters installed in 2024/Q1 | Meters installed in 2024/Q2 | Total installations since 2019 |  |  |
| Aba | - | 1,442 | 6,471 | 8,483 | 16,396 |  |  |  |  |  | - | - | - | - |
| Abuja | 1,201 | 1,954 | 53 | 1,016 | 4,224 | - | - | - | - | - | - | - | - | - |
| Benin | 241 | 2,849 | 36 | - | 3,126 | - | - | - | - | - | - | - | - | - |
| Eko | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
| Enugu | - | - | - | - | - | 106 | 193 | 193 | 105 | - | - | - | - | 597 |
| Ibadan | - | - | - | - | - | - | - | - | - | 13,379 | - | - | - | 63,669 |
| Ikeja | - | 3,456 | 2,514 | 3,344 | 9,314 | - | - | - | - | - | - | - | - | - |
| Jos | - | - | - | - | - | - | - | 2,326 | 7,164 | 257 | 2,484 | - | 11,974 |  |
| Kaduna | - | - | - | - | - | - | - | - | 96 | 53 | - | - | 149 |  |
| Kano | - | - | - | - | - | - | - | - | - | - | - | 96 | 96 |  |
| Port Harcourt | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
| Yola | - | - | - | - | - | - | - | - | - | - | - | - | - | - |
| Total | 1,442 | 5,840 | 9,074 | 12,843 | 33,060 | 106 | 193 | 2,519 | 7,365 | 53 | 2,484 | 96 | 76,485 |  |

* * *

Appendix XII: Category of complaints received by DisCos in 2024/Q2

| DisCos | Complaints Received | Complaint Categories |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others |  |  |
| Aba | 4,279 | 2,957 | 83 | 38 | - | 500 | 75 | 9 | 617 |
| Abuja | 25,893 | 10,708 | 2,527 | 273 | 301 | 586 | 1,271 | 0 | 10,227 |
| Benin | 6,020 | 157 | 633 | 47 | 101 | 1,085 | 86 | 9 | 3,902 |
| Eko | 53,377 | 21,897 | 7,527 | 727 | 0 | 4,947 | 0 | 0 | 18,279 |
| Enugu | 22,020 | 14,151 | 2,268 | 353 | 7 | 3,245 | 224 | 210 | 1,562 |
| Ibadan | 51,718 | 30,301 | 1,463 | 176 | 0 | 17518 | 105 | 0 | 2,155 |
| Ikeja | 20,536 | 10,599 | 1,530 | 241 | 47 | 2,492 | 92 | 3,011 | 2,524 |
| Jos | 20,013 | 9,165 | 2,349 | 453 | 1 | 5,884 | 150 | 1 | 2,010 |
| Kaduna | 6,546 | 1,976 | 3,493 | 476 | 12 | 347 | 151 | 1 | 90 |
| Kano | 18,073 | 16,719 | 592 | 53 | 0 | 637 | 43 | 0 | 29 |
| Port Harcourt | 56,928 | 20,655 | 5,111 | 1,783 | 0 | 3,825 | 579 | 122 | 24,853 |
| Yola | 2,038 | 1,138 | 603 | 178 | 1 | 12 | 13 | 0 | 93 |
| All DisCos | 287,441 | 140,423 | 28,179 | 4,798 | 470 | 41,078 | 2,789 | 3,363 | 66,341 |

* * *

Appendix XIII: Category of complaints received at the Commission’s CCU in 2024/Q2

| DisCos | Complaints Received | Complaints Resolved | Credit Adjustment(N'000) | Complaint Categories |  |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | Band | Non-compliance |  |  |  |  |
| Aba | 0 | 0 | - | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 |
| Abuja | 137 | 5 | - | 10 | 13 | 1 | 1 | 34 | 4 | 0 | 6 | 65 | 3 |
| Benin | 5 | 0 | 102,325.54 | 0 | 1 | 0 | 0 | 3 | 0 | 0 | 0 | 0 | 1 |
| Eko | 1 | 2 | - | 0 | 0 | 0 | 0 | 0 | 4 | 0 | 1 | 4 | 1 |
| Enugu | 11 | 7 | 1,265.02 | 0 | 3 | 0 | 0 | 1 | 0 | 0 | 1 | 0 | 6 |
| Ibadan | 20 | 1 | - | 3 | 3 | 0 | 0 | 1 | 13 | 0 | 0 | 0 | 0 |
| Ikeja | 17 | 1 | 658.38 | 2 | 0 | 0 | 0 | 5 | 2 | 0 | 1 | 3 | 4 |
| Jos | 1 | 0 | - | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 |
| Kaduna | 2 | 0 | - | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 0 |
| Kano | 1 | 0 | - | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 0 |
| Port Harcourt | 3 | 1 | - | 1 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 1 | 0 |
| Yola | 2 | 1 | - | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 0 | 1 | 0 |
| All DisCos | 212 | 18 | 104,248.96 | 17 | 21 | 1 | 1 | 49 | 20 | 1 | 13 | 72 | 17 |

