CHAPTER 7 Transmission Network Development Plantransmission lines and transformers is shown in...
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CHAPTER 7 Transmission Network Development Plan
Transcript of CHAPTER 7 Transmission Network Development Plantransmission lines and transformers is shown in...
CHAPTER 7 Transmission Network
Development Plan
7-1
Chapter 7 Transmission network development plan
7-1 Outline of Transmission Network in Nigeria
7-1-1 Geographical Structure of the Transmission Company of Nigeria (TCN)
TCN has created eight Transmission Planning Regions for better planning.
The actual regions under the field and maintenance services sector are shown in Figure 7-1.1. Since new regions, Abuja Region (FCT (Abuja), Nasarawa and Kogi states) were settled in July, 2018, there are currently nine Transmission Planning Regions.
Source: TCN Figure 7-1.1 Geographical Structure of TCN
The electricity supply to Nigerian consumers is handled by 11 privatized distribution companies, each with its own area, as shown in Figure 7-1.2.
ABUJA REGION
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Source: JICA Study Team Figure 7-1.2 Areas of Distribution Companies in Nigeria
The electricity consumption of the southern DisCos far exceeds their northern equivalents because the former are far more densely populated and most industries are concentrated there.
7-1-2 Existing and Planned Power System and Network Configuration
The two latest maps with the existing, ongoing and planned Nigerian 330 and 132 kV transmission network are shown in Annexes 7.1a and 7.1b (respectively dated January and March, 2018).
The latest version of the single-line diagram of the existing network (dated July, 2016), is shown in Annex 7.1c. TCN has advised that there has not been further updated.
Technical data on transmission lines and transformers is shown in Annexes 7.1d and 7.1e respectively.
The present status of reactors and capacitors installed in the TCN network is summarized in Table 7-1.1 and Table 7-1.2. Introducing additional capacitors, as necessary, takes the status of pre-existing units into consideration, as shown in Table 7-1.2, assuming all faulty and repairable capacitors will, if necessary, be repaired and the others will be commissioned as planned.
Table 7-1.1 Shunt Reactors
S/N Substation Voltage
(kV)
MX
(MVar) Switchable
1 KANO 330 -75.00 Y
2 GOMBE 330 -50.00 Y
3 GOMBE 330 -50.00 Y
4 YOLA 330 -75.00 Y
5 KADUNA 330 -75.00 Y
Benue
MakurdiNo. Disco Location
1 Abuja Electricity Distribution Company Abuja
2 Benin Electricity Distribution Company Benin
3 Eko Electricity Distribution Company Eko
4 Enugu Electricity Distribution Company Enugu
5 Ibadan Electricity Distribution Company Ibadan
6 Ikeja Electricity Distribution Company Ikeja
7 Jos Electricity Distribution Company Jos
8 Kaduna Electricity Distribution Company Kaduna
9 Kano Electricity Distribution Company kano
10 Port Harcourt Electricity Distribution Company Port Harcourt
11 Yola Electricity Distribution Company Yola
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S/N Substation Voltage
(kV)
MX
(MVar) Switchable
6 JOS 330 -75.00 Y
7 JEBBA T.S. 330 -75.00 Y
8 JEBBA T.S. 330 -75.00 Y
9 OSHOGBO 330 -75.00 N
10 BENIN 330 -75.00 Y
11 BENIN 330 -75.00 Y
12 ALAOJI 330 -75.00 Y
13 IKEJA WEST 330 -75.00 Y
14 IKEJA WEST 330 -75.00 Y
15 KATAMPE 330 -75.00 Y
16 MAKURDI 330 -75.00 Y
17 ONITSHA 330 -75.00 Y
18 OKEARO 330 -75.00 Y
19 GOMBE 33 -30.00 Y
20 GOMBE 33 -30.00 Y
21 YOLA 33 -30.00 Y
22 YOLA 33 -30.00 Y
Source: JICA Study Team
Table 7-1.2 Fixed capacitors
S/N Substation Voltage
(kV)
Capacitor
(MVar) Status Planned Action
1 Kumbotso 330 50 In operation
2 Kumbotso 330 50 In operation
3 Akangba A 132 72 Installed but not commissioned yet To be commissioned
4 Akangba B 33 24 Installed but not commissioned yet To be commissioned
5 Akoka 33 24 Installed but not commissioned yet To be commissioned
6 Alausa 33 24 Installed but not commissioned yet To be commissioned
7 Alimoso 33 24 Installed but not commissioned yet To be commissioned
8 Ejigbo 33 24 Installed but not commissioned yet To be commissioned
9 Ijoro 33 24 Installed but not commissioned yet To be commissioned
10 Isolo 33 24 Installed but not commissioned yet To be commissioned
11 Ogba 33 24 Installed but not commissioned yet To be commissioned
12 Otta 33 24 Installed but not commissioned yet To be commissioned
13 Yandev 33 20 Installed but not commissioned yet To be commissioned
14 Ikorodu 33 20 Faulty, mainly due to CB fault Can be repaired
15 Ikorodu 33 20 Faulty, mainly due to CB fault Can be repaired
16 Abeokuta 33 20 Faulty, mainly due to CB fault Can be repaired
17 Abeokuta 33 20 Faulty, mainly due to CB fault Can be repaired
18 Iseyin 33 20 Faulty, mainly due to CB fault Can be repaired
19 Aiyede 33 20 Faulty, mainly due to CB fault Can be repaired
20 Aiyede 33 20 Faulty, mainly due to CB fault Can be repaired
21 Agbara 33 20 Commissioned, can be switched on
22 Ijebuode 33 20 Commissioned, can be switched on
23 Sagamu 33 20 Commissioned, can be switched on
24 Irua 33 20 Faulty, mainly due to CB fault Can be repaired
25 Ilorin 33 20 Faulty, mainly due to CB fault Can be repaired
26 Akure 33 20 Faulty, mainly due to CB fault Can be repaired
27 Awka 33 20 Faulty, mainly due to CB fault Can be repaired
28 Uyo 33 20 Faulty, mainly due to CB fault Can be repaired
29 Effurum 33 20 Faulty, mainly due to CB fault Can be repaired
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S/N Substation Voltage
(kV)
Capacitor
(MVar) Status Planned Action
30 Amkpe 33 20 Faulty, mainly due to CB fault Can be repaired
31 Akwanga 33 20 Faulty, mainly due to CB fault Can be repaired
32 Akwanga 33 20 Faulty, mainly due to CB fault Can be repaired
33 Minna 33 20 Faulty, mainly due to CB fault Can be repaired
34 Minna 33 20 Faulty, mainly due to CB fault Can be repaired
35 Kontagora 33 20 Faulty, mainly due to CB fault Can be repaired
36 Kontagora 33 20 Faulty, mainly due to CB fault Can be repaired
37 Zaria 33 20 Faulty, mainly due to CB fault Can be repaired
38 Zaria 33 20 Faulty, mainly due to CB fault Can be repaired
39 Kaduna Town 33 20 Faulty, mainly due to CB fault Can be repaired
40 Kaduna Town 33 20 Faulty, mainly due to CB fault Can be repaired
41 Dakata 33 20 Faulty, mainly due to CB fault Can be repaired
42 Dakata 33 20 Faulty, mainly due to CB fault Can be repaired
43 Apir 33 20 Faulty, mainly due to CB fault Can be repaired
44 Kumbotso 33 20 Installed but not commissioned yet To be commissioned
45 Okene 33 20 Installed but not commissioned yet To be commissioned
46 Dan-Agundi 33 20 Installed but not commissioned yet To be commissioned
47 Katsina 33 20 Installed but not commissioned yet To be commissioned
48 Ife 33 20 Installed but not commissioned yet To be commissioned
49 Ayede 33 20 Installed but not commissioned yet To be commissioned
50 Ijebu-Ode 33 20 Installed but not commissioned yet To be commissioned
51 Shagamu 33 20 Installed but not commissioned yet To be commissioned
52 Iseyin 33 20 Installed but not commissioned yet To be commissioned
53 Ilorin 33 20 Installed but not commissioned yet To be commissioned
54 Akure 33 20 Installed but not commissioned yet To be commissioned
55 Apo 33 20 Installed but not commissioned yet To be commissioned
56 Apo 33 20 Installed but not commissioned yet To be commissioned
Source: JICA Study Team
7-1-3 Operating Frequency and Voltage Limits
In accordance with the Grid Code and to maintain the security and integrity of the transmission system, it is necessary that the System Operator operate and dispatch the transmission system in such a manner as to provide adequate frequency control and achieve operation within applicable frequency limits at all times.
The nominal system frequency shall be 50 Hz. The National Control Center endeavors to control this to within a narrow operating band of +/- 0.5% from 50 Hz (49.75 – 50.25 Hz), but under system stress the frequency on the power system may vary within the limits of 50 Hz +/- 2.5% (48.75 – 51.25 Hz).
The nominal voltage levels of the transmission and distribution system are 330, 132, 66, 33 and 11 kV respectively. Under normal operation, the limits of the 330 and 132 kV systems are 0.85-1.05 and 0.85-1.10 pu respectively. Under contingency conditions the emergency limits for the same are 0.80-1.10 and 0.80-1.15 pu.
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7-1-4 System Peak Demand and Generation
7-1-4-1 Development of Peak Output and Energy Generated
The installed capacity (less de-commissioned units) in the grid as of December, 2016 was 12,310 MW. In 2016, the plant average MW availability was 7,877 MW, which was 23.07% higher than the 6,401 MW obtained in 2015. The Thermal Station average MW availability contribution was 6,669 MW – exceeding the, 2015 figure of 5,312 MW by 25.53%. The Hydro Station average MW availability was 1208 MW, which exceeded the, 2015 figure of 1,088 MW by 120 MW (11.07%). The maximum daily energy of 109,372 MWh occurred on 2 February, 2016, exceeding the maximum daily energy of 106,825 MWh recorded on 24 November, 2015 by 2,546 MWh (2.38%). The peak generation of 5,074 MW. which was attained on 2 February, 2016 exceeds the peak generation of 4,883 MW recorded on 23 November, 2015 by 190 MW (3.91%).
Peak output of power stations depends on the availability of generation units, water inflow for hydro power plants and gas supply for thermal power plants and not on actual demand. Demand is always much higher than the available generation capacity.
NCC daily operational report on 08.12.2015 shows a Peak Demand Forecast (connected + suppressed load) of 14,630 MW.
The peak generation of 5,074 MW, which was attained on 2 February, 2016 exceeded the peak generation of 4,883 MW recorded on 23 November, 2015 by 190 MW (3.91%).”
In general, only approximately 40% of the estimated demand could be supplied.
NCC’s operational reports show that many generation units are not in operation due to the unavailability of gas. On December 8, 2015 for example, about 1,500 MW of generation capacity were was offline for this reason. The gas supply was interrupted due to sabotage of the pipeline system.
7-1-4-2 Transition of Energy Generation and Peak Demand
Records on annual energy generated and simultaneous national peak demand of electricity show permanent growth with two periods of stagnation/decline.
Figure 7-1.3 and Figure 7-1.4 indicate that periods of stagnation/decline of energy generation and peak demand were offset rapidly in the following years.
Between 1973 and 2016, peak generation increased from 385 to 5,074 MW, i.e. with an average growth rate of about 6.2%. During the same period the annual energy generated increased from 2,493 to 28,412 GWh, i.e. with an average growth rate of about 6%.
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Source: TCN Annual Report, 2016
Figure 7-1.3 Annual Energy Generated
Source: TCN Annual Report, 2016 Figure 7-1.4 National Peak
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GWH ANNUAL ENERGY GENERATED (GWH) 1973 -20163
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9 70
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67 88
7 10
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MW
YEAR
SIMULTANEOUS NATIONAL PEAK (MW ) 1973 -2016
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7-1-4-3 Transmission Losses
The overall transmission losses and substation consumptions amounted to 9.92% of the energy sent out in 2016, as shown in Table 7-1.3. The losses in 2016 were lower than the previous year, signifying a steady decline over the past three years.
Table 7-1.3 Energy balance summary (Dec-Jan, 2016)
Energy generated
(MWh)
Energy sent out
(MWh)
Energy available
for sales, incl distr
losses (MWh)
Transformer
losses and
substations
consumption
(MWh)
Transformer
losses and
substations
consumption (%
of energy sent
out)
Energy available
for sales and distr
losses (% of
energy)
28,532 28,033 25,251 27,821 9.92 90.08
Source: JICA Study Team
7-1-4-4 Existing Generation and Generation Expansion
Based on information provided, the already installed gross power generation capacity is about 13,300 MW, of which some 11,800 MW are noted as net available capacity.
Considering the latest information provided by generating companies, about 9,500 MW (80%) of this capacity should have been available at the end of the year, 2015. However, only 5,900 MW net capacity has been made available, as reflected in the statistics of the National Control Center (NCC).
The reasons for the unavailability include: planned outages for maintenance or forced outages due to technical deficiencies of assets, as well as unplanned unavailability due to fuel supply shortages or sabotage of gas pipelines.
A further analysis of information provided shows that about 20% of the installed generation capacity is based on plants which are 25 or more years old, some of which have efficiency of under 30%.
It is obvious that most of the old thermal power plants are - or will be – subject to more frequent forced outages or long- term planned maintenance outages in the near future. Accordingly, they should be replaced by new and more efficient facilities.
Together with TCN, it was agreed that all existing power plant units not being currently available should be made available by 2020 at the latest, even if currently unavailable for technical reasons.
The Master Plan shows a program for step-by-step modernization of these plants in parallel to implementing new units at existing sites, as well as completely new power plants.
It further shows technical data for all existing and new generation facilities and the respective implementation timetable. Newly proposed power plants are considering diversification of primary energy sources in the form of solar/wind/hydro technology, as well as modern gas- and coal-fired thermal plants.
Installation of new assets will follow the assumed increasing power demand, as well as the need for replacement of existing power generation assets.
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7-1-4-5 Daily Load Curve
Electrical power demand in Nigeria peaks in the evening, between 20:00 and 23:00 hours, while power demand is lowest in the early morning between 03:00 and 05:00 hours.
Figure 7-1.5 Daily Load Curve on 1 October, 2014
7-1-5 Difficulties and Challenges Faced by TCN
7-1-5-1 General
The electric power system of Nigeria has long suffered from a lack of generation capacity which requires permanent load shedding. Furthermore, frequent transmission and distribution system disturbances exacerbate the unreliability of the power system.
The main reasons for power shortages are outages of generation units and a lack of gas to generate power. The gas supply is frequently interrupted due to the pipeline network being sabotaged.
The main concern for the future expansion of generation, however, is the availability of gas for additional generation capacity and the expansion of the gas pipeline network. Currently, most power plants are installed in southern Nigeria close to oil and gas fields. To ensure a reliable and optimally expanded transmission system, there will be a need to install new power plants also elsewhere in Nigeria.
There are some plans for new hydro power plants, while photovoltaic and wind power plants are also under consideration.
However, to provide sufficient base load power in future, large coal-fired power plants may have to be
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included in the generation expansion program.
In terms of generation and load balance in the eight TCN planning regions, four or five have a significant generation deficit. With the exception of Benin and Port Harcourt regions, demand exceeds available generation power in all others. In the Shiroro region however, the situation will be reversed once new HPP plants (e.g. Zugeru) come into operation.
The reason for this imbalance is due to the generation being mainly concentrated in South (thermal stations in Port Harcourt, Enugu, Benin and Lagos) and Central West (hydro stations of Jebba, Kainji and Shiroro in Shiroro region). The Central, North and North-East in particular are characterized by the total absence of generating stations, while load demand is mainly in the South and South-West.
To supply power in areas with little or no generation such as the North-East, long 330 kV transmission lines are built (radial system), which means voltage regulation problems may occur and the reactive power flowing through them necessitates large reactive power compensation equipment (reactors) at the corresponding substations (Kano, Gombe, Maiduguri).
Additional 330 kV lines running in parallel are expected to exacerbate overvoltage issues, necessitating additional compensation equipment at Yola, Jalingo and other substations.
7-1-5-2 Frequency Control
The Grid Code frequency range is 50 Hz + 0.50%, i.e. 49.75 to 50.25 Hz (Grid Code chapter 4 Section 15.3.1), however due to the low availability of units on free governor control coupled with serious demand/generation imbalance, it was practically difficult to maintain and only Omotosho gas and NIPP and Olorunsogo gas units that were on free governor at one point or the other in recent years.
NCC was therefore constrained on numerous occasions to operate the grid outside the statutory frequency limits.
The frequency fluctuations which are mostly due to load rejection by DisCos and volatile loads from steel mills create harmonics and cause voltage flickering within the system. Most of the UFLS relay schemes installed in some substations to mitigate the impact of system collapses were not functional most of the time, which is why the characteristically strenuous manual frequency control technique, achieved through load shedding, defined year-round operations.
7-1-5-3 Voltage Control
In 2016, the voltage limits specified by the Grid Code were achieved largely on the upper voltage limit. The lower voltage limit meanwhile, formally experienced in the northern axis of the grid and plagued by voltage instability/decay, has been improved by installing capacity banks at Kano T.S. The AVRs of some GenCos are not functional.
7-1-5-4 Transmission Constraints
Transmission is plagued with incessant tripping of transmission lines, improper relay coordination, line
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limitation, ageing lines and inability to satisfy the N-1 contingency.
Transformers loaded to 100% and above of their rating require very urgent attention. Circumstances where some have to be loaded for hours above 100% reflects the urgent need to reinforce affected transformer banks.
7-1-5-5 Power Pool With Neighboring Countries
The sphere of operations of the Transmission Company of Nigeria transcends the geographical landscape of the country; the Republics of Niger and Benin are interconnected with the Nigerian transmission network.
The energy supplied to Benin Republic in 2016 was 1,275 GWH, signifying a decrease of 16.95% when compared with the 2015 figure of 1,535 GWH. The Republic of Niger was furnished with energy of 666 GWH in 2016, which is lower than the 2015 supply of 692 by 3.77% (ref. Table 7-1.4). These values represent only energy delivered through the 132kV transmission lines only. A fraction of the total supply to that country was through some 33kV distribution feeders.