* * *

Appendix XIV: Category of complaints received at the NESI Call Centre in 2024/Q2

| DisCos | Complaints Received | Complaints Resolved | Credit Adjustment(N'000) | Complaint Categories |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Metering | Interruption | Voltage | Loadshedding | Billing | Disconnection | Delay | Others | Band |  |  |  |  |
| Aba | 16 | 5 | - | 1 | 4 | 0 | 0 | 5 | 2 | 0 | 0 | 4 |
| Abuja | 714 | 99 | - | 31 | 114 | 7 | 0 | 113 | 16 | 1 | 9 | 423 |
| Benin | 101 | 22 | 3,617.59 | 15 | 39 | 5 | 0 | 35 | 4 | 0 | 0 | 3 |
| Eko | 1,039 | 189 | 3,577.67 | 216 | 259 | 15 | 1 | 266 | 32 | 3 | 12 | 235 |
| Enugu | 153 | 60 | 1,970.49 | 27 | 27 | 5 | 1 | 53 | 12 | 1 | 1 | 26 |
| Ibadan | 250 | 41 | 48,734.74 | 63 | 48 | 0 | 1 | 62 | 9 | 0 | 6 | 62 |
| Ikeja | 1,688 | 491 | 20,663.57 | 383 | 201 | 10 | 8 | 731 | 101 | 11 | 31 | 211 |
| Jos | 58 | 23 | - | 9 | 15 | 4 | 0 | 7 | 1 | 0 | 0 | 22 |
| Kaduna | 39 | 7 | - | 3 | 9 | 1 | 0 | 10 | 1 | 0 | 0 | 15 |
| Kano | 18 | 8 | - | 3 | 9 | 1 | 0 | 2 | 2 | 0 | 0 | 1 |
| Port Harcourt | 164 | 32 | - | 24 | 50 | 8 | 0 | 42 | 9 | 1 | 3 | 27 |
| Yola | 17 | 5 | - | 0 | 5 | 1 | 0 | 6 | 1 | 0 | 1 | 3 |
| All DisCos | 4,257 | 982 | 29,878.07 | 775 | 780 | 57 | 11 | 1,332 | 190 | 17 | 63 | 1,032 |

* * *

Appendix XV: List and addresses of NERC Forum Offices as of June 2024

| S/N | Forum Office | Location | Telephone | Email |
| --- | --- | --- | --- | --- |
| 1 | Abakaliki, Ebonyi State | 3, Ezekua Crescent, Off Nsugbe Street, Abakaliki Ebonyi State | 9037808590 | [abakalikiforum@nerc.gov.ng](mailto:abakalikiforum@nerc.gov.ng) |
| 2 | Abeokuta, Ogun State | 31 First Avenue, Ibara Housing Estate, Ibrar GRA, Abeokuta | 9139381008 | [abekaukiforum@nerc.gov.ng](mailto:abekaukiforum@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, Ekiit State | Km 5, Iwokoro Road, Ado Ekiti, Ekiit State | 9169978242 | [ado-ekitiforum@nerc.gov.ng](mailto:ado-ekitiforum@nerc.gov.ng) |
| 5 | Asaba, Delta State | Denis Osadebe Way, Beside Mobile Filling Station, Asaba, Delta State | 9062277247 | [asabaforum@nerc.gov.ng](mailto:asabaforum@nerc.gov.ng) |
| 6 | Awka, Anambra State | Plot 80, Aroma Junction Layout, Opp, CBN, Awka, Anambra State | 9037808594 | [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, Akpapkova Street, Benin City, Eda State | 9037808592 | [beninferorum@nerc.gov.ng](mailto:beninferorum@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, MCC 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 | [ekoferorum@nerc.gov.ng](mailto:ekoferorum@nerc.gov.ng) |
| 13 | Enugu, Enugu State | John Anichukwu Close, Plot 7 Mkpkiti 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 | 8140404079 | [gombeforum@nerc.gov.ng](mailto:gombeforum@nerc.gov.ng) |
| 15 | Gusau, Zamfara State | 2 Canteen Daiji, 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 | Ikaja, Lagos State | 199, Obafetmi Awolowo Way, Alausa, Ikaja, Lagos State | 8106807298 | [ikajiaforum@nerc.gov.ng](mailto:ikajiaforum@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 | [josfonurm@nerc.gov.ng](mailto:josfonurm@nerc.gov.ng) |
| 20 | Kaduna, Kaduna State | 22, Ahmdu Bello Way, Opposite NNDC Building, Kaduna, Kaduna State | 8106807299 | [kadunaiforum@nerc.gov.ng](mailto:kadunaiforum@nerc.gov.ng) |
| 21 | Kano, Kano State | 2, Miller Road, Bompai, Nasarawa G.R.A, Kano, Kano State | 8146862222 | [kanonairoforum@nerc.gov.ng](mailto:kanonairoforum@nerc.gov.ng) |
| 22 | Katsina, Katsina State | 7, Abuja Crescent, Off Hassan Usman Katsina Road, Katsina, Katsina State | 7031704821 | [katsinaiforum@nerc.gov.ng](mailto:katsinaiforum@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 | Lokoja, Kogi State | Hassan Kastina Rd, Opp. State Civil Service Commission, Zone 8 Police HQ, Lokoja, Kogi State. | 9062924601 | [lokojaforum@nerc.gov.ng](mailto:lokojaforum@nerc.gov.ng) |

* * *

Appendix XVI: Appeals handled by Forum Offices in 2024/Q1 and 2024/Q2

| S/N | Forum Offices | 2024/Q1 |  |  |  | 2024/Q2 |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Appeals Received | Appeals Resolved | Appeals Pending | Appeals Received | Appeals Resolved | Appeals Pending | Resolution Rate |  |  |  |
| 1 | Abakaliki, Ebonyi State | 41 | 17 | 21 | 41.46% | 66 | 42 | 18 | 63.64% |
| 2 | Abeokuta, Ogun State | 122 | 42 | 33 | 34.43% | 152 | 14 | 63 | 9.21% |
| 3 | Abuja, FCT | 35 | 27 | 8 | 77.14% | 45 | 30 | 15 | 66.67% |
| 4 | Ado-Ekiti | 16 | 10 | 6 | 62.50% | 19 | 11 | 8 | 57.89% |
| 5 | Asaba, Delta State | 72 | 50 | 21 | 69.44% | 51 | 34 | 15 | 66.67% |
| 6 | Awka, Anambra State | 101 | 56 | 45 | 55.45% | 149 | 103 | 46 | 69.13% |
| 7 | Bauchi, Bauchi State | 6 | 6 | 0 | 100.00% | 3 | 3 | 0 | 100.00% |
| 8 | Benin, Eda State | 55 | 39 | 16 | 0.00% | 60 | 53 | 7 | 0.00% |
| 9 | Calabar, C/Rivers State | 3 | 3 | 0 | 0.00% | 26 | 19 | 7 | 73.08% |
| 10 | Dutse, Jigawa State | 27 | 17 | 10 | 62.96% | 4 | 2 | 2 | 50.00% |
| 11 | Eko, Lagos State | 7 | 5 | 2 | 71.43% | 218 | 155 | 63 | 71.10% |
| 12 | Enugu, Enugu State | 207 | 159 | 45 | 76.81% | 204 | 83 | 76 | 40.69% |
| 13 | Gombe, Gombe State | 201 | 82 | 68 | 40.80% | 13 | 1 | 12 | 7.69% |
| 14 | Gusau, Zamfara State | 12 | 0 | 11 | 0.00% | 10 | 10 | 0 | 100.00% |
| 15 | Ibadan, Oyo State | 8 | 2 | 6 | 25.00% | 104 | 65 | 39 | 62.50% |
| 16 | Ikewa, Lagos State | 142 | 114 | 28 | 80.28% | 642 | 320 | 322 | 49.84% |
| 17 | Ilorin, Kwara State | 537 | 240 | 297 | 44.69% | 96 | 62 | 34 | 64.58% |
| 18 | Jas, Plateau State | 60 | 26 | 34 | 43.33% | 17 | 13 | 4 | 76.47% |
| 19 | Kaduna, Kaduna State | 17 | 12 | 5 | 70.59% | 28 | 17 | 0 | 60.71% |
| 20 | Kano, Kano State | 22 | 13 | 7 | 59.09% | 23 | 17 | 0 | 73.91% |
| 21 | Katsina, Katsina State | 26 | 15 | 7 | 57.69% | 4 | 3 | 1 | 75.00% |
| 22 | Kebbi, Kebbi State | 3 | 1 | 2 | 33.33% | 4 | 2 | 2 | 50.00% |