Table 7-1.4 Cross-border electricity transactions (MWH)
Month BENIN REPUBLIC NIGER REPUBLIC
2016 2015 2016
JANUARY 139,232 131,851 JANUARY 139,232
FEBRUARY 137,028 128,821 FEBRUARY 137,028
MARCH 117,525 133,755 MARCH 117,525
APRIL 104,796 134,685 APRIL 104,796
MAY 86,139 111,132 MAY 86,139
JUNE 63,542 125,313 JUNE 63,542
JULY 88,775 114,134 JULY 88,775
AUGUST 97,162 133,044 AUGUST 97,162
SEPTEMBER 85,785 120,276 SEPTEMBER 85,785
OCTOBER 122,435 137,372 OCTOBER 122,435
NOVEMBER 116,345 137,028 NOVEMBER 116,345
DECEMBER 116,487 128,131 DECEMBER 116,487
TOTAL 1,275,251 1,535,542 TOTAL 1,275,251
AVERAGE 106,271 127,962 AVERAGE 106,271
Source: JICA Study Team
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7-2 Ongoing Projects
7-2-1 Contents of Projects
In July 2018, the JICA study team received two updated lists of recently completed and ongoing projects from TCN:
One list with TCN projects and
One list with NIPP projects.
These are included in Annexes 7.2a and 7.2b respectively.
While executing the Transmission Expansion Plan Study, it was agreed with TCN that as a basis for preparing the plan, we will assume that all ongoing projects will be completed by 2020.
Based on this network configuration, power system studies to identify further transmission system expansions between 2020 and 2040 were carried out.
The challenging nature of implementing transmission projects identified in the Transmission Expansion Plan by 2020 is acknowledged, given that it takes a minimum of three years from now to implement such projects (one year to prepare tender documents and select the implementation contractor and two years for project implementation). Accordingly, projects that may not be completed by 2020 should be prioritized for completion as soon as possible after 2020.
The TCN and NIPP projects that are expected to be implemented by 2020 have been included in the new PSS/E case for 2020. They are listed in Annexes 7.2a and 7.2b and the PSS/E case has also been modified to include the decisions made, following an exchange of dialog between TCN and the JICA study team.
7-2-2 Donors Assistance and Prospective Donors
7-2-2-1 Inclusion of TCN, NIPP, JICA and AFD projects
Annexes 7.2c and 7.2d show the 330 kV network configurations in the Lagos region including the projects that will be implemented under JICA financing. Furthermore, the following ongoing projects financed by AFD (Agence Française de Développement) for Abuja area have been considered:
New transmission lines:
142km of new 330 kV Double-Circuit line from Lafia 330 kV Substation (new) to New Apo 330/132/33 kV Substation.
7km of new 132 kV Double-Circuit line from New Apo 330/132/33 kV substation to Old Apo 132/33 kV substation
35km of new 132 kV Double-Circuit line from New Apo 330/132/33 kV substation to the new Kuje132/33 kV substation
29km of new 132 kV Double-Circuit line from the proposed Kuje 132/33 kV Substation to West Main (Lugbe) 330/132/33V substation.
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New substations:
330/132/33 kV substation at New Apo 132 kV line bay extension at Old Apo 132 kV SS 330/132/33 kV substation at WestMain (Lugbe) 132/33 kV substation at Kuje to be equipped with 3 × No. 60MVA 132/33 kV Substation at Wumba/Lokogomato 132/33 kV GIS substation at Gwarimpa
7-2-2-2 Additional Transmission System Expansions and Rehabilitation Measures Proposed by TCN
In the latest Transmission Expansion Plan submitted to TCN in December 2017, TCN has requested the inclusion of additional transmission system expansions and rehabilitation/reinforcement measures which have been identified by TCN. Six EXCEL lists have been provided with proposed projects, see Annexes 7.2e1 to 7.2e5.
The annexes also show the costs of the individual measures as estimated by TCN.
TCN plans to implement the measures and finance them via development banks as shown in Table 7-2.1.
Table 7-2.1 Prospective Development Banks Finance
Project Development Bank Total Cost
(million US$)
Annex 7.2e1 AFD (French Development Agency - Agence Française de Développement) 170
Annex 7.2e2 JICA (Japan International Cooperation Agency) To be determined
Annex 7.2e3 AfDB (African Development Bank) 410
Annex 7.2e4 World Bank 486
Annex 7.2e5 AFD (French Development Agency - Agence Française de Développement) 272
Total 1,538
Source: JICA Study Team
There are plans to implement all network expansions and rehabilitation/reinforcement measures as soon as possible, but considerable preparatory work (e.g. feasibility studies, tender documents etc.) is required in most cases. At this stage only implementation of system expansions according to Annex 7.2e1 (AFD-Project) is going-on and commissioning by 2020 may be achievable.
For projects financed by other banks (Annexes 7.2e2 to 7.2e5) implementation between 2020 and 2025 can be considered feasible. Usually about two to three years are required for feasibility studies, environmental impact studies, route survey, preparation of technical specifications and tender documents, bidding, tender evaluation and contracting and arrangement financing agreements. Two to three years can also be assumed for constructing and commissioning the projects.
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Table 7-2.2 Main TCN 330 and 132 kV transmission line projects
Area Region Location Description Voltage
(kV)
in
operation
by
PROPOSED ABUJA TRANSMISSION RING PROJECT (AFD1)
North-Central Abuja New Apo
Construction of about 172km of a new 330 kV
Double-Circuit line from Lafia 330 kV Substation
(new) to the proposed New Apo 330/132/33 kV
Substation.
330 2020
North-Central Abuja Old Apo
Construction of about 7km of a new 132 kV
Double-Circuit line from New Apo 330/132/33 kV
substation to Old Apo 132/33 kV substation:
132 2020
North-Central Abuja Old Kuje
Construction of 35km of a new 132 kV
Double-Circuit line from New Apo 330/132/33 kV
substation to the proposed Kuje 132/33 kV
substation.
132 2020
North-Central Abuja West Main Lugbe
Construction of 29 km of a new 132 kV
Double-Circuit line from the proposed Kuje 132/33
kV Substation to West Main (Lugbe) 330/132/33 V
substation.
132 2020
LAGOS/OGUN TRANSMISSION PROJECTS (JICA)
South-West Lagos New Abeokuta (Kobape) Ejio (Arigbajo) – New Abeokuta (Kobape) 132 kV
D/C Transmission Line (37.8km). 132 2022
South-West Lagos Ejio (Arigbajo) Olorunsogo – Ejio (Arigbajo) 330 kV D/C
Transmission Line (12.9km). 330 2022
South-West Lagos Ikeja West Ejio (Arigbajo) – Ikeja West/Osogbo 330 kV D/C
Turn-in-out (5.9km). 330 2022
South-West Lagos Ejio (Arigbajo) Likosi (Ogijo) - Aribajo D/C Transmission Line
(43.7km). 330 2022
South-West Lagos Shagamu
132 kV Quad Line (2.3km) from Likosi (Ogijo) –
Existing Ikorodu/Shagamu 132 kV 2x D/C
Transmission Line
132 2022
South-West Lagos Abule Oba (Redeem) 132 kV D/C Transmission Line (10.3km) from Likosi
(Ogijo) – Abule Oba (Redeem). 132 2022
South-West Lagos Ikeja West MAKOGI (MFM) – Existing Benin (Omotosho)/Ikeja
West 330 kV 2 x D/C Transmission Line (4.2km). 330 2022
South-West Lagos Ajegunle
(New Agbara)
Ejio (Arigbajo) – Ajegunle (New Agbara) 330 kV D/C
Transmission Line (30.6km). 330 2022
South-West Lagos Agbara Ajegunle (New Agbara) – Agbara 132 kV D/C
Transmission Line (20.8km). 132 2022
South-West Lagos Badagry Ajegunle (New Agbara) – Badagry 132 kV D/C
Transmission Line (34.2km). 132 2022
PROPOSAL FOR NORTH-EAST TRANSMISSION INFRASTRUCTURE PROJECT TO BE FINANCED BY AfDB
North-East Bauchi Maiduguri - Manguno - Marte -
Dikwa - Bama
Construction of a new 321km, 132 kV
Double-Circuit Line Between Maiduguri - Manguno -
Marte - Dikwa -Bama.
132 after
2020
North-East Bauchi Maiduguri - Bama - Goza - Gulak
Construction of a new 165km, 132 kV
Double-Circuit Line from Maiduguri - Bama - Goza -
Gulak.
132 after
2020
North-East Bauchi Mayo Belwa - Jada - Ganye Construction of a new 78km, 132 kV Double-Circuit
Line from Mayo Belwa - Jada - Ganye. 132
after
2020
North-East Bauchi Biu - BuniYadi - Damaturu Construction of a new 134km, 132 kV
Double-Circuit Line from Biu - BuniYadi - Damaturu. 132
after
2020
North-East Bauchi Dambua - Chibok - Uba - Mubi Construction of a new 130km, 132 kV
Double-Circuit Line from Dambua - Chibok - Uba - 132
after
2020
7-14
Area Region Location Description Voltage
(kV)
in
operation
by
Mubi.
North-East Bauchi Mayo Belwa - Jada - Ganye Construction of a new 78km, 132 kV Double-Circuit
Line from Mayo Belwa - Jada - Ganye. 132
after
2020
North-East Bauchi Biu - BuniYadi - Damaturu Construction of a new 134km, 132 kV
Double-Circuit Line from Biu - BuniYadi - Damaturu. 132
after
2020
North-East Bauchi Dambua - Chibok - Uba - Mubi
Construction of a new 130km, 132 kV
Double-Circuit Line from Dambua - Chibok - Uba -
Mubi.
132 after
2020
North-West Kaduna
Construction of Quad 330 kV on
Kaduna-Kano 330 kV Single DC
Transmission Line
Construction of Double-Circuit 330 kV Quad
Conductor Kaduna-Kano Transmission line. 330
after
2020
North-West Kaduna Zaria
Turn-in Turn-out and Installation of 2x150 MVA
330/132/33 kV Transformer, 6x330 kV bay
extension, 2x60MVA 132/33 kV Transformer,
associated 132 kV line bays and 6 number 33 kV
feeder bays at Zaria.
330 after
2020
North-West Kaduna Millennium City Kaduna
Turn-in Turn-Out and Installation of 2x150 MVA
330/132/33 kV Transformer, 2 x330 kV bay
extension and 2x60MVA 132/33 kV Transformer
and 2x3number associated outgoing 33 kV feeders.
330 after
2020
North-West Kaduna Rigasa town, Kaduna
Turn-in Turn-out and Installation of 2x60 MVA
132/33 kV Transformer and 5 number outgoing 33
kV feeders.
132 after
2020
North-West Kaduna Jaji, Kaduna
Turn-in Turn-out and Installation of 2x60 MVA
132/33 kV Transformer and 6 number outgoing 33
kV feeders.
132 after
2020
South-South Benin Reconstruction of Delta to Benin
330 kV Transmission Line
Reconstruction of one of Delta-Benin 330 kV
Transmission Line Double-Circuit to Quad
Conductor 330 kV Double-Circuit Line.
330 after
2020
South-South Port
Harcourt
Reconstruction of Alaoji to Onitsha
330 kV Transmission Line
Double-Circuit Alaoji-Ihiala-Onitsha to Quad
conductor 330 kV transmission line. 330
after
2020
South-South
Ahoda,
Gilili and
Sapele
Environmental Impact Assessment
and Resettlement Action Plan and
Payment of Compensation
Double-Circuit (DC) 132 kV Ahoda-Gilli-Gilli DC
Transmission Line and 2x60MVA 132/33 kV
Transformer at Gilli plus associated 6 number
outgoing 33 kV feeders and DC 132 kV Sapele -
Odilli DC Transmission Line and 2x60MVA
132/33 kV Transformer at Gilli plus associated 6
number outgoing 33 kV feeders.
132 after
2020
North-East `Bauchi
Environmental Impact Assessment
and Resettlement Action Plan and
Payment of Compensation
132 kV line and associated substations:
Maiduguri-Manguno-Marte-Dikwa-Bama,
Maiduguri-Bama-Gwoza;
Hadeja-Nguru-Gashua-Damaturu; Biu-Miringa-Buni
Yadi-Damaturu; Dambua-Chibok-Askira-Uba-Mubi;
Mayo Belwa-Jada-Ganye
132 after
2020
PROPOSED NETAP PACKAGE AS OF 03 APRIL, 2017 - $486 MILLION
South-West Osogbo Osogbo- Offa -Ganmo - Ilorin Reconductoring of 150km, 132 kV Line Between
Osogbo-Offa/Omuaran to Ganmo and Ilorin T.S. 132 2020
South-West Osogbo Ayede - Shagamu
Reconstruction and Conversion of SC to
Double-Circuit of Ayede -Ajebo-Ishara-Shagamu 132
kV Line (54km) and Creation of Additional Bays 132
132 2020
7-15
Area Region Location Description Voltage
(kV)
in
operation
by
kV Line Bays at Ayede, Ajebo, Ishara and Shagamu.
South-West Osogbo Osogbo- Ife/Ilesha
Reconstruction and Conversion to Double-Circuit of
Osogbo-Ife/Ilesha 132 kV Line (39.21 km) and
Osogbo-Ilesha 132 kV Line Tie-Off (22.1km) and
Creation of Additional 132 kV Line Bays at Osogbo
and Ilesha.
132 2020
South-East Port
Harcourt AFAM - PH Main
Reconstruction of Existing Double 132 kV Line
Circuit to 4 x 132 kV Line Circuit Using the Same
Right of Way from AFAM to Port Harcourt Main
(37.8km) and Creating Additional 3 x 132 kV Line
Bays.
132 2020
South-East Port
Harcourt PH Main - PH Town
Reconductoring of 132 kV Double-Circuit of Port
Harcourt Main to Port Harcourt Town 132 kV Line
(6km).
132 2020
North-West Kaduna Kumbotso - Hadelja Reconductoring of Kumbotsho- Hadeji 132 kV Line
(165 km). 132 2020
North-West Kaduna Kumbotso - Kankia Reconductoring of Kumbotsho- Kankia 132 kV Line
(100 km). 132 2020
South-East Enugu Onitsha - Oji River
Reconductoring of Onitsha- Orji 132 kV Line (87km)
with Turn-In- Turn-Out Tower at Nibo (Agu Awka) in
Awka 132 kV Substation.
132 2020
South-East Enugu Alaoji to Aba Town
Reconductoring of Alaoji - Aba Town Double-Circuit
132 kV line (8km) Including Rehabilitation of Two
Nos. Towers along the Line.
132 2020
South-South Benin Irrua - Benin Reconductoring of Irrua - Benin 132 kV line (81 km). 132 2020
South-South Benin Irrua - Okpila Reconductoring of Irrua- Okpilai 132 kV line (43
km). 132 2020
South-South Benin Okpila - Okene Reconductoring of Okpilai - Okene 132 kV line (65
km). 132 2020
South-South Benin Ajakuta-Okene Reconductoring of Ajakuta- Okene 132 kV line (60
km). 132 2020
North-East Bauchi Gombe-Biu-Damboa-Maiduguri
Reconductoring of the Entire Route Length from
Gombe -Dadin Kowa- Biu -Damboa - Maiduguri 132
kV line of 356 km Route Length.
132 2020
NORTHERN CORRIDOR TRANSMISSION PROJECT 2 (AFD2)
North-West Shiroro Kainji - Birnin-Kebbi 330 kV
Double-Circuit (DC) Line (310km)
330 kV DC Transmission Line Kainji-Birnin-Kebbi
(following the existing ROW of the SC 330 kV line)
and 4x 330 kV bay extension at B/ Kebbi and 2 x 330
kV bay extension at Kainji
330 after
2020
North-West Shiroro Birnin-Kebbi-Sokoto 330 kV
Double-Circuit (DC) Line (130km)
(1) Birnin-Kebbi-Sokoto 330 kV DC Transmission
Line on the existing 132 kV Birnin-Kebbi Sokoto
ROW and reconducting the existing 132 kV
Single-Circuit Birnin-Kebbi Line to double its
capacity
330 after
2020
North-West Kaduna Katsina-Daura-Gwiwa-Minjibir-Kura
(234KM)
Construction of length of 330 kV DC Twin line
between Katsina-Daura-Gwiwa-Jogana- Kura. 330
after
2020
North-Central Shiroro Lambata (Mina-Suleja Rd)
Turn-in Turn-out Mina - Suleja 132 kV DC and
Construction of 1 x 60 MVA 132/33 kV Complete
substation.
132 after
2020
North-West Shiroro Fakon Sarki-Argungu
Turn-in Turn-Out on Brinin Kebbi-Sokoto 132 kV
Line and Construction of 2 x 60MVA 132/33 kV
Complete substation.
132 after
2020
7-16
Area Region Location Description Voltage
(kV)
in
operation
by
North-West Shiroro Yelwa- Yawuri
Construction of 1 x 60MVA 132/33 kV Complete
substation and High-Voltage Switchgears and
Associated Equipment.
132 after
2020
North-Central Shiroro Birnin Gwari
Construction of 1 x 60MVA 132/33 kV Complete
substation and High-Voltage Switchgears and
Associated Equipment.
132 after
2020
North-West Kaduna Daura-Katsina State
Installation of 2x150MVA 330/132/33 kV
Double-Circuit Substation and with associated 132
kV bay extension and Installation of 2x60MVA
132/33 kV transformers, 6number outgoing 33 kV
feeder bays.
330 after
2020
North-West Kaduna Jogana-Kano
Installation of 2x150MVA 330/132/33 kV
Double-Circuit Substation and with associated 132
kV bay extension and Installation of 2x60 MVA
132/33 kV transformers, 6number outgoing 33 kV
feeder bays.