* * *

Appendix XVII: Category of appeals received by Forum Offices in 2024/Q1 and 2024/Q2

| Forum Office | 2024/Q1 |  |  |  |  |  |  | 2024/Q2 |  |  |  |  |  |  |  |  |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others | Billing | Disconnection | Con. Delay | Interruption | Metering | Load Shedding | Voltage | Others |  |
| Abakaliki, Ebonyi State | 25 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 43 | 0 | 0 | 1 | 1 | 0 | 0 | 1 |
| Abeokuta, Ogun State | 48 | 1 | 0 | 1 | 16 | 5 | 0 | 9 | 60 | 2 | 0 | 1 | 22 | 19 | 0 | 1 |
| Abuja, FCT | 1 | 0 | 0 | 0 | 22 | 0 | 0 | 4 | 4 | 0 | 0 | 0 | 30 | 0 | 0 | 1 |
| Ado-Ekiti, Ekiti State | 10 | 0 | 0 | 0 | 1 | 0 | 0 | 3 | 7 | 0 | 0 | 0 | 5 | 0 | 0 | 1 |
| Asaba, Delta State | 19 | 3 | 0 | 0 | 3 | 0 | 0 | 3 | 21 | 0 | 0 | 0 | 5 | 0 | 0 | 1 |
| Awka, Anambra State | 68 | 5 | 0 | 0 | 13 | 0 | 0 | 1 | 81 | 6 | 0 | 0 | 17 | 0 | 0 | 1 |
| 4 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 1 | 0 | 0 | 0 | 2 | 0 | 0 | 1 |  |
| 24 | 1 | 0 | 1 | 4 | 0 | 1 | 3 | 36 | 1 | 0 | 0 | 2 | 0 | 0 | 1 |  |
| B/Kebbi, Kebbi State | 0 | 0 | 0 | 0 | 1 | 0 | 0 | 2 | 1 | 0 | 0 | 0 | 0 | 0 | 0 | 1 |
| Colabar, C/Rivers State | 11 | 1 | 0 | 1 | 4 | 0 | 0 | 3 | 7 | 3 | 0 | 0 | 4 | 0 | 0 | 1 |
| Dutse, Jigawa State | 3 | 1 | 0 | 0 | 2 | 0 | 0 | 0 | 2 | 0 | 0 | 0 | 0 | 0 | 0 | 1 |
| Eko, Lagos State | 53 | 13 | 0 | 5 | 73 | 0 | 1 | 7 | 68 | 10 | 0 | 13 | 65 | 0 | 1 | 1 |
| Enugu, Enugu State | 150 | 5 | 0 | 0 | 19 | 0 | 0 | 1 | 107 | 9 | 0 | 0 | 13 | 3 | 0 | 1 |
| Gombe, Gombe State | 4 | 0 | 0 | 0 | 5 | 0 | 1 | 0 | 0 | 0 | 0 | 0 | 2 | 0 | 0 | 1 |
| Gusau, Zamfara State | 1 | 2 | 0 | 0 | 0 | 0 | 0 | 1 | 0 | 2 | 1 | 0 | 1 | 0 | 0 | 1 |

* * *

## SECOND QUARTER 2024 NERC QUARTERLY REPORTS

## \[NIGERIAN ELECTRICITY REGULATORY COMMISSION\]