330 after
2020
North-West Shiroro 330 kV Sokoto Transmission
Substation
Installation of 2x150 MVA 330/132/33 kV
Transformers at Sokoto New 330 Double-Circuit
Substation and with associated 132 kV bay
extension and Installation of 2 x 60 MVA 132/33 kV
transformers, 6 number outgoing 33 kV feeder
bays.
330 after
2020
North-Central Shiroro
Shiroro –Kaduna (Mando) 330 kV
Lines 1 & 2 SC Transmission Lines
(96km)
Reconstruction and upgrading of two Single-Circuit
330 kV Transmission Lines 1 & 2 from Shiroro PS to
Mando (Kaduna) to a two Double-Circuit, Quad
conductor Shiroro-Mando (Kaduna) Transmission
lines 1 and 2. The line bay extension at Mando and
Shiroro.
330 after
2020
North-East Bauchi Bauchi 330 kV Transmission
Substation (2km)
Turn-in-out of the existing 330 kV SC Jos-Gombe
line at Bauchi and installation of 2x150 MVA
330/132/33 kV Transformers with associated 132
kV bay extension and 2 x 60 MVA 132/33 kV
transformers, 6 number outgoing 33 kV feeder
bays.
330 after
2020
Source: JICA Study Team
Some of these projects are critical to operate the system in 2020 and if a load exceeding 9 GW is to be served adequately, these projects will have to be expedited, targeting completion by 2020 or as soon as possible after 2020.
7-2-2-3 Transmission System Expansions Financed by AFD
A financing agreement is in place to improve the transmission system in the Greater Abuja area.
The transmission system expansions included in the ADF-financed project will strengthen the 330/132 kV system supplying power to the capital Abuja. A new 132 kV Double-Circuit transmission line (172 km) between New Apo 330/132/33 kV Substation and the planned Lafia 330 kV Substation will establish a third infeed to the Abuja 132 kV ring allowing power supply from the power plants in the Delta Area and the planned Mambilla Hydro Power Plant.
7-17
These network expansions are planned to be commissioned in 2020, see Table 7-2.2.
A detailed list of the transmission system expansions with their cost as estimated by TCN is shown in Annex 7.2e1. The planned transmission lines and substations are shown in Annex 7.1 on a map of Nigeria.
7-2-2-4 Transmission System Expansions to Be Financed by JICA
To improve the transmission system operation and reliability of the transmission network in the Lagos region, there are plans to install new transmission lines and substations financed by JICA, which is currently preparing a feasibility study.
The planned 330 kV substations Likosi (Ogijo) and Ejio (Arigbajo) will reconfigure the transmission system from single- to Double-Circuit configuration improving rehabilitation during line maintenance and outages. The 330-kV Double-Circuit line to Ejio (Arigbajo) - Ajegunle (New Agbara) and Ajegunle (New Agbara) substation will allow power export to Benin bypassing the heavily loaded Ikeja Substation. The new 132/33 kV substations Abule Oba (Redeem), MAKOGI (MFM) and Badagry will provide additional infeed capacity into the distribution system.
Commissioning of these network expansions is scheduled for 2020, see Table 7-2.2.
Annex 7.2d shows the present network configuration in the Lagos area and the future configuration after commissioning new lines and substations.
A detailed list of the transmission system expansions with their cost as estimated by TCN is shown in Annex 7.2e2.
7-2-2-5 Transmission System Expansions to Be Financed by AfDB
The transmission system in the North-East of Nigeria is not well developed. Many north-eastern cities are not yet connected to the transmission system and rely on local generation only.
To improve the electricity supply from the national grid, TCN is planning to install various 132 kV transmission lines and new 132/33 kV substations as follows:
New Transmission Lines 321 km, 132 kV Double-Circuit Line Between Maiduguri - Manguno - Marte - Dikwa -Bama 165 km, 132 kV Double-Circuit Line from Maiduguri - Bama - Goza - Gulak 78 km, 132 kV Double-Circuit Line from Mayo Belwa - Jada - Ganye 134 km, 132 kV Double-Circuit Line from Biu - BuniYadi - Damaturu 130 km, 132 kV Double-Circuit Line from Dambua - Chibok - Uba - Mubi
132/33 kV Substations New 132/33 kV Manguno Substation, 2 x 60 MVA, Extension of Old Maiduguri 132 kV switchgear by 2 bays, New 132/33 kV Marte Substation, 2 x 60 MVA,
7-18
New 132/33 kV Dikwa Substation, 1 x 60 MVA, New 132/33 kV Bama Substation, 2 x 60 MVA, Extension of New Maiduguri 132 kV switchgear by 2 bays, New 132/33 kV Gwoza Substation, 1 x 60 MVA, Extension of Gulak 132 kV switchgear by 2 bays, New 132/33 kV Jada Substation, 2 x 60 MVA, New 132/33 kV Ganye Substation, 2 x 60 MVA, New 132/33 kV Uba Substation, 2 x 60 MVA, New 132/33 kV Chibok Substation, 1 x 60 MVA, New 132/33 kV Biu Substation, 1 x 60 MVA, New 132/33 kV Bunyadi Substation, 1 x 60 MVA, Extension of Damaturu 132 kV switchgear by four bays, New 132/33 kV Kwaya Kusar Substation, 1 x 60 MVA, Extension of Gulak 132 kV switchgear by 2 bays,
In addition to the above, the following lines are planned:
In the North-West planning region of Nigeria there are plans to build a 330-kV Double-Circuit line between Kaduna and Kano, two 330/132 kV substations and two 132/33 kV substations.
In the South planning region, the reconstruction of two 330 kV transmission lines is planned. The 330 kV lines Delta-Benin and Alaoji-Ihiala-Onitsha shall be replaced by Double-Circuit lines with Quad conductors.
Furthermore, environmental impact assessments for various transmission lines are included in the scope.
A detailed list of transmission system expansion measures included in the scope of financing is shown in Annex 7.2e3 with their cost as estimated by TCN.
The planned transmission lines and substations are shown in Annex 7.1 on a map of Nigeria.
7-2-2-6 Transmission System Rehabilitations and Reinforcements/Upgrading to Be Financed by the World Bank
Under the Nigeria - Electricity Transmission Project (NETAP) it is proposed to carry out numerous rehabilitations/reinforcements of existing substations and transmission lines, financed by the World Bank.
The reinforcement and upgrading of substations includes the installation of additional 330/132 kV and 132/33 kV transformers, replacement of existing transformers by units with a higher rated capacity and installation of associated switchgear equipment and control and protection equipment. The rehabilitation measures include replacing high-voltage switchgear and associated equipment as well as control and protection equipment.
The rehabilitation/reinforcement of transmission lines includes mostly reconductoring of lines.
7-19
A detailed list of system rehabilitations and reinforcements/upgrading with their cost as estimated by TCN is shown in Annex 7.2e4. The annex shows that the substations and transmission lines are located throughout all the TCN planning regions of Nigeria.
7-2-2-7 Transmission System Expansions to Be Financed by AFD
Under a second financing agreement with AFD, there are plans to build new transmission lines and substations and rehabilitate transmission lines and substations in various northern planning areas of TCN, to improve power transmission in the northern transmission corridor. The scope includes also various rehabilitation measures for substations and transmission lines.
A detailed list of transmission system expansion measures included in the scope of financing is shown in Annex 7.4e5 with their cost as estimated by TCN.
7-20
7-3 Criteria to Formulate a Transmission Network Development Plan
7-3-1 Appraisal Criteria for TCN Network Expansions
Each of the main 330 and 132 kV projects has been appraised using ENTSO-E methodology. As such, the benefit of each project is assessed against a number of indicators, ranging from technical and socio-economic issues to their environmental impact.
The analysis has been performed for projects with implementation in the transmission network scheduled for 2025. Applying the ENTSO-E methodology, expected benefits were weighted and individually applied for each project. For this study, the projects were appraised against the following criteria:
Increase of Network Transfer Capacity, estimating the incremental power transfer capacity between two points of the transmission system (MW);
Social and Environmental Impacts, reflecting the level of certainty with respect to the planned commissioning time of the project and its impacts on the environment;
Security of Power Supply, evaluating the project impact on the reliability status of connected parts of the network;
Integration of Renewable Energy Sources (RES), Support for RES integration is defined as the ability of the system to allow the connection of new RES plants and unlock existing and future “green” generation;
Effect on Transmission Losses (Energy Efficiency), comparing losses (in MWs) relevant to scenarios with and without projects (or their specific components);
Technical resilience/system safety margin, evaluating the project influence on overall system reliability;
The radar format graph of Figure 7-3.1 shows, for example, the points scored by certain projects and hence their priority ranking. When comparing for the five projects, the 132 kV Ayade – Ibadan North project has the highest score and thus the highest priority. Other projects are also calculated and prioritized accordingly.
7-21
Source: JICA Study Team
Figure 7-3.1 Project Appraisal Criteria and Scores
7-3-2 Methodology Overview
The methodology of the power system analysis is summarized as follows:
7-3-2-1 Definition of the Security Reference Level
The goal of the study is to propose the necessary updates and reinforcements to the TCN power system to achieve secure operation for the system for the period 2020 to 2040. First, the present system model is analyzed, taking into account the recently completed and ongoing TCN and NIPP projects scheduled for completion by 2020. It has also been assumed that certain projects in the Lagos area undertaken by JICA will be completed for the period 2020-2025.
(1) Voltage criteria
The Grid Code of, 2014, v2, states that the System Operator shall endeavor to control the different busbar voltages to be within the voltage control ranges specified in Table 7-3.1:
Table 7-3.1 Voltage criteria
Voltage Level
(kV)
Normal Operation Contingency Operation
Minimum Voltage
(kV) (pu)
Maximum Voltage
(kV) (pu)
Minimum Voltage
(pu)
Maximum Voltage
(pu)
330 kV 280.5 (0.85) 346.5 (1.05) 0.80 1.10
132 kV 112.2 (0.85) 145.2 (1.10) 0.80 1.15
66 kV 62.04 (0.94) 69.96 (1.06) 0.89 1.11
33 kV 31.02 (0.94) 34.98 (1.06) 0.89 1.11
11 kV 10.45 (0.95) 11.55 (1.05) 0.90 1.10
Source: JICA Study Team
0
0.5
1
1.5
2
2.5
3
Increase ofnetwork transfer
capacity
RES integration
Improved securityof supply
Reduction intransmission
losses
Technicalresilience/system
safety margin
Social andEnvironmental
Impacts
330 and 132 kV projects
330 Akangba-Alagbon
330 Ukwaji-Abakaliki
132 Ayede-Ibadan North
132 NewAgbara-Agbara
132 Ibom IPP-Ikot Abasi
Points:
9
10.3
10.8
9.9
10
7-22
Under system stress or following system faults, voltages can be expected to deviate outside the above limits by a further +/-5% (excluding transient and sub-transient disturbances).
7-3-2-2 Thermal Criteria
The maximum permissible thermal overloading for all branches at 330 and 132 kV level is 100% of the nominal rating (Rate A) under normal (N) system conditions and 110% of the nominal rating under contingency (N-1) system conditions.
7-3-2-3 Policy of the Power System Analysis
(1) Execution of analyses on the 2020 model
The initial analysis relates to the static security assessment. Using the outcome of this analysis, an initial reinforcement list and recommendations for new lines and transformers are provided.
(2) Execution of the analysis on the 2025, 2030, 2035 and 2040 models
Considering the recommendations and reinforcements provided in b) already implemented in the 2020 network model, the same analysis is carried out on the 2025, 2030, 2035 and 2040 scenarios. The reinforcements and recommendations for these years constitute the outcome of this analysis.
The proposed transmission expansion projects from 2020 to 40 are detailed in the following sections.
Five milestone study years have been selected to cover the planning horizon of the Master Plan: 2020, 2025, 2030, 2035 and 2040.
7-3-3 Load Demand
The load demand in each of the DisCos areas in Nigeria is summarized in Table 7-3.2
In the 2020 network configuration, the assumed total demand is 9,023 MW, to closely match the validated DisCos load demand, as presented by the 11 DisCos in the workshop of January 2017 in Abuja. Thereafter, the load demand to be served depends on two factors: (a) the rate of increase in forecast demand as presented in Section 5 and, more importantly, (b) the limits of the generation expansion plan.
The maximum load demand that can be realistically supplied will, accordingly, have to follow the development of the generation planning schedule and will be limited by associated financial and time constraints.
The total demand that can be served includes the export requirements to neighboring countries.
Table 7-3.2 Load demand per DisCo
DisCo 2020 incr 2025 incr 2030 incr 2035 incr 2040
1-Ikeja 1,166 76% 2,058 42% 2,921 21% 3,536 22% 4,300
2-Ibadan 1,104 107% 2,285 43% 3,267 24% 4,054 25% 5,055
3-Abuja 865 169% 2,329 50% 3,500 26% 4,398 21% 5,336
4-Benin 954 94% 1,852 34% 2,489 17% 2,901 17% 3,391
5-Kaduna 495 136% 1,169 81% 2,117 20% 2,533 20% 3,045
7-23
DisCo 2020 incr 2025 incr 2030 incr 2035 incr 2040
6-Jos 309 109% 646 60% 1,035 4% 1,079 5% 1,131
7-Enugu 924 81% 1,668 19% 1,979 3% 2,037 4% 2,112
8-Port Harcourt 794 122% 1,762 35% 2,385 17% 2,802 18% 3,305
9-ΕΚΟ 1,087 69% 1,837 22% 2,240 6% 2,382 5% 2,512
10-Kano 708 121% 1,565 64% 2,570 38% 3,549 13% 4,023
11-Yola 230 131% 532 77% 942 54% 1,448 16% 1,680
Country (MW) 8,636 105% 17,703 44% 25,447 21% 30,719 17% 35,890
Export (MW) 387 1,540 1,830 2,000 2,000
Total Load (MW) 9,023 113% 19,243 42% 27,277 20% 32,719 16% 37,890
Source: JICA Study Team
The increase in load that can be supplied by the planned generation for the period 2020-2040 is shown in Figure 7-3.2. The development of the generation system and associated demand can thus be referred to as the 9 GW in 2020, 18 GW in 2025, 26 GW in 2030, 31 GW in 2035 and 36 GW in 2040 respectively.
Source: JICA Study Team
Figure 7-3.2 Increase in Served Nigerian Load 2020-2040
Based on the installed generation, the maximum generation that can be made available to supply the peak demand is calculated as shown in the following Table 7-3.3 and Figure 7-3.3.
The generation expansion assumed for this study, for an average exceeding 2 GW per year for the period 2020-2034, is considered rather optimistic.
Table 7-3.3 Installed and available generation for 2020, 2025, 2030, 2035 and 2040
2020 2025 2030 2035 2040
Installed generation (GW) 14.1 29.2 41.2 51.3 54.9
Proposed candidates (GW) 0.7 9.1 18.5 28.6 32.4
Less PV (not available during peak load) in GW -1.08 -1.31 -2.11 -2.11 -2.11
Less a% of proposed candidates (in% and GW)
0% 20% 20% 20% 20%
0.0 -1.8 -3.7 -5.7 -6.5
Less a min% on planned and unplanned outages (in% and GW)
20% 20% 20% 20% 20%
-2.6 -5.2 -7.1 -8.7 -9.3
Available generation (max./rated) in GW 10.4 20.9 28.3 34.8 37.1
Available generation (running) during peak demand (GW)
9.9 19.8 26.9 33.4 35.6
Available generation (max), as% of the total (installed+planned+proposed).
74% 71% 69% 68% 67%
Source: JICA Study Team
8636
17703
25447
30719
35890
0
5000
10000
15000
20000
25000
30000
35000
40000
2015 2020 2025 2030 2035 2040 2045
Supplied Nigerian Load MW
7-24
Source: JICA Study Team
Figure 7-3.3 Installed and Available Generation for 2020, 2025, 2030, 2035 and 2040
7-4 Expansion Plan for 2020
7-4-1 Static Security Analysis, Year 2020
7-4-1-1 Network Configuration
The network configuration for 2020 is shown in the single-line diagrams of Annexes 7.4.2 and 7.4.1. The SLDs include all the ongoing and committed TCN, NIPP and JICA new projects, assuming completion in all cases by 2020.
The new transmission expansion projects identified on the basis of the load-flow studies carried out are shown on the map of Annexes 7.4.3 and 7.4.4.
The input data used and the assumptions made with regard to the load demand, generation capacities and expansion, transmission lines and reactive power compensation equipment are detailed in the following sections.
Figure 7-4.1 below shows the 330-kV transmission system in 2020 (red lines), assuming all the ongoing
7-25
and committed TCN, NIPP and certain JICA new projects will be completed by 2020.
The diagram shows the running generation and load in each DisCo area and the power flows between DisCos.
Dotted lines and lines in magenta denote future projects beyond 2020, which were analyzed in the study of the corresponding year and reported accordingly in this report.
Source: JICA Study Team
Figure 7-4.1 330 kV Transmission System 2020
7-4-1-2 Load Demand
In the 2020 network configuration the assumed total demand is 9,023 MW, closely matching the validated DisCos load demand, as presented by the 11 DisCos in the workshop of January 2017 in Abuja.
The load in each of the DisCo areas in Nigeria is shown in Figure 7-4.2 and summarized in Table 7-4.1.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1194 MW
8 TO 4 563 MW
3 TO 2 223 MW
7 TO 4 792 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 179 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 633 MW
G
G
G
DISCOS
2 TO 1 1242 MW
4 TO 3 0 MW
G
G
Diagram created using'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2020\DP 2020 model Yash.sav'
'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yash.sld'
GG
TCN 2020 MODEL
DISCO DEMANDWED, JUL 18 2018 15:15
3 TO 5 1009 MW
1 TO 9 284 MW
GG
5 TO 6 -64 MW
10 TO 6 0 MW
5 TO 10 0 MW
6 TO 11 218 MW
G
4 TO 9 506 MW
4 TO 1 761 MW
G
G
83004IKOT-EKPENE_
73006UGWUAJI_3
73001ONITSHA 3
73005ASABA_3
73003MAKURDI_3
1
1
33007GWAGW BB1
23005AKURE 3
23001OSOGBO 3
1
2
3
23003GANMO 3
23002OMOTOSHO3
33002BKEBBI 3
1
2
13003IKEJA W 3
13005OLORUNSOGO3
13029OGIJO 3
13030MFM 3
1
0 50
2
0 50
SW
0
63007DAMATURU 3
63005MAIDUGURI 3
2
0
69
13002EGBIN 3
13025EPE 3
13000AJA 3
13031OKO_OBA_313034
LEKKI 330
13027ALAGBON_3
13001AKANGBA 3
1
33001KATAMPE 3
83007ONNIE_3
1
83002ALAOJI 3
83010IKOT ABASI_3
83000AFAM IV 3
83005OWERRI_3
73004ALIADE_3
63001JOS 3
73010ABAKALIKI_3
0 72
63002YOLA 3
53001KANO 3
2
3
SW
0
53005KANO_NEW330
53003ZARIA_330
53000KADUNA 3
53002KATSINA 3
13032NEW_AGBARA_3
1260
1
23000AYEDE 3
43000AJAOKUTA 3
43008LOKOJA _3
43002BENIN 3
43001ALADJA 3
43003DELTA IV 3
43004SAPELE 3
43011B_NORTH_3
43005GEREGU
43009OBAJANA_3
83006EGBEMA_3
83009OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
2
1 2
33020SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
53004FUNTUA 3
53007TMAFARA3
53008GUSAU 3
33021KAINJI 3
33005KAINJI G .S.3
33003JEBBA T.S.3
33009ZUNGERU
33004JEBBA G .S.3
33022APO_NEW 3
33023LAFIA 3
63003BAUCHI 3
63008MAMBILA 3
43006EFFURUN 3
73002OKPAI 3
73030IHIALA 3
23006IBADAN
13026OKE_ARO_3
53012DUTSE 3
53011KAZAURE 3
1
2
0 72
63009WUKARI
33006SOKOTO 3
83001ALAOJI NIPP3
73007NNEWI 3
0
32 9
30
338
1
2
1
13004SAKETE 3
13028ARIGBAJO
63006JALINGO_3
33010ZABORI
SW 0
13012PARAS
63015MAYOBELWA
43007AZURA
43010ETHIOPE
13035IJORA 3
187
1
32021NIAMEY 1
1
40
1
52010GAZOUA 1
SW
34
Export 387 MW
Total Generation 9417 MWNigeria Load 8637 MW
Genera tion from H PP 1322 MW
Generation per DISCO Loads per DISCO
3-Abuja 866 MW
7-Enugu 924 MW
2-Ibadan 1104 MW
1-Ikeja 1166 MW
6-Jos 309 MW
5-Kaduna 495 MW
10-Kano 708 MW
11-Yola 230 MW
3-Abuja 1750 MW
4-Benin 1775 MW
9-Eko 0 MW
7-Enugu 796 MW
2-Ibadan 476 MW
1-Ikeja 1110 MW
6-Jos 105 MW
5-Kaduna 194 MW
10-Kano 9 MW
8-Pt Harco 3202 MW
11-Yola 0 MW
Genera tion from PV 0 MW
Total Load 9024 MW
9-Eko 1087 MW
8-Pt Harco 794 MW
4-Benin 954 MW
1
1
1
1
1
1
7-26
The total demand includes the export requirements to neighboring countries as follows:
To Benin (Sakete, 330 kV): To Niger (Niamey, 132 kV): To Niger (Gazoua, 132 kV):
The export requirements modeled for 2020, 2025, 2030 and 2035 were based on information provided by TCN and the results of earlier WAPP studies and reports.
In the 2020 load model representation in PSS/E, a pessimistic power factor of around 0.85 has been assumed, despite the new Grid Code requirements calling for a pf of 0.95, as it is believed that most users at distribution level are not in full compliance yet with this requirement. It is noted that the Grid Code requirements (ref. article 15.6 on Demand power factor corrections and 16.7 on provision of voltage control) states that The Off-takers shall maintain a power factor of at least 0.95 at the Connection Point.
Accordingly, the loads in the 2020 models are based on a pf of 0.85, those in the 2025 model on a still-conservative pf of 0.92 and only the 2030 loads have a pf of 0.95.
Table 7-4.1 Load demand per DisCo
SCO Load (MW)
1-Ikeja 1,166
2-Ibadan 1,104
3-Abuja 866
4-Benin 954
5-Kaduna 495
6-Jos 309
7-Enugu 924
8-Port Harcourt 794
9-Eko 1,087
10-Kano 708
11-Yola 230
Total for Nigeria 8,637
Export 387
Total load 9,024
Source: JICA Study Team
The modeled loads of individual substations within each DisCo are detailed in Annex 7.4.5.
The total generation required to meet the load in Nigeria is 9,421 MW and total losses are 397 MW.
7-4-1-3 Generation Capacity
The ratings of the conventional generating units in Nigeria for 2020 are shown in Table 7-4.2.
7-27
Table 7-4.2 Ratings of power generating units (Pmax)
Station Name Company Name Primary Energy
Resource
Commercial Operation
Date
No of Units
Gross Unit
Capacity (MW)
Gross Plant
Capacity (MW)
Total 2020
Existing generation capacity
AFAM IV - GT13-18 AFAM POWER PLC. GAS 1982 6 75 450 150
AFAM V - GT19-20 AFAM POWER PLC. GAS 2002 2 138 276 276
AFAM VI - GT11-13 SHELL ROT GAS 2009 3 166 498 450
AFAM VI - ST1 SHELL ROT STEAM 2010 1 230 230 200
ALAOJI – NIPP NIPP GAS 2013 4 120 480 480
CALABAR / ODUKPANI NIPP NIPP GAS 2015 5 113 565 338
DELTA II - GT3-8 TRANSCORP POWER LTD GAS 2002 6 24 143 123
DELTA III - GT9-14 TRANSCORP POWER LTD GAS 2005 6 24 143 128
DELTA IV - GT15-20 TRANSCORP POWER LTD GAS 1990 6 99 594 630
EBUTE BARGE (CYREX) AES AES / CYREX ENERGY LTD GAS 2002 9 31 279 0
EGBIN EGBIN POWER PLC STEAM 1985 6 220 1,320 1,320
GBARAIN - GT2 NIPP NIPP GAS 2016 1 113 113 113
GEREGU FGN 1 GEREGU GENERATION
COMPANY LTD GAS 2007 3 138 414 414
GEREGU NIPP 1 NIPP GAS 2013 3 148 444 220
IBOM 1 IBOM POWER GAS 2009 1 42 42 0
IBOM 1 IBOM POWER GAS 2010 1 114 114 114
IBOM 1 IBOM POWER GAS 2016 1 40 40 0
IHOVBOR (EYAEN) NIPP NIPP GAS 2013 4 113 452 339
JEBBA POWER HOLDING CO OF
NIGERIA HYDRO 1983 6 101.15 606.9 607
KAINJI - G11-12 POWER HOLDING CO OF
NIGERIA HYDRO 1976 2 100 200 200
KAINJI - G5-6 POWER HOLDING CO OF
NIGERIA HYDRO 1968 2 120 240 240
KAINJI - G7-10 POWER HOLDING CO OF
NIGERIA HYDRO 1978 4 80 320 160
OKPAI IPP NIGERIAN AGIP OIL CO GAS 2005 2 165 330 300
OKPAI IPP NIGERIAN AGIP OIL CO STEAM 2005 1 140 140 140
OLORUNSOGO I PACIFIC ENERGY GAS 2007 8 42 335 335
OLORUNSOGO II NIPP NIPP GAS 2011 4 120 480 240
OLORUNSOGO II NIPP NIPP STEAM 2012 2 120 240 120
OMOKU IPP FIRST INDEPENDENT
POWER GAS 2006 6 25 150 150
OMOTOSHO I OMOTOSHO ELECTRIC
ENERGY COMPANY GAS 2007 8 42 335 304
OMOTOSHO II NIPP NIPP GAS 2012 4 120 480 240
PARAS ENERGY PARAS ENERGY &
NATURALS RES. DEV. LTD GAS 2016 9 9 79 170
RIVERS IPP FIRST INDEPENDENT
POWER GAS 2012 1 191 191 191
SAPELE SAPELE POWER PLC STEAM 1978 6 88 528 400
SAPELE OGORODE 1 NIPP NIPP GAS 2011 4 113 454 454
SHIRORO SHIRORO HYDRO ELECTRIC HYDRO 1990 4 150 600 600
TRANS-AMADI IPP FIRST INDEPENDENT
POWER GAS 2010 4 25 100 100
Subtotal 1-Existing generation capacity 10,098
Additional generation capacity by 2020
AFAM III
GAS 2018 8 30 240 240
7-28
Station Name Company Name Primary Energy
Resource
Commercial Operation
Date
No of Units
Gross Unit
Capacity (MW)
Gross Plant
Capacity (MW)
Total 2020
AFRINERGIA SOLAR AFRINIGER SOLAR PV 2020 50 50
ANJEED KAFACHAN SOLAR
IPP
ANJEED KAFACHAN SOLAR
IPP PV 2020 100 100
AZURA
GAS 2018 3 150 450 450
CT COSMOS CT COSMOS PV 2020 70 70
EGBEMA I - NIPP NIPP GAS 2018 1 113 113 113
EGBEMA I - NIPP NIPP GAS 2019 1 113 113 113
EGBEMA I - NIPP NIPP GAS 2019 1 113 113 113
EN Consulting & Projects -
Kaduna PV 2020 100 50
GBARAIN / UBIE I NIPP GAS 2017 1 113 113 113
GURARA SALINI NIGERIA LTD HYDRO 2017 2 15 30 30
IBOM II
GAS 2020 4 138 552 276
KADUNA IPP KADUNA IPP GAS 2019 1 215 215 215
KASHIMBILLA
HYDRO 2019 40 40 40
KVK POWER NIGERIA LTD KVK POWER NIGERIA LTD PV 2020 55 55
LR AARON SOLAR POWER
PLANT LR AARON SOLAR PV 2019 100 100
MABON - DADIN KOWA MABIN LTD. HYDRO 2018 1 39 39 39
MIDDLE BAND SOLAR MIDDLE BAND SOLAR PV 2020 100 100
MOTIR DUSABLE MOTIR DUSABLE LTD PV 2020 100 100
NIGERIA SOLAR CAPITAL
PARTNERS
NIGERIA SOLAR CAPITAL
PARTNERS PV 2020 100 100
NOVA SCOTIA POWER Nova Scotia Power
Development Ltd PV 2018 80 80
NOVA SOLAR NOVA SOLAR POWER LTD PV 2018 100 100
OKPAI IPP II - AGIP (NNPC
POWER BUSINESS PLAN) NIGERIAN AGIP OIL CO GAS 2020 2 150 300 300
OKPAI IPP II - AGIP (NNPC
POWER BUSINESS PLAN) NIGERIAN AGIP OIL CO STEAM 2020 1 150 150 150
OMOKU - NIPP NIPP GAS 2018 1 113 113 113
OMOKU - NIPP NIPP GAS 2019 1 113 113 113
ORIENTAL
PV 2020 50 50
PAN AFRICA SOLAR PAN AFRICA SOLAR LTD PV 2019 75 75
QUAINT ENERGY SOLUTIONS QUAINT ENERGY
SOLUTIONS PV 2019 50 50
ZUNGERU
HYDRO 2019 4 700 700 700
Subtotal 2-Additional generation capacity by 2020 4,198
Total by 2020 14,296
Source: JICA Study Team
The PV plants shown in Table 7-4.3, are planned to be installed mainly in northern Nigeria and are most likely to go into operation by 2020.
Table 7-4.3 PV plants in operation by 2020
PN Plant Location Installed Capacity (MW)
Pan Africa Solar Kankia 75
Nova Solar Katsina 100
LR Aaron Power Abuja/Gwangwalada 100
Nova Scotia Dutse/Jigawa 80
7-29
PN Plant Location Installed Capacity (MW)
KVK Power Sokoto 55
Quaint Power/Energy Kaduna 50
Anjeed Kafanchan Kafanchan 100
Nigeria Solar Capital Partners Gombe/Bauchi 100
Motir Dusable Oji 100
Afrinergia Solar Karu-Keffi 50
CT Cosmos Jos/Makeri/Pankshin 70
Oriental Dutse 50
EN Consulting-Kaduna Kaduna-Zaria 50
Middle Band Solar Lokoja 100
Source: JICA Study Team
7-4-1-4 Study Cases 2020
Four scenarios, as shown in Table 7-4.4 have been studied for 2020. The focus was on the two cases, (Dry Season Peak and Dry Season Off-Peak), which capture the extreme combinations of generation and load. Other scenarios, such as Wet Season Peak and Wet Season Off-Peak, are less onerous, as it has emerged that their requirements are covered by the extreme case studied:
Table 7-4.4 2020 study cases
Case Description Generation Load (MW)
Dry Season Peak
DP
Dry
Night
Peak Load
Dry-Reduced HPP generation (1,322 MW)
No PV generation
Increased requirement from GTs
Peak load
(night)
8637 +
export (387)
Wet Season
Peak
WP
Wet
Night
Peak Load
Wet-Normal HPP generation (2,100 MW)
No PV generation
Increased requirement from GTs
Peak load
(night)
8637 +
export
Dry Season
Off-Peak
DOP
Dry
Day
Off-Peak Load
Dry-Reduced HPP generation (1,100 MW)
PV generation (400 MW)
Off-Peak
load (day)
7340+
export (387)
Wet Season
Off-Peak
WOP
Wet
Day
Off-Peak Load
Wet-Normal HPP generation (2,100 MW)
PV generation (400 MW)
Off-Peak
load (day)
7340 +
export (387)
Source: JICA Study Team
7-4-2 2020 Base Case Load-flow Results
The load-flow results are shown in Annexes 7.4.2 and 7.4.6 to 7.4.9
In the base case (N-0) load-flow calculations the following observations are made:
7-4-2-1 Power Flows Between DisCos and Regions
The diagram of Figure 7-4.1 and the SLD in Annex 7.4.1 indicate the power flows between the 11 DisCos areas in Nigeria using green arrows, for general peak load and generation case. The DisCos are:
1-Ikeja 5-Kaduna 9-Eko 2-Ibadan 6-Jos 10-Kano 3-Abuja 7-Enugu 11-Yola 4-Benin 8-Port Harcourt
7-30
The Nigeria planning regions are:
1-Lagos 5-Kaduna 9-Abuja (July 2018~) 2-Osogbo 6-Bauchi 3-Shiroro 7-Enugu 4-Benin 8-Port Harcourt
The generation (installed and running) and the load in each DisCo are summarized in Table 7-4.5 and Figure 7-4.2. The running generation is approximately 74% of the total installed capacity.
Table 7-4.5 Running generation and load in different areas (DisCos)
Region
Running Generation
(MW)
Load
(MW)
Generation deficit/surplus
(MW) Remarks
1-Ikeja 735 1,166 -431 Generation deficit
2-Ibadan 476 1,104 -628 Generation deficit
3-Abuja 1,979 866 1,113 Generation surplus
4-Benin 1,775 954 821 Generation surplus
5-Kaduna 344 495 -151 Generation deficit
6-Jos 105 309 -204 Generation deficit
7-Enugu 796 924 -128 Generation deficit
8-Port Harcourt 3,202 794 2,408 Generation surplus
9-Eko 0 1,087 -1,087 Generation deficit
10-Kano 9 708 -699 Generation deficit
11-Yola 0 230 -230 Generation deficit
Total for Nigeria - 8,637 -
Export - 387 -
Totals 9,421 9,024 397 (losses)
Source: JICA Study Team
Source: JICA Study Team
Figure 7-4.2 Generation and Load per DisCo
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotalfor
NigeriaExport
Totals,incl
export
Run Genaration 735 476 1979 1775 344 105 796 3202 0 9 0 9421
Load 1166 1104 866 954 495 309 924 794 1087 708 230 8637 387 9024
Gen deficit/surplus -431 -628 1113 821 -151 -204 -128 2408 -1087 -699 -230 397
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
3500
MW
7-31
The general voltage profile is shown in Figure 7-4.3, with blue and red indicating relatively low and high voltages respectively. Lagos, Osogbo and Kaduna are clearly areas with low voltages encountered due to high demand, insufficient local generation, voltage drop in radial feeders and overloaded 132 kV lines and 132/33 kV transformers, even in some areas with high generation.
Source: JICA Study Team
Figure 7-4.3 Voltage Profile of 330, 132 and 33 kV Systems
It can be seen that:
The generation is mainly concentrated in the South (thermal stations in Port Harcourt, Enugu, Benin and Lagos) and Central West (hydro stations of Jebba, Kainji and Shiroro in the Shiroro region). The Central, North and North-East regions in particular are characterized by the total absence of generating stations.
Load demand centers in the South and South-West. Table 7-4.5 shows that with the exception of Benin, Abuja and Port Harcourt areas, where there is a significant generation surplus, demand exceeds available supply in all other regions of Nigeria.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1153 MW
8 TO 4 593 MW
3 TO 2 403 MW
7 TO 4 856 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 170 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 626 MW
G
G
G
DISCOS
2 TO 1 1505 MW
4 TO 3 0 MW
G
G
Diagram created using'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2020\Master 2020 model Yash.sav''D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yash.sld'
GG
TCN 2020 MODELDISCO DEMANDSAT, JUL 14 2018 21:56
3 TO 5 935 MW
1 TO 9 331 MW
GG
5 TO 6 -85 MW
10 TO 6 0 MW
5 TO 10 0 MW
6 TO 11 219 MW
G
4 TO 9 602 MW
4 TO 1 875 MW
G
G
1.016
1.008
286
6
1.013
1.035
1.040
278 5
278 5
278 5
278 5
83004IK OT -E K P E NE _
73006
UGWUA JI_3
73001ONIT S HA 3
73005
A S A B A _3
1.041
1.023
352
5
1.038
296
21296
21
1. 04973003
MA K URDI_3
1.050
1
1.037
28 20
28 20
1
1.038
35 8
39
35 8
39
1.03570 47
1. 042
179 23
179 23
33007GWA GW B B 1
0.992
585
67
585
67
601
19
0.980
23005
A K URE 3
0.995
1.014
319 16
84
87
23001
OS OGB O 3
0.999
231
19
231
19
153
15
1
1.007
54
55
1.033
80
90
80
90
244
146
2
3
23003GA NMO 3
23002
OMOT OS HO3
33002
B K E B B I 3 1.051
1.0331.045
134
12
135
12
93
56 93
56
108 41
0. 957
297
85
0.987
0.968
1
2
0.976
216
29 216
29
216
29
216
29
13003
IK E JA W 3
13005OLORUNS OGO3
13029
OGIJO 3
0.971
195
29 195
29
22 8
38
22 8
38
13030
MF M 3
0.964
123
65 123
65
0.972
21 8
10 6
21 8
10 6
105
68
105
68
1.018
172 61
174
23
1
0 52
2
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0
63007
DA MA T URU 3 1.020
123
48
63005
MA IDUGURI 3 0.983
42
88
2
0
72
0. 981
192
49
192
49
218
158 218
158
0
14 7
19 4
15
13002E GB IN 3
0.966
0.970
249
90
0.974
84
130
84
130
28 2
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28 2
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0.977
114
25
114
25
0.978
115
1
115
1
183
27 183
27
298
19
298
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13025
E P E 3
13000
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13031
OK O_OB A _313034
LE K K I 330
13027
A LA GB ON_3
13001A K A NGB A 3
1.028
158
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83007
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217
49
217
49
190
4 190
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1. 038
103
34 103
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1. 030
48 67 48 67
1.037
504
504
83010
IK OT A B A S I_3
1.048
50
11 50
11
83000A F A M IV 3
83005
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1.033
25 37
114
61
114
61
1. 045
356
80
356
80
323 63
323 63
73004
A LIA DE _3
63001JOS 3
1.030
63 763 7
73010
A B A K A LIK I_3
1.003
96 34
0 75
63002Y OLA 3
1.000
53001K A NO 3
1.010
2
3
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0
1.010
221
36
53005
K A NO_NE W330
1.025
276
25
53003Z A RIA _330
53000
K A DUNA 3
53002K A T S INA 3
1.010
74
25
75
42
74
25 75
42
0.973
85 65
85
6513032
NE W_A GB A RA _3
0.962
26 2
8
1260
1
23000
A Y E DE 3
1.039
43000A JA OK UT A 3
43008
LOK OJA _3
43002
B E NIN 3
1.020 304
6
43001A LA DJA 3
43003
DE LT A IV 3
1.014
30 4
6
202
22
202
22
202
22
43004
S A P E LE 3
43011B _NORT H_3
1.039 224 3
224 3
43005GE RE GU
1.043
8
208
20
43009
OB A JA NA _3
1.024
388 1
388 1
83006E GB E MA _3
83009OMOK U_3
83008CA LA B A R_P S _3
83003A DIA GB O_3
63000
GOMB E 3
313
14
2
1 2
33020
S HIRORO 3
33008WE S T MA IN_3
73000NHA V E N 3
1.000
53004F UNT UA 3
1.000
53007
T MA F A RA 3
1.000
53008
GUS A U 3
33021K A INJI 3
1.04524
13
33005
K A INJI G.S .3
33003JE B B A T .S .3
274
10
276
24
249
90
108 41
28
601.037
12
52
247
45
33009
Z UNGE RU
33004
JE B B A G.S .3
33022
A P O_NE W 3
1.050
33023LA F IA 3
1.057
229 15
23 2
46
311
61
311
61
54
43 54
43
63003
B A UCHI 3 1.044
173 62
176
23
63008
MA MB ILA 3
1.000
1.038
161 4
161 4
1. 000
43006E F F URUN 3
286
6
73002OK P A I 3
1.018
1.018
265 15
73030
IHIA LA 3
23006IB A DA N
1.000
13026OK E _A RO_3
388
23
53012
DUT S E 3
1.000
53011
K A Z A URE 3
1.000
1
2
0 75
1.000
63009WUK A RI
33006
S OK OT O 3
1.000
22
11
22
11
83001A LA OJI NIP P 3
73007NNE WI 3
0
32 9
30
338
1
2
1
13004
S A K E T E 3
1.014
1.000
13028A RIGB A JO
63006
JA LINGO_3
33010ZABORI
1.000
SW 0
13012PARAS
0.978
67
23 6723
67
32
67
32
63015M AYOBELWA 1.004 2
6
4
117
121
117
114
246
7
244
65
247
24
243
48
71
26
72
105
21
1
62
21
1
46
21
1
62
21
1
46
171
36
173
15
43007
A Z URA
66
24
66
96
200
11
200
11
202
11
202
11
43010E T HIOP E
0.964
69
1010
141
44 141
44
69
13035
IJORA 3
1.000
187
1
32021NIA ME Y 1
0.954
1
40 1
52010GA Z OUA 1
SW
32
Export 387 MW
Total Generation 9421 MWNigeria Load 8637 MW
Genera tion from H PP 1501 MW
Generation per DISCO Loads per DISCO
3-Abuja 866 MW
7-Enugu 924 MW
2-Ibadan 1104 MW
1-Ikeja 1166 MW
6-Jos 309 MW
5-Kaduna 495 MW
10-Kano 708 MW
11-Yola 230 MW
3-Abuja 1979 MW
4-Benin 1775 MW
9-Eko 0 MW
7-Enugu 796 MW
2-Ibadan 476 MW
1-Ikeja 735 MW
6-Jos 105 MW
5-Kaduna 344 MW
10-Kano 9 MW
8-Pt Harco 3202 MW
11-Yola 0 MW
Genera tion from PV 200 MW
Total Load 9024 MW
9-Eko 1087 MW
8-Pt Harco 794 MW
4-Benin 954 MW
1
1
1
1
1
1
1.037
0.975
0.912
1.1
0.85
Vo
lta
ge
(p
u)
7-32
To supply load to areas with little or no generation such as the North-East, long 330 kV transmission lines are built (radial system), which are then prone to voltage regulation problems. Moreover, the excessive reactive power flowing through these lines necessitates large reactive power compensation equipment (reactors) at the corresponding substations (Kano, Gombe, Maiduguri).
Any addition of more 330 kV lines running in parallel, as planned, may require additional compensation equipment, as of Yola and Jalingo and possibly elsewhere to limit the overvoltages due to line charging currents.
The general profile of power flows in the TCN system is shown graphically in Figure 7-4.4
Source: JICA Study Team
Figure 7-4.4 Power flows in the TCN system
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1153 MW
8 TO 4 593 MW
3 TO 2 403 MW
7 TO 4 856 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 170 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 626 MW
G
G
G
DISCOS
2 TO 1 1505 MW
4 TO 3 0 MW
G
G
Diagram created using'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2020\Master 2020 model Yash.sav''D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yash.sld'
GG
TCN 2020 MODELDISCO DEMANDSAT, JUL 14 2018 21:56
3 TO 5 935 MW
1 TO 9 331 MW
GG
5 TO 6 -85 MW
10 TO 6 0 MW
5 TO 10 0 MW
6 TO 11 219 MW
G
4 TO 9 602 MW
4 TO 1 875 MW
G
G
1.016
1.008
286
6
1.013
1.035
1.040
278 5
278 5
278 5
278 5
83004IK OT -E K P E NE _
73006
UGWUA JI_3
73001ONIT S HA 3
73005
A S A B A _3
1.041
1.023
352
5
1.038
296
21296
21
1. 04973003
MA K URDI_3
1.050
1
1.037
28 20
28 20
1
1.038
35 8
39
35 8
39
1.03570 47
1. 042
179 23
179 23
33007GWA GW B B 1
0.992
585
67
585
67
601
19
0.980
23005
A K URE 3
0.995
1.014
319 16
84
87
23001
OS OGB O 3
0.999
231
19
231
19
153
15
1
1.007
54
55
1.033
80
90
80
90
244
146
2
3
23003GA NMO 3
23002
OMOT OS HO3
33002
B K E B B I 3 1.051
1.0331.045
134
12
135
12
93
56 93
56
108 41
0. 957
297
85
0.987
0.968
1
2
0.976
216
29 216
29
216
29
216
29
13003
IK E JA W 3
13005OLORUNS OGO3
13029
OGIJO 3
0.971
195
29 195
29
22 8
38
22 8
38
13030
MF M 3
0.964
123
65 123
65
0.972
21 8
10 6
21 8
10 6
105
68
105
68
1.018
172 61
174
23
1
0 52
2
0 52SW
0
63007
DA MA T URU 3 1.020
123
48
63005
MA IDUGURI 3 0.983
42
88
2
0
72
0. 981
192
49
192
49
218
158 218
158
0
14 7
19 4
15
13002E GB IN 3
0.966
0.970
249
90
0.974
84
130
84
130
28 2
10 8
28 2
10 8
0.977
114
25
114
25
0.978
115
1
115
1
183
27 183
27
298
19
298
19
13025
E P E 3
13000
A JA 3
13031
OK O_OB A _313034
LE K K I 330
13027
A LA GB ON_3
13001A K A NGB A 3
1.028
158
30
6
64
1
33001K A T A MP E 3
1.033
61 861 8
1.047
201 20
201 20
83007
ONNIE _3
1.038
217
49
217
49
190
4 190
4
1
83002
A LA OJI 3
1.040121
12 121
12 184
36
222
9222
9 184
36
1. 038
103
34 103
34
1. 030
48 67 48 67
1.037
504
504
83010
IK OT A B A S I_3
1.048
50
11 50
11
83000A F A M IV 3
83005
OWE RRI_3
1.033
25 37
114
61
114
61
1. 045
356
80
356
80
323 63
323 63
73004
A LIA DE _3
63001JOS 3
1.030
63 763 7
73010
A B A K A LIK I_3
1.003
96 34
0 75
63002Y OLA 3
1.000
53001K A NO 3
1.010
2
3
S W
0
1.010
221
36
53005
K A NO_NE W330
1.025
276
25
53003Z A RIA _330
53000
K A DUNA 3
53002K A T S INA 3
1.010
74
25
75
42
74
25 75
42
0.973
85 65
85
6513032
NE W_A GB A RA _3
0.962
26 2
8
1260
1
23000
A Y E DE 3
1.039
43000A JA OK UT A 3
43008
LOK OJA _3
43002
B E NIN 3
1.020 304
6
43001A LA DJA 3
43003
DE LT A IV 3
1.014
30 4
6
202
22
202
22
202
22
43004
S A P E LE 3
43011B _NORT H_3
1.039 224 3
224 3
43005GE RE GU
1.043
8
208
20
43009
OB A JA NA _3
1.024
388 1
388 1
83006E GB E MA _3
83009OMOK U_3
83008CA LA B A R_P S _3
83003A DIA GB O_3
63000
GOMB E 3
313
14
2
1 2
33020
S HIRORO 3
33008WE S T MA IN_3
73000NHA V E N 3
1.000
53004F UNT UA 3
1.000
53007
T MA F A RA 3
1.000
53008
GUS A U 3
33021K A INJI 3
1.04524
13
33005
K A INJI G.S .3
33003JE B B A T .S .3
274
10
276
24
249
90
108 41
28
601.037
12
52
247
45
33009
Z UNGE RU
33004
JE B B A G.S .3
33022
A P O_NE W 3
1.050
33023LA F IA 3
1.057
229 15
23 2
46
311
61
311
61
54
43 54
43
63003
B A UCHI 3 1.044
173 62
176
23
63008
MA MB ILA 3
1.000
1.038
161 4
161 4
1. 000
43006E F F URUN 3
286
6
73002OK P A I 3
1.018
1.018
265 15
73030
IHIA LA 3
23006IB A DA N
1.000
13026OK E _A RO_3
388
23
53012
DUT S E 3
1.000
53011
K A Z A URE 3
1.000
1
2
0 75
1.000
63009WUK A RI
33006
S OK OT O 3
1.000
22
11
22
11
83001A LA OJI NIP P 3
73007NNE WI 3
0
32 9
30
338
1
2
1
13004
S A K E T E 3
1.014
1.000
13028A RIGB A JO
63006
JA LINGO_3
33010ZABORI
1.000
SW 0
13012PARAS
0.978
67
23 6723
67
32
67
32
63015M AYOBELWA 1.004 2
6
4
117
121
117
114
246
7
244
65
247
24
243
48
71
26
72
105
21
1
62
21
1
46
21
1
62
21
1
46
171
36
173
15
43007
A Z URA
66
24
66
96
200
11
200
11
202
11
202
11
43010E T HIOP E
0.964
69
1010
141
44 141
44
69
13035
IJORA 3
1.000
187
1
32021NIA ME Y 1
0.954
1
40 1
52010GA Z OUA 1
SW
32
Export 387 MW
Total Generation 9421 MWNigeria Load 8637 MW
Genera tion from H PP 1501 MW
Generation per DISCO Loads per DISCO
3-Abuja 866 MW
7-Enugu 924 MW
2-Ibadan 1104 MW
1-Ikeja 1166 MW
6-Jos 309 MW
5-Kaduna 495 MW
10-Kano 708 MW
11-Yola 230 MW
3-Abuja 1979 MW
4-Benin 1775 MW
9-Eko 0 MW
7-Enugu 796 MW
2-Ibadan 476 MW
1-Ikeja 735 MW
6-Jos 105 MW
5-Kaduna 344 MW
10-Kano 9 MW
8-Pt Harco 3202 MW
11-Yola 0 MW
Genera tion from PV 200 MW
Total Load 9024 MW
9-Eko 1087 MW
8-Pt Harco 794 MW
4-Benin 954 MW
1
1
1
1
1
1
300
200
100
400
0
MW
Flo
w
TCN330kV TRANSMISSINO NETWORK
TCN2020MODEL
Total Generation: 9421 MW
Nigeria Load: 8637 MW
Export: 387 MW
Total Load: 9024 MW
Generation from PV: 200 MW
Generarion from HPP: 1501 MW
7-33
7-4-2-2 Dry Season Peak Case
(1) Prerequisites for analysis
(a) Generation from PVs = 0 MW and (b) Reduced generation from HPP plants of 1,322 MW)
The running generation and load for each DisCo are shown in Figure 7-4.5 and Table 7-4.6. The total running generation to meet the load and losses is 9,417 MW.
Source: JICA Study Team
Figure 7-4.5 Dry Season Peak Generation and Load Per DisCo
Table 7-4.6 2020 Dry Season Peak - Running Generation
Bus Name PGen
(MW) Bus Name
PGen
(MW) Bus Name
PGen
(MW)
AARON PV 15.000 0 EGBIN ST 2 16.000 171.4 NOVA SOLA PV33.000 0
AES BERG202 11.000 0 EGBIN ST 3 16.000 171.4 NSCP PV 15.000 0
AES BERG203 11.000 0 EGBIN ST 4 16.000 171.4 O REN SOL PV15.000 0
AES BERG204 11.000 0 EGBIN ST 5 16.000 171.4 OBAJANA 15.000 0
AES BERG205 11.000 0 EGBIN ST 6 16.000 171.4 OKPAI GT11 11.500 135
AES BERG207 11.000 0 ELEME 15.000 0 OKPAI GT12 11.500 135
AES BERG208 11.000 0 EN ARFICA PV15.000 0 OKPAI ST18 11.500 126
AES BERG209 11.000 0 ETHIOPE 15.000 0 OKPAI_IPPII 11.500 400
AES BERG210 11.000 0 GBARAIN_GTB115.000 102 OLOR NIPPST110.500 108
AES BERG211 11.000 0 GBARAIN_GTB215.000 102 OLOR NIPPST210.500 0
AFAM VI GT1111.500 150 GEN DANGOTE 15.000 0 OLORNIPPGT1110.500 0
AFAM VI GT1211.500 150 GEN_AMADI 15.000 90 OLORNIPPGT1210.500 0
AFAM VI GT1311.500 105 GEN_KADUNA 15.000 194 OLORNIPPGT2110.500 108
AFAM VI ST1011.500 180 GEOMETRIC_AB15.000 0 OLORNIPPGT2210.500 108
AFAM1GT1-2 11.500 0 GER NIPPGT2110.500 100 OLORUNSO GT110.500 22
AFAM1GT3-4 11.500 0 GER NIPPGT2210.500 0 OLORUNSO GT210.500 22
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotalfor
NigeriaExport Totals
Run Genaration 1110 476 1750 1775 194 105 796 3202 0 9 0 9417
Load 1166 1104 866 954 495 309 924 794 1087 708 230 8637 387 9024
Gen deficit/surplus -56 -628 884 821 -301 -204 -128 2408 -1087 -699 -230 393
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
3500
MW
Dry season Peak
7-34
Bus Name PGen
(MW) Bus Name
PGen
(MW) Bus Name
PGen
(MW)
AFAM2 GT5-6 11.500 54 GER NIPPGT2310.500 100 OLORUNSO GT310.500 20
AFAM2GT 7-8 11.500 54 GEREGU GT11 10.500 83 OLORUNSO GT410.500 0
AFAM3 GT9-1011.500 54 GEREGU GT12 10.500 83 OLORUNSO GT510.500 22
AFAM3GT11-1211.500 54 GEREGU GT13 10.500 83 OLORUNSO GT610.500 22
AFAM4GT13-1411.500 67 GR COWRI PV 33.000 0 OLORUNSO GT710.500 22
AFAM4GT15-1611.500 0 GURARA GBUS 11.500 0 OLORUNSO GT810.500 22
AFAM4GT17-1811.500 0 IBOM GT1 11.500 34 OMOKU1 GT1 15.000 68
AFAMV GT 19 11.500 125 IBOM GT2 11.500 34 OMOKU1 GT2 15.000 50
AFAMV GT 20 11.500 125 IBOM GT3 11.500 34 OMOKU2 GT1 15.000 102
AFRINEGIA PV15.000 0 IBOM II 11.500 260 OMOKU2 GT2 15.000 102
ALAOJI_GTB1 15.000 81 IHOVBOR_GTB115.000 110 OMOTNIPP GT110.500 108
ALAOJI_GTB2 15.000 81 IHOVBOR_GTB215.000 110 OMOTNIPP GT210.500 108
ALAOJI_GTB3 15.000 81 IHOVBOR_GTB315.000 110 OMOTNIPP GT310.500 0
ALAOJI_GTB4 15.000 81 IHOVBOR_GTB415.000 0 OMOTNIPP GT410.500 0
ALAOJI_STB1 17.000 0 IJORA GT 4-611.000 0 OMOTOSO GT1 10.500 70
ALAOJI_STB1 17.000 0 JBS WIND 15.000 70 OMOTOSO GT3 10.500 66
ALSCON GT1 11.500 0 JEBBA 2G1 16.000 90 OMOTOSO GT5 10.500 0
ALSCON GT2 11.500 0 JEBBA 2G2 16.000 90 OMOTOSO GT7 10.500 0
ANJEED PV 15.000 0 JEBBA 2G3 16.000 0 PAN AFRIC PV15.000 0
ASCO G1 11.000 0 JEBBA 2G4 16.000 0 PARAS 11.500 0
ASCO G2 11.000 0 JEBBA 2G5 16.000 0 PARASGT1-9 11.000 81
AZURA GT 15.000 280 JEBBA 2G6 16.000 90 QUAINT PV 15.000 0
AZURA ST 15.000 125 KAINJ 1G11 16.000 90 RIVERS _GT1 10.500 172
BRESSON GTS 11.000 0 KAINJ 1G12 16.000 90 RIVERS_GT2 10.500 0
CALABAR_GTB115.000 100 KAINJ 1G5 16.000 45 SAP_NIPP_GT115.800 77
CALABAR_GTB215.000 102 KAINJ 1G6 16.000 45 SAP_NIPP_GT215.800 77
CALABAR_GTB315.000 102 KAINJ 1G7-8 16.000 160 SAP_NIPP_GT315.800 76
CALABAR_GTB415.000 0 KAINJ 1G9-1016.000 0 SAP_NIPP_GT415.800 76
CALABAR_GTB515.000 0 KASHIMB HP2 15.000 0 SAPELE GT1-215.800 0
CT COSMO PV 15.000 0 KASHIMB HP3 15.000 0 SAPELE GT3-415.800 0
DELT3 GT9-1111.500 38 KASHIMB HP4 15.000 0 SAPELE ROT 15.800 0
DELT3GT12-1411.500 0 KASHIMB HPP 15.000 21 SAPELE ST1 15.800 0
DELTA GT 15 11.500 96 KAZAURE PV1 11.000 0 SAPELE ST2 15.800 0
DELTA GT16 11.500 96 KAZAURE PV1011.000 0 SAPELE ST3 15.800 0
DELTA GT17 11.500 97 KAZAURE PV2 11.000 0 SAPELE ST4 15.800 0
DELTA GT18 11.500 0 KAZAURE PV3 11.000 0 SAPELE ST5 15.800 0
DELTA GT19 11.500 0 KAZAURE PV4 11.000 0 SAPELE ST6 15.800 0
DELTA GT20 11.500 0 KAZAURE PV5 11.000 0 SHIROR 411G116.000 140
DELTA1 GT1 11.500 0 KAZAURE PV6 11.000 0 SHIROR 411G216.000 140
DELTA1 GT2 11.500 0 KAZAURE PV7 11.000 0 SHIROR 411G316.000 0
DELTA2 GT3-511.500 45 KAZAURE PV8 11.000 0 SHIROR 411G416.000 0
DELTA2 GT6-811.500 10 KAZAURE PV9 11.000 0 SINOSUN PV 15.000 0
DKOWA G1 11.000 14 KT WF 33 33.000 9 SYNER GEN PV15.000 0
DUSABLE PV 15.000 0 KVKPOWER PV 15.000 0 ZUNGE_G1 16.000 107
EGBEMA_GTB1 15.000 102 LAFARAGE 1 11.000 0 ZUNGE_G2 16.000 107
EGBEMA_GTB2 15.000 102 MIDBAND PV 15.000 0 ZUNGE_G3 16.000 0
EGBEMA_GTB3 15.000 102 NOVA SCOT PV132.00 0 ZUNGE_G4 16.000 107
EGBIN ST 1 16.000 171.4 NOVA SOLA PV15.000 0
Source: JICA Study Team
7-35
The power flows are shown in Figure 7-4.6.
Source: JICA Study Team
Figure 7-4.6 2020 Dry Season Peak Power Flows in 330 kV System
(2) Overloads of lines and transformers
The base case (N-0) overloaded 132 kV lines as well as the 330/132 kV and 132/33 kV transformers are listed in Table 7-4.7, Table 7-4.8 and Table 7-4.9.
It should be noted that introducing the 330kV substation at Ijora eliminates the overloads of the 132kV line Alagbon - Ijora and the need to have this line reinforced. It will become even more crucial in subsequent years, so it should be integrated into the system as soon as possible.
Table 7-4.7 2020 Dry Season Peak - Overloaded Lines (base case)
Bus
Number
Bus name Bus
Number
Bus name CKT Contingency
label
Rating
(MVA)
Flow
(MVA)
Loading
(%)
82024 IBOM IPP 1 132.00 82031 IKOT_ABASI 132.00 1 BASE CASE 125.7 182.1 144.8
Source: JICA Study Team
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1194 MW
8 TO 4 563 MW
3 TO 2 223 MW
7 TO 4 792 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETW ORK
G
G
G
G
G
G
6 TO 3 179 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 633 MW
G
G
G
DISCOS
2 TO 1 1242 MW
4 TO 3 0 MW
G
Diagram created using
'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2020\DP 2020 model Yash.sav''D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yash.sld'
GG
TCN 2020 MODEL
DISCO DEMANDSAT, JUL 14 2018 23:19
3 TO 5 1009 MW
1 TO 9 284 MW
GG
5 TO 6 -64 MW
10 TO 6 0 MW
6 TO 11 218 MW
G
4 TO 9 506 MW
4 TO 1 761 MW
G
G
1.016
1.012
265
8
1.014
1.028
1.037
28
8 2
28
8 2
28
8 2
28
8 2
83004
IKOT-EKPENE_
73006
UGWUAJI_3
73001
ONITSHA 3
73005
ASABA_3
1.040
1.025
339
4
1.03728
1
26
28
1
26
1.03173003
MAKURDI_3
1.034
1
1.025
22
26
21
26
1
1.030
384
26
384
26
1.02696
53
1.037
23
8
18
23
8
18
33007GWAGW BB1
0.999
481
44 481
44
491
3
0.985
23005AKURE 3
0.999
1.017
321 12
112
81
23001
OSOGBO 3
1.004
233
16
233
16
155
17
1
1.010
27
58
1.033
31
88
31
88
16
0
14
7
2
3
23003GANMO 3
23002
OMOTOSHO3
33002
BKEBBI 3 1.046
1.0331.045
134
12
135
12
82
55 82
55
11
9
43
0.964
213
96
0.994
0.974
1
2
0.983
189
37 189
37
189
37
189
37
13003
IKEJA W 3
13005OLORUNSOGO3
13029
OGIJO 3
0.978
186
34 186
34
218
41
218
41
13030
MFM 3
0.970
103
68 103
68
0.978
278
91
278
91
160
52
160
52
0.999
17
2
63
17
5
17
1
0 50
2
0 50
SW
0
63007
DAMATURU 3 0.997
12
2
41
2
0.988
127
62
127
62
218
155 218
155
73
137
118
17
13002EGBIN 3
0.972
0.977
273
83
0.980
155
107
155
107
307
101
307
101
0.984
96
31
96
31
0.985
96
6
96
6
154
37 154
37
251
33
251
33
13025
EPE 3
13000
AJA 3
13031
OKO_OBA_313034LEKKI 330
13027
ALAGBON_3
13001
AKANGBA 3
1.018
168
32
8
68
1
33001
KATAMPE 3
1.023
62
1062
10
1.047
20
2
21
20
2
21
83007
ONNIE_3
1.037
22
8
40
22
8
40
19
1
5 19
1
5
1
83002ALAOJI 3
1.03912
6
16
12
6
16
19
3
29
20
8
14
20
8
14
19
3
29
1.036
10
3
30
10
3
30
1.028
48 6
7 4
8 67
1.034
50
4
50
4
83010
IKOT ABASI_3
1.047
50
11
50
11
83000
AFAM IV 3
83005
OWERRI_3
1.026
18
18
93
51
93
51
1.030
40
0
57
40
0
57
36
5
59
36
5
59
73004ALIADE_3
63001
JOS 3
1.023
63
663
6
73010
ABAKALIKI_3
0.980
96
29
0 72
63002
YOLA 3
1.000
53001
KANO 3
0.997
2
3
SW
0
0.998
221
38
53005
KANO_NEW330
1.013
277
29
53003
ZARIA_330
53000KADUNA 3
0.999
74
22
75
43
22 75
43
0.981
77
66 7
7
66
13032
NEW_AGBARA_3
0.968
262
9
1260
1
23000AYEDE 3
1.036
43000
AJAOKUTA 3
43008LOKOJA _3
43002BENIN 3
1.023 29
1
7
43001ALADJA 3
43003
DELTA IV 3
1.017
291
7
197
19
197
19
197
19
43004
SAPELE 3
43011B_NORTH_3
1.036
22
4
12
22
4
12
43005
GEREGU
1.038
8
208
20
43009OBAJANA_3
1.024
38
8 1 3
88 1
83006
EGBEMA_3
83009
OMOKU_3
83008
CALABAR_PS_3
83003
ADIAGBO_3
63000GOMBE 3
29
2
22
2
1 2
33020
SHIRORO 3
33008
WESTMAIN_3
73000
NHAVEN 3
1.000
53004FUNTUA 3
1.000
1.000
53008GUSAU 3
33021KAINJI 3
1.04524
13
33005
KAINJI G .S.3
33003
JEBBA T.S.3
253
13
255
30
273
83
11
9
43
21
531.030
93
47
25
2
35
33009
ZUNGERU
33004
JEBBA G .S.3
33022APO_NEW 3
1.033
33023
LAFIA 3
1.039
26
9 1
273
49
35467
354
67
56
38 56
38
63003BAUCHI 3 1.027
17
4
63
17
7
17
63008
MAMBILA 3
1.000
1.037
16
1 61
61 6
1.000
43006EFFURUN 3
265
8
73002
OKPAI 3
1.018
1.018
25
1
16
73030
IHIALA 3
23006IBADAN
1.000
13026
OKE_ARO_3
37
7
21
1.000
1
2
0 72
1.000
63009
WUKARI
1.000
23
11
23
11
83001ALAOJI NIPP3
73007
NNEWI 3
0
329
30
338
1
2
1
13004
SAKETE 3
1.017
1.000
13028ARIGBAJO
63006JALINGO_3
33010ZABORI
1.000
SW
0
13012PARAS
0.984
16
8 16
8
16
17
16
17
63015MAYOBELWA 0.982
25
3
156
112
15
6
10
6
24 7
4
24 5
64
24 8
22
24 3
47
128 24
129
98
272
50
271
38
272
50
271
38
171
34
173
15
43007
AZURA
12
5
22
12
6
90
200
6
20
0
7
202
6
20
2
6
43010
ETHIOPE
0.971
92
44
165
37 165
37
92
13035
IJORA 3
Export 387 MW
Total Generation 9417 MWNigeria Load 8637 MW
Generation from HPP 1322 MW
Generation per DISCO Loads per DISCO
3-Abuja 866 MW
7-Enugu 924 MW
2-Ibadan 1104 MW
1-Ikeja 1166 MW
6-Jos 309 MW
5-Kaduna 495 MW
10-Kano 708 MW
11-Yola 230 MW
3-Abuja 1750 MW
4-Benin 1775 MW
9-Eko 0 MW
7-Enugu 796 MW
2-Ibadan 476 MW
1-Ikeja 1110 MW
6-Jos 105 MW
5-Kaduna 194 MW
10-Kano 9 MW
8-Pt Harco 3202 MW
11-Yola 0 MW
Generation from PV 0 MW
Total Load 9024 MW
9-Eko 1087 MW
8-Pt Harco 794 MW
4-Benin 954 MW
1
1
1
1
1
1
300
200
100
400
0
MW
Flo
w
TCN330kV TRANSMISSINO NETWORK
TCN2020MODEL
Total Generation: 9421 MW
Nigeria Load: 8637 MW
Export: 387 MW
Total Load: 9024 MW
Generation from PV: 200 MW
Generarion from HPP: 1501 MW
7-36
Table 7-4.8 2020 Dry Season Peak - Overloaded 330/132 kV transformers (base case)
Bus
Number Bus Name
Voltage
(kV) Area
Bus
Number Bus Name
Wind
Number CKT
Loading
(MVA)
Rating
(MVA)
Loading
(%)
330/132 kV 3-W and A/T
23003 GANMO 3 330 2 3WNDTR GANMO TR2A 1 1 157.4 150 104.9
33002 BKEBBI 3 330 3 3WNDTR B_KEBBI T1 1 1 176.9 150 118
43002 BENIN 3 330 4 3WNDTR BENIN TR1 1 1 156 150 104
43002 BENIN 3 330 4 3WNDTR BENIN TR2 1 1 156 150 104
43002 BENIN 3 330 4 3WNDTR BENIN TR3 1 1 156 150 145.6
43011 B.NORTH_3 330 4 3WNDTR BENIN 9T1 2 1 88 67.5 131.6
Source: JICA Study Team
Table 7-4.9 2020 Dry Season Peak - Overloaded 2-winding transformers (base case)
Bus
Number Bus Name
Voltage
(kV) Area
Bus
Number Bus Name
Voltage
(kV) cct
Loading
(MVA)
Rating
(MVA)
Loading
(%)
132/33 and 132/11 kV 2-W transformers
32017 SULEJA 1 132 3 36016 SULEJA 11 11 1 18.6 7.5 247.6
42004 BENIN 1 132 4 45029 BENIN T22 33 33 1 85.9 60 143.1
52001 KANO 1 132 5 55058 KUMB T3
MOB 33 3 41.9 30 139.6
42004 BENIN 1 132 4 45031 BENIN T24 33 33 1 82.9 60 138.1
42004 BENIN 1 132 4 45030 BENIN T23 33 33 1 80.9 60 134.8
52016 FUNTUA 1 132 5 56000 FUNTUA 11 11 1 9.6 7.5 127.6
42005 B_N0RTH 1 132 4 45015 B_NORTH_33 33 1 73.9 60 123.2
22015 OMUARAN
1 132 2 25016 OMUARAN 33 33 1 33.4 30 111.4
52016 FUNTUA 1 132 5 55003 FUNTUA 33 33 1 33 30 109.9
52016 FUNTUA 1 132 5 56005 FUNTUA T2 11 2 7.9 7.5 105.9
22013 OFFA 1 132 2 25015 OFFA 33 33 1 31.8 30 105.8
12029 OJO 1 132 1 15030 OJO 33 33 1 30.4 30 101.4
Source: JICA Study Team
7-4-2-3 Wet Season Peak Case
(1) Prerequisites for analysis
(a) Generation from PVs = 0 MW and (b) Normal generation from HPP plants of 2,100 MW,
The running generation and load for each DisCo are shown in Figure 7-4.7.
7-37
Source: JICA Study Team
Figure 7-4.7 Wet Season Peak Generation and Load Per DisCo
(2) Overloads of lines and transformers
The base case (N-0) overloaded 132 kV lines are listed in Table 7-4.10.
Table 7-4.10 2020 Wet Season Peak - Overloaded Lines (base case)
Bus
Number
Bus name Bus
Number
Bus name CKT Contingency
label
Rating
(MVA)
Flow
(MVA)
Loading
(%)
82024 IBOM IPP 1 132.00 82031 IKOT_ABASI 132.00 1 BASE CASE 125.7 182.6 145.2
Source: JICA Study Team
No new overloaded lines are reported, in addition to those overloaded in the Dry Season Peak case. The same applies for the overloaded transformer.
7-4-2-4 Dry Season Off- Peak Case
(1) Prerequisites for analysis
(a) Generation from PVs = 400 MW and (b) Reduced generation from HPP plants of 1,100 MW,
The running generation and load for each DisCo are shown in Figure 7-4.8.
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotalfor
NigeriaExport Totals
Run Genaration 692 476 2120 1775 224 134 796 3202 0 9 0 9428
Load 1166 1104 866 954 495 309 924 794 1087 708 230 8637 387 9024
Gen deficit/surplus -474 -628 1254 821 -271 -175 -128 2408 -1087 -699 -230 404
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
3500
MW
Wet season Peak
7-38
Source: JICA Study Team
Figure 7-4.8 Dry Season Off-Peak Generation and Load per DisCo
(2) Overloads of lines and transformers
The base case (N-0) overloaded 132 kV lines are listed in Table 7-4.11.
Table 7-4.11 2020 Dry Season Off-Peak - Overloaded Lines (base case)
Bus Number
Bus name Bus
Number Bus name CKT
Contingency label
Rating (MVA)
Flow (MVA)
Loading (%)
82024 IBOM IPP 1 132.00 82031 IKOT_ABASI 132.00 1 BASE CASE 125.7 189.6 150.9
Source: JICA Study Team
The overloaded line(s) are the same as in the Dry Season Peak case.
The overloaded transformers are fewer than the Dry Season Peak case, as shown in the following tables, Table 7-4.12 and Table 7-4.13.
Table 7-4.12 2020 Dry Season Off-Peak - Overloaded 330/132 kV transformers (base case)
Bus Number
Bus Name
Voltage (kV)
Area Bus
Number Bus
Name Wind CKT
Loading (MVA)
Rating (MVA)
Loading (%)
43011 B.NORTH_3 330 4 3WNDTR BENIN 9T1 2 1 74.3 67.5 110
Source: JICA Study Team
Table 7-4.13 2020 Dry Season Off-Peak - Overloaded 2-winding transformers (base case)
Bus Number
Bus Name
Voltage (kV)
Area Bus
Number Bus
Name Voltage
(kV) cct
Loading (MVA)
Rating (MVA)
Loading (%)
132/33 and 132/11 kV 2-W transformers
32017 SULEJA 1 132 3 36016 SULEJA 11 11 1 15.5 7.5 206
42004 BENIN 1 132 4 45029 BENIN T22 33 33 1 72.4 60 120.6
52001 KANO 1 132 5 55058 KUMB T3 33 3 34.9 30 116.3
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotal for NigeriaExport Totals
Run Genaration 97 476 1170 1775 364 105 795 3202 0 149 0 8133
Load 991 938 736 811 421 263 785 675 924 602 195 7341 387 7728
Gen deficit/surplus -894 -462 434 964 -57 -158 10 2527 -924 -453 -195 405
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
3500
MW
Dry season Off-Peak
7-39
Bus Number
Bus Name
Voltage (kV)
Area Bus
Number Bus
Name Voltage
(kV) cct
Loading (MVA)
Rating (MVA)
Loading (%)
MOB
42004 BENIN 1 132 4 45031 BENIN T24 33 33 1 69.9 60 116.4
42004 BENIN 1 132 4 45030 BENIN T23 33 33 1 68.2 60 113.7
52016 FUNTUA 1 132 5 56000 FUNTUA 11 11 1 9.6 7.5 127.6
42005 B_N0RTH 1 132 4 45015 B_NORTH_33 33 1 62.4 60 104
Source: JICA Study Team
7-4-2-5 Wet Season Off-Peak Case
(1) Prerequisites for analysis
(a) Generation from PVs = 400 MW and
(b) Normal generation from HPP plants of 2,100 MW,
The running generation and load for each DisCo are shown in Figure 7-4.9.
Source: JICA Study Team
Figure 7-4.9 Wet Season Off-Peak Generation and Load Per DisCo
(2) Overloads of lines and transformers
The base case (N-0) overloaded 132 kV lines are listed in Table 7-4.14.
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotalfor
NigeriaExport Totals
Run Genaration 129 476 2135 1469 364 139 796 2382 0 149 0 8039
Load 991 938 736 811 421 263 785 675 924 602 195 7341 387 7728
Gen deficit/surplus -862 -462 1399 658 -57 -124 11 1707 -924 -453 -195 311
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
3500
MW
Wet season Off- Peak
7-40
Table 7-4.14 2020 Wet Season Off-peak - Overloaded Lines (base case)
Bus Number
Bus name Bus
Number Bus name CKT
Contingency label
Rating (MVA)
Flow (MVA)
Loading (%)
82024 IBOM IPP 1 132.00 82031 IKOT_ABASI 132.00 1 BASE CASE 125.7 189.4 150.7
Source: JICA Study Team
No new overloaded lines are reported, in addition to those overloaded in the Dry Season Peak case.
The same applies for the overloaded transformer.
7-4-3 2020 Contingency Analysis Load-flow Results
An N-1 contingency analysis using ACCC in PSS/E has been carried out for the 330 and 132 kV transmission lines, using their RATE B as short-term overload ratings.
The N-1 criterion is not applicable for transformer circuits. The results are summarized in tables fromTable 7-4.15 to Table 7-4.19.
Table 7-4.15 Non-converged cases
Contingency LINE Bus
Number Bus Name
Voltage (kV)
Bus Number
Bus name CKT
SINGLE 53001-53005(2) OPEN LINE 53001 KANO 3 330 53005 KANO_NEW330 2
SINGLE 63000-63002(1) OPEN LINE 63000 GOMBE 3 330 63002 YOLA 3 1
SINGLE 63000-63007(1) OPEN LINE 63000 GOMBE 3 330 63007 DAMATURU 3 1
SINGLE 32003-32041(3) OPEN LINE 32003 BKEBBI 1 132 32041 KVKPOWER PV 3
SINGLE 32016-32041(3) OPEN LINE 32016 SOKOTO 1 132 32041 KVKPOWER PV 3
SINGLE 52015-52016(1) OPEN LINE 52015 ZARIA 1 132 52016 FUNTUA 1 1
Source: JICA Study Team
In the above contingency cases of the loss of 330 kV lines from Gombe to Yola and Damaturu, the load-flow case did not converge as expected, due to the absence of a second parallel circuit and insufficient support from alternative routes.
Converting to a Double-Circuit will resolve these issues.
The overloads reported for the 132 kV circuits will have to be resolved by either reinforcing these lines or providing new alternative routes for the power flow.
In all N-1 contingencies, a number of 132 kV voltages are lower than the minimum permissible level of 0.8p.u. However, this is due to overloads of the associated 132 kV lines and transformers and the remedial actions for the U/V are linked to the solutions initially required for overloads of these circuits.
7-4-3-1 2020 Dry Season Peak Case-ACCC
The base case and N-1 contingency analysis results are shown in Table 7-4.16.
It can be seen that the loadings of all the 330 kV lines are within their thermal rating limits with the exception of the Double-Circuit 330 kV lines from Benin to Omotosho and from Shiroro to Kaduna.
Table 7-4.16 shows the overloaded 132 kV lines.
7-41
Table 7-4.16 2020 Dry Season Peak - Overloaded Lines (base case and under N-1)
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
330 kV System
None
132 kV System
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 182.1 144.8
82019 OMOKU 1 82036 RUMUSOI 1 2 SINGLE 82019-82036(1) 138.3 219 158.3
82019 OMOKU 1 82036 RUMUSOI 1 1 SINGLE 82019-82036(2) 138.3 219 158.3
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 211.5 152.9
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 203.5 147.1
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 201.9 146
82017 YENAGOA 1 82022 GBARAIN UBIE 2 SINGLE 82017-82022(1) 138.3 191.2 138.2
82017 YENAGOA 1 82022 GBARAIN UBIE 1 SINGLE 82017-82022(2) 138.3 191.2 138.2
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 176.8 127.9
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 176.8 127.9
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 172.5 124.8
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 172.5 124.8
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 172 124.4
82017 YENAGOA 1 82018 AHOADA 1 2 SINGLE 82017-82018(1) 138.3 171.4 123.9
82017 YENAGOA 1 82018 AHOADA 1 1 SINGLE 82017-82018(2) 138.3 171.4 123.9
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 94.7 123.5
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 184.2 122.4
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 184.2 122.4
82007 PHCT MAIN1 82036 RUMUSOI 1 2 SINGLE 82007-82036(1) 138.3 166 120
82007 PHCT MAIN1 82036 RUMUSOI 1 1 SINGLE 82007-82036(2) 138.3 166 120
82000 AFAM 1-2-3 82002 AFAM IV 2 SINGLE 82000-82002(1) 138.3 160.2 115.8
82000 AFAM 1-2-3 82002 AFAM IV 1 SINGLE 82000-82002(2) 138.3 160.2 115.8
52015 ZARIA 1 52016 FUNTUA 1 1 SINGLE 32016-52004(1) 99.3 110.4 111.2
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82005-82024(1) 150.4 166.5 110.7
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82005-82024(2) 150.4 166.5 110.7
Source: JICA Study Team
7-4-3-2 2020 Wet Season Peak case-ACCC
The base case and N-1 contingency analysis results are shown in Table 7-4.17.
Table 7-4.17 2020 Wet Season Peak - Overloaded Lines (base case and under N-1)
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
330 kV System
None
132 kV System
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 182.6 145.2
82019 OMOKU 1 82036 RUMUSOI 1 1 SINGLE 82019-82036(2) 138.3 220 159.1
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 208.8 151
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 201.9 146
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 200.8 145.2
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 200.2 144.8
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 200.2 144.8
82017 YENAGOA 1 82022 GBARAIN UBIE 2 SINGLE 82017-82022(1) 138.3 191.2 138.3
82017 YENAGOA 1 82022 GBARAIN UBIE 1 SINGLE 82017-82022(2) 138.3 191.2 138.3
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 180 130.1
7-42
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 180 130.1
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 98.1 128
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 172.9 125
82017 YENAGOA 1 82018 AHOADA 1 2 SINGLE 82017-82018(1) 138.3 171.5 124
82017 YENAGOA 1 82018 AHOADA 1 1 SINGLE 82017-82018(2) 138.3 171.5 124
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 184.5 122.7
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 184.5 122.7
82007 PHCT MAIN1 82036 RUMUSOI 1 2 SINGLE 82007-82036(1) 138.3 167.1 120.8
82007 PHCT MAIN1 82036 RUMUSOI 1 1 SINGLE 82007-82036(2) 138.3 167.1 120.8
82000 AFAM 1-2-3 82002 AFAM IV 2 SINGLE 82000-82002(1) 138.3 160.2 115.8
82000 AFAM 1-2-3 82002 AFAM IV 1 SINGLE 82000-82002(2) 138.3 160.2 115.8
23002 OMOTOSHO3 43002 BENIN 3 2 SINGLE 23002-43002(1) 855.1 948.8 111
23002 OMOTOSHO3 43002 BENIN 3 1 SINGLE 23002-43002(2) 855.1 948.8 111
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82005-82024(1) 150.4 166.4 110.6
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82005-82024(2) 150.4 166.4 110.6
52015 ZARIA 1 52016 FUNTUA 1 1 SINGLE 32016-52004(1) 99.3 106.3 107
82013 ONNE 1 82040 TRAMADI 2 SINGLE 82013-82040(1) 138.3 139.6 100.9
82013 ONNE 1 82040 TRAMADI 1 SINGLE 82013-82040(2) 138.3 139.6 100.9
Source: JICA Study Team
7-4-3-3 2020 Dry Season Off-Peak Case-ACCC
The base case and N-1 contingency analysis results are shown in Table 7-4.18. The 330 kV lines overloaded under N-1 are shown in red fonts.
Table 7-4.18 2020 Dry Season Off-Peak - Overloaded Lines (base case and under N-1)
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
330 kV
23002 OMOTOSHO3 43002 BENIN 3 2 SINGLE 23002-43002(1) 855.1 1,081.6 126.5
23002 OMOTOSHO3 43002 BENIN 3 1 SINGLE 23002-43002(2) 855.1 1,081.6 126.5
132 kV
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 189.6 150.9
62000 GOMBE 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 151.3 197.2
82019 OMOKU 1 82036 RUMUSOI 1 2 SINGLE 82019-82036(1) 138.3 213.6 154.5
82019 OMOKU 1 82036 RUMUSOI 1 1 SINGLE 82019-82036(2) 138.3 213.6 154.5
62003 YOLA 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 114.4 149.2
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 202.6 146.5
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 202.6 146.5
82017 YENAGOA 1 82022 GBARAIN UBIE 2 SINGLE 82017-82022(1) 138.3 191.5 138.5
82017 YENAGOA 1 82022 GBARAIN UBIE 1 SINGLE 82017-82022(2) 138.3 191.5 138.5
82000 AFAM 1-2-3 82002 AFAM IV 2 SINGLE 82000-82002(1) 138.3 181.4 131.1
82000 AFAM 1-2-3 82002 AFAM IV 1 SINGLE 82000-82002(2) 138.3 181.4 131.1
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 175.5 126.9
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 97.0 126.5
82017 YENAGOA 1 82018 AHOADA 1 2 SINGLE 82017-82018(1) 138.3 174.5 126.2
82017 YENAGOA 1 82018 AHOADA 1 1 SINGLE 82017-82018(2) 138.3 174.5 126.2
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 185.3 123.2
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 185.3 123.2
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 169.9 122.9
82007 PHCT MAIN1 82036 RUMUSOI 1 2 SINGLE 82007-82036(1) 138.3 169.5 122.5
7-43
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
82007 PHCT MAIN1 82036 RUMUSOI 1 1 SINGLE 82007-82036(2) 138.3 169.5 122.5
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 169.1 122.3
82013 ONNE 1 82040 TRAMADI 2 SINGLE 82013-82040(1) 138.3 157.5 113.9
82013 ONNE 1 82040 TRAMADI 1 SINGLE 82013-82040(2) 138.3 157.5 113.9
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 153.1 110.7
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 153.1 110.7
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82005-82024(1) 150.4 155 103.1
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82005-82024(2) 150.4 155 103.1
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 142.4 103
Source: JICA Study Team
7-4-3-4 2020 Wet Season Off-Peak case-ACCC
The base case and N-1 contingency analysis results are shown in Table 7-4.19. The 330 kV lines overloaded under N-1 are shown in red fonts.
Table 7-4.19 2020 Wet Season Off- peak - Overloaded Lines (base case and under N-1)
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
330 kV System
23002 OMOTOSHO3 43002 BENIN 3 2 SINGLE 23002-43002(1) 855.1 944.4 110.4
23002 OMOTOSHO3 43002 BENIN 3 1 SINGLE 23002-43002(2) 855.1 944.4 110.4
132 kV System
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 189.4 150.7
62000 GOMBE 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 153.2 199.7
62003 YOLA 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 116.3 151.6
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 202.5 146.4
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 202.5 146.4
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 98.2 128.1
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 175.5 126.9
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 171.2 123.8
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 184.6 122.7
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 184.6 122.7
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 169.4 122.5
82007 PHCT MAIN1 82014 RIVERS_IPP 2 SINGLE 82007-82014(1) 138.3 155.2 112.2
82007 PHCT MAIN1 82014 RIVERS_IPP 1 SINGLE 82007-82014(2) 138.3 155.2 112.2
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 153.8 111.2
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 153.8 111.2
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82005-82024(1) 150.4 156.7 104.2
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82005-82024(2) 150.4 156.7 104.2
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 142.4 103.0
Source: JICA Study Team
7-4-4 Summary of Results of Load-flow Analysis for 2020
The results of the static security analysis for 2020 are summarized as follows:
7-4-4-1 Overloaded 330 and 132 kV Transmission Lines
There are no overloads in 330 kV lines under normal operation. However, when tripping the 330 kV lines from Gombe to Yola and Damaturu, the load-flow case did not converge, as expected, due to the absence of
7-44
a second parallel circuit and insufficient support from alternative routes. Converting to a Double-Circuit will resolve these issues.
Under N-1, if any of the following 132 kV lines are tripped, the case will also not converge:
From BKebbi to KVK Power PV From Zaria to Funtua
These 132 kV N-1 cases will have to be resolved by providing new alternative routes for the power flow.
Priority is to resolve the overloads occurring under normal (N-0) operation of the 132 kV lines shown in Table 7-4.20.
Table 7-4.20 Reinforcements of 132 kV lines overloaded under N-0
Bus Name Bus Name Proposed Solution
Ibom IPP Ikot Abasi convert to DC
Source: JICA Study Team
As a next priority, the overloaded 330 and 132 kV lines under N-1 contingencies must be reinforced. This entails either reconductoring to higher rating conductors or, in the case of SC, converting to DC by installing a second parallel circuit.
The lines in Table 7-4.21 are ranked according to their percentage overload. The table lists the worst scenarios in terms of overloads, out of the four study cases (DP, DoP, WP, WoP). The shaded lines are DC lines for which reconductoring is recommended. The 330 kV lines overloaded under N-1 are shown in red fonts.
Table 7-4.21 Reinforcements of 330 and 132 kV lines overloaded under N-1
Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
330 kV
23002 OMOTOSHO3 43002 BENIN 3 cct1 SINGLE 23002-43002(1) 855.1 1,081.6 126.5
23002 OMOTOSHO3 43002 BENIN 3 cct2 SINGLE 23002-43002(2) 855.1 1,081.6 126.5
132 kV
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 189.6 150.9
62000 GOMBE 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 151.3 197.2
82019 OMOKU 1 82036 RUMUSOI 1 1 SINGLE 82019-82036(2) 138.3 220 159.1
82019 OMOKU 1 82036 RUMUSOI 1 2 SINGLE 82019-82036(1) 138.3 213.6 154.5
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 211.5 152.9
62003 YOLA 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 116.3 151.6
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 203.5 147.1
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 202.6 146.5
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 202.6 146.5
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 201.9 146
82017 YENAGOA 1 82022 GBARAIN UBIE 2 SINGLE 82017-82022(1) 138.3 191.5 138.5
82017 YENAGOA 1 82022 GBARAIN UBIE 1 SINGLE 82017-82022(2) 138.3 191.5 138.5
82000 AFAM 1-2-3 82002 AFAM IV 2 SINGLE 82000-82002(1) 138.3 181.4 131.1
82000 AFAM 1-2-3 82002 AFAM IV 1 SINGLE 82000-82002(2) 138.3 181.4 131.1
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 180 130.1
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 180 130.1
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Bus Number
Bus Name Bus
Number Bus Name cct Contingency Label
Rating (MVA)
Flow (MVA)
Loading (%)
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 98.2 128.1
82017 YENAGOA 1 82018 AHOADA 1 2 SINGLE 82017-82018(1) 138.3 174.5 126.2
82017 YENAGOA 1 82018 AHOADA 1 1 SINGLE 82017-82018(2) 138.3 174.5 126.2
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 172.9 125
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 184.5 122.7
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 184.5 122.7
82007 PHCT MAIN1 82036 RUMUSOI 1 2 SINGLE 82007-82036(1) 138.3 169.5 122.5
82007 PHCT MAIN1 82036 RUMUSOI 1 1 SINGLE 82007-82036(2) 138.3 169.5 122.5
82013 ONNE 1 82040 TRAMADI 2 SINGLE 82013-82040(1) 138.3 157.5 113.9
82013 ONNE 1 82040 TRAMADI 1 SINGLE 82013-82040(2) 138.3 157.5 113.9
82007 PHCT MAIN1 82014 RIVERS_IPP 2 SINGLE 82007-82014(1) 138.3 155.2 112.2
82007 PHCT MAIN1 82014 RIVERS_IPP 1 SINGLE 82007-82014(2) 138.3 155.2 112.2
52015 ZARIA 1 52016 FUNTUA 1 1 SINGLE 32016-52004(1) 99.3 110.4 111.2
Source: JICA Study Team Note: It should be noted that with regard to the overloaded 330 kV lines in 2020 (Benin-Omotosho), remedial actions are already
planned and these lines will not be overloaded in 2025, as shown in Section 7.5.
7-4-4-2 Overloaded Transformers
(1) Overloads above 100% of transformer ratings
The 330/132 kV 3-W and A/T transformers overloaded above their 100% rating MVA under normal (base case) operation, listed in Table 7-4.22, must be upgraded:
Table 7-4.22 Upgrading requirements of 330/132 kV 3-winding transformers overloaded under N-0
Bus Number
Bus Name Voltage
(kV) Bus Name
Loading (MVA)
Rating (MVA)
Loading (%)
330/132 kV 3-W transformers
43002 BENIN 3 330 BENIN TR3 156 150 145.6
43011 B.NORTH_3 330 BENIN 9T1 88 67.5 131.6
33002 BKEBBI 3 330 B_KEBBI T1 176.9 150 118
23003 GANMO 3 330 GANMO TR2A 157.4 150 104.9
43002 BENIN 3 330 BENIN TR1 156 150 104
43002 BENIN 3 330 BENIN TR2 156 150 104
Source: JICA Study Team
The 132/33 kV and 132/11 kV transformers overloaded above their 100% rating MVA under normal (base case) operation, listed in Table 7-4.23, must be upgraded:
Table 7-4.23 Upgrading requirements of 132/33 kV and 132/11 kV 2W transformers
overloaded under N-0
Bus Number
Bus Name
Voltage (kV)
Bus Number
Bus Name
Voltage (kV)
Loading (MVA)
Rating (MVA)
Loading (%)
132/33 and 132/11 kV 2-W transformers
32017 SULEJA 1 132 36016 SULEJA 11 11 18.6 7.5 247.6
42004 BENIN 1 132 45029 BENIN T22 33 33 85.9 60 143.1
52001 KANO 1 132 55058 KUMB T3 MOB 33 41.9 30 139.6
42004 BENIN 1 132 45031 BENIN T24 33 33 82.9 60 138.1
42004 BENIN 1 132 45030 BENIN T23 33 33 80.9 60 134.8
52016 FUNTUA 1 132 56000 FUNTUA 11 11 9.6 7.5 127.6
42005 B_N0RTH 1 132 45015 B_NORTH_33 33 73.9 60 123.2
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Bus Number
Bus Name
Voltage (kV)
Bus Number
Bus Name
Voltage (kV)
Loading (MVA)
Rating (MVA)
Loading (%)
22015 OMUARAN 1 132 25016 OMUARAN 33 33 33.4 30 111.4
52016 FUNTUA 1 132 55003 FUNTUA 33 33 33 30 109.9
52016 FUNTUA 1 132 56005 FUNTUA T2 11 7.9 7.5 105.9
22013 OFFA 1 132 25015 OFFA 33 33 31.8 30 105.8
12029 OJO 1 132 15030 OJO 33 33 30.4 30 101.4
Source: JICA Study Team
(2) Overloads above 85% of transformer ratings
Table 7-4.24 shows 330/132 kV, 132/33 kV and 132/11 kV transformers which are overloaded above their 85% rating MVA under normal (base case) operation and shall be considered for upgrading.
Table 7-4.24 Upgrading requirements of 330/132 kV, 132/33 kV and
132/11 kV transformers overloaded over 85% under N-0
Bus Number
Bus Name
Voltage (kV)
Bus Number
Bus Name
Voltage (kV)
cct Load
(MVA) Rating (MVA)
Loading (%)
330/132 kV Transformers 3-W
52001 KANO 1 132 3WNDTR KANO T3A WND 2 1 112.3 120 93.6
42005 B_N0RTH 1 132 3WNDTR BENIN 9T1 WND 1 1 82.8 90 92
132/33 kV and 132/11 kV Transformers
82005 EKET 1 132 85002 EKET T1B 33 1 43.7 45 97.2
12055 ODOGUNYAN 1 132 15063 ODOGUNYA 33 33 1 57.9 60 96.5
12055 ODOGUNYAN 1 132 15063 ODOGUNYA 33 33 2 57.9 60 96.5
22022 GANM0 T1 BB 132 25032 GANMO T1 33 1 57.1 60 95.2
12023 EJIGBO 1 132 15128 EJIGBO 33 33 1 28.4 30 94.5
12023 EJIGBO 1 132 15128 EJIGBO 33 33 2 28.4 30 94.5
12029 OJO 1 132 15047 OJO T3_T4 33 5 55.8 60 92.9
12019 ALIMOSHO 1 132 15072 ALIMOSHO T1 33 3 27.5 30 91.8
42002 UGHELLI 1 132 45001 UGHELLI 33 33 1 53.6 60 89.3
12037 PARAS_1 132 15116 AFR FOUNDRY 33 1 35.6 40 89
22027 SHAGAMU 1 132 25035 SHAGAMU 33 33 1 26.5 30 88.3
82000 AFAM 1-2-3 132 86000 AFAM 11 11 1 55.1 64 86.1
22008 IWO 1 132 25002 IWO 33 33 1 12.9 15 85.9
22008 IWO 1 132 25002 IWO 33 33 2 34.3 40 85.9
82005 EKET 1 132 85002 EKET T1B 33 1 43.7 45 97.2
Source: JICA Study Team
7-4-4-3 Undervoltages Under N-1 Conditions
In all N-1 contingencies, a number of 132 kV voltages are lower than the minimum permissible level of 0.8p.u. However, this is due to overloads of the associated 132 kV lines and transformers and the remedial actions for the undervoltages (U/V) is linked with the solutions required first for overloads of these circuits, as well as with the implementation of reactive power compensation equipment.
The reactive power requirements, i.e. the need to have existing reactors and capacitors in operation and/or install new ones by 2020, including the need for new SVCs, are summarized in the following sections:
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(1) SVC requirements
No SVC at Gombe is necessary by 2020.
(2) Reactors
The status of reactors required in the Dry Season Peak case is shown in Table 7-4.25. It can be seen that only reactors at Gombe, Yola and Maiduguri are required. The new equipment required is shown in bold:
Table 7-4.25 Reactor requirements for 2020 Dry Season Peak
Bus Number
Bus Name Voltage
(kV) Id In Service
B-Shunt (MVar)
63005 MAIDUGURI 3 330.00 330 2 1 -75.00
63002 YOLA 3 330.00 330 1 1 -75.00
63002 YOLA 3 330.00 330 2 1 -75.00
63000 GOMBE 3 330.00 330 1 1 -50.00
63000 GOMBE 3 330.00 330 2 1 -50.00
65001 YOLA T1 33 33.000 33 1 1 -30.00
65014 GOMBE T4A 33.000 33 1 1 -30.00
Source: JICA Study Team
The status of reactors required in Dry Season Off-Peak and in Wet Season Off-Peak cases is shown in Table 7-4.26. The new equipment required is shown in bold:
Table 7-4.26 Reactor requirements for 2020 dry and wet season off-peak
Bus Number
Bus Name Voltage
(kV) Id
In Service
B-Shunt (MVar)
53001 KANO 3 330 1 1 -75
63001 JOS 3 330 1 1 -75
63002 YOLA 3 330 1 1 -75
63002 YOLA 3 330 2 1 -75
63005 MAIDUGURI 3 330 2 1 -75
63000 GOMBE 3 330 1 1 -50
63000 GOMBE 3 330 2 1 -50
65001 YOLA T1 33 33 1 1 -30
65014 GOMBE T4A 33 1 1 -30
Source: JICA Study Team
(3) Capacitors
The status of capacitors required in the Dry Season Peak case is shown in Table 7-4.27. The new equipment required is shown in bold:
Table 7-4.27 Capacitor requirements for 2020 Dry Season Peak
Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
62021 MAIDUGURI 1 132 1 1 10.8
52022 HADEJIA 1 132 1 1 20
22017 ONDO2 1 132 1 1 24
42008 IRRUA 1 132 1 1 24
52011 GUSAU 1 132 1 1 50
12004 AKANGBA BBII 132 1 1 72
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Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
15002 AGBARA 33 33 1 1 20
15022 IKORODU 33 33 2 1 20
15027 ILUPEJU 33 33 1 1 20
25018 AKURE T3A 33 33 1 1 20
45003 OKENE 33 33 1 1 20
55001 DAN AGUNDI 3 33 2 1 20
55010 KATSINA 33 33 1 1 20
15037 NEW ABEOK 33 33 1 1 20
25004 AYEDE 33 33 1 1 20
25012 ISEYIN 33 33 1 1 20
25035 SHAGAMU 33 33 1 1 20
25038 IJEBU-ODE 33 33 1 1 20
15006 AKANGBA 33 33 1 1 24
15007 AKOKA T1 33 33 1 1 24
15009 ALAUSA 33 33 1 1 24
15010 ALIMOSHO 33 33 1 1 24
15014 EJIGBO 33 33 1 1 24
15015 IJORA 33 33 1 1 24
15018 OGBA 33 33 1 1 24
15028 ISOLO 33 33 1 1 24
15128 EJIGBO 33 33 1 1 24
15079 OTTA T2 33 1 1 24
15080 OLD ABEOK T2 33 3 1 24
25011 ILORIN 33 33 1 1 24
Source: JICA Study Team
The status of capacitors required in Dry Season Off-Peak case is shown in Table 7-4.28.
Table 7-4.28 Capacitor requirements for 2020 Dry Season Off-Peak
Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
62021 MAIDUGURI 1 132 1 1 10.8
52022 HADEJIA 1 132 1 1 20
22017 ONDO2 1 132 1 1 24
42008 IRRUA 1 132 1 1 24
52011 GUSAU 1 132 1 1 50
12004 AKANGBA BBII 132 1 1 72
15002 AGBARA 33 33 1 1 20
15022 IKORODU 33 33 2 1 20
15027 ILUPEJU 33 33 1 1 20
15037 NEW ABEOK 33 33 1 1 20
25004 AYEDE 33 33 1 1 20
25012 ISEYIN 33 33 1 1 20
25018 AKURE T3A 33 33 1 1 20
25035 SHAGAMU 33 33 1 1 20
25038 IJEBU-ODE 33 33 1 1 20
45003 OKENE 33 33 1 1 20
55001 DAN AGUNDI 3 33 2 1 20
55010 KATSINA 33 33 1 1 20
15006 AKANGBA 33 33 1 1 24
7-49
Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
15007 AKOKA T1 33 33 1 1 24
15009 ALAUSA 33 33 1 1 24
15010 ALIMOSHO 33 33 1 1 24
15014 EJIGBO 33 33 1 1 24
15015 IJORA 33 33 1 1 24
15018 OGBA 33 33 1 1 24
15028 ISOLO 33 33 1 1 24
15079 OTTA T2 33 1 1 24
15080 OLD ABEOK T2 33 3 1 24
15128 EJIGBO 33 33 1 1 24
25011 ILORIN 33 33 1 1 24
Source: JICA Study Team
7-4-4-4 Power Factor Correction at DisCo’s Level
With reference to the Grid Code requirements (ref. article 15.6 on Demand power factor corrections and 16.7 on the provision of voltage control stating that The Off-takers shall maintain a power factor not less than 0.95 at the Connection Point), since the resulting power factor of loads connected at 33 kV level and below is less than the 0.95 required, all DisCos shall be required to undertake a program of having capacitors installed at distribution level to ensure the power factor at all 33 kV S/S is not less than 0.9 by 2020 and 0.95 by 2025, in line with the Grid Code requirements. (Note: the loads in the 2025 model however have been based on a conservative power factor of 0.92 and only the 2030 loads have a pf of 0.95)
7-4-5 Expansion Plan for 2020
7-4-5-1 Transmission Lines
As shown in the SLDs of Annexes 7.4.1 and 7.4.2, the transmission lines shown in Table 7-4.29 must be implemented by 2020 or as soon as possible thereafter. Line Nos. 1 to 5 in Table 7-4.29 require reconductoring only. A priority ranking from 1 to 3 has been included in this table, with 1 denoting the highest priority.
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Table 7-4.29 New transmission lines required by 2020
No From To
kV km Remarks Priority/Ranking
1
Part of
North-East
Ring
Damaturu Maiduguri DC 330 260 An SC already exists. 1
2 Gombe Damaturu DC 330 180 An SC already exists. 1
3 Gombe Yola DC 330 240 An SC already exists. 1
4 Yola Jalingo DC 330 160 Can be delayed beyond 2020 but ASAP
thereafter. One circuit via Mayo Belwa. 3
5 Jos Gombe DC 330 270
Via Bauchi.
Should be completed by 2020 or ASAP
thereafter.
A SC already exists.
1
6
Part of
North-West
ring
Kainji Birnin-Kebbi DC 330 310
An SC already exists. Needs to be
expedited by 2020 if possible or ASAP
thereafter.
3
7 Kaduna Kano DC 330 230
Undertaken by TCN as part of the NTEP
to be financed by IDB. Needs to be
expedited by 2020 if possible or ASAP
thereafter.
2
8 Akangba Ijora DC 330 14 A 330kV substation at Ijora and
associated 330kV lines are necessary
after 2020, but since they remove in
2020 the overloads at 132kV
Ijora-Alagbon line and improve voltage
profile in the area, it is recommended to
implement as soon as possible after
2020.
2
9 Ijora Alagbon DC 330 8 2
10 Arigbajo New Agbara DC 330 40
If not undertaken by JICA.
Not considered necessary for 2020, as it
is lightly loaded. However, it is necessary
for meeting the N-1 criterion for the
export lines to Sakete.
2
11 Ugwaji Abakaliki DC 330 85 1
12 Osogbo Arigbajo DC 330 183 If not undertaken by JICA. 1
13 Ayede Ibadan North DC 132 15 An SC exists. A second circuit in parallel is
needed. 1
14 New Agbara Agbara DC 132 18 2
15 Ogijo Redeem DC 132 14 If not undertaken by JICA. 2
16 Birmin Kebbi Dosso DC 132 128 An SC already exists. 2
Source: JICA Study Team Notes: The lines recommended for the North-East ring above must comply with the N-1 static security criterion, as well as
improving the voltage stability of the area. It is recognized however that in implementation terms it will be challenging to complete it all by 2020. However, if it is not possible to implement by 2020, they should be implemented as soon as possible thereafter within the period 2020-2025, based on which the investment plan detailed in Section 9 has been drawn up.
The JICA project of new 330 kV lines (DC) from Ogijo to Arigbajo is not considered necessary in 2020, as it is lightly loaded under all scenarios (it will be required, though, in 2025).
The JICA project of new 330 kV lines (DC) from Arigbajo to New Agbara is not considered necessary for 2020, as it is lightly loaded. It is necessary only for meeting the N-1 criterion for the export lines to Sakete.
As shown in Section 8, the first priority is to resolve the overloads occurring under normal (N-0) operation of the following 132 kV lines shown in Table 7-4.30:
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Table 7-4.30 Reinforcements of 132 kV lines overloaded under N-0
From To Proposed solution
Ibom IPP Ikot Abasi Convert to DC
Source: JICA Study Team
As a next priority, the overloaded 330 and 132 kV lines under N-1 contingencies must be reinforced. This entails either reconductoring to higher rating conductors or, in case of SC, conversion to DC by installing a second parallel circuit.
The lines in Table 7-4.31 are ranked according to their percentage overload. The shaded lines are DC lines for which reconductoring is recommended.
Table 7-4.31 Reinforcements of 132 kV lines overloaded under N-1
FROM Bus No.
Bus name TO Bus No.
Bus name cct Contingency label Rating (MVA)
Flow (MVA)
Loading (%)
330 kV
23002 OMOTOSHO3 43002 BENIN 3 cct1 SINGLE 23002-43002(1) 855.1 1081.6 126.5
23002 OMOTOSHO3 43002 BENIN 3 cct2 SINGLE 23002-43002(2) 855.1 1081.6 126.5
132 kV
82024 IBOM IPP 1 82031 IKOT_ABASI 1 BASE CASE 125.7 189.6 150.9
62000 GOMBE 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 151.3 197.2
82019 OMOKU 1 82036 RUMUSOI 1 1 SINGLE 82019-82036(2) 138.3 220 159.1
82019 OMOKU 1 82036 RUMUSOI 1 2 SINGLE 82019-82036(1) 138.3 213.6 154.5
42000 AJAOKUTA 1 42009 OKENE 1 1 SINGLE 42004-42008(1) 138.3 211.5 152.9
62003 YOLA 1 62013 T_JUNCTION 1 1 SINGLE 63000-63002(1) 76.7 116.3 151.6
42004 BENIN 1 42008 IRRUA 1 1 SINGLE 42000-42009(1) 138.3 203.5 147.1
52033 MANDO T4A BB 52035 KUDENDA 1 2 SINGLE 52033-52035(1) 138.3 202.6 146.5
52033 MANDO T4A BB 52035 KUDENDA 1 1 SINGLE 52033-52035(2) 138.3 202.6 146.5
22002 OSOGBO 4T2 22008 IWO 1 1 SINGLE 22000-22006(1) 138.3 201.9 146
82017 YENAGOA 1 82022 GBARAIN UBIE 2 SINGLE 82017-82022(1) 138.3 191.5 138.5
82017 YENAGOA 1 82022 GBARAIN UBIE 1 SINGLE 82017-82022(2) 138.3 191.5 138.5
82000 AFAM 1-2-3 82002 AFAM IV 2 SINGLE 82000-82002(1) 138.3 181.4 131.1
82000 AFAM 1-2-3 82002 AFAM IV 1 SINGLE 82000-82002(2) 138.3 181.4 131.1
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 2 SINGLE 12003-12019(1) 138.3 180 130.1
12003 IKEJA W 1BB1 12019 ALIMOSHO 1 1 SINGLE 12003-12019(2) 138.3 180 130.1
62009 BIU 1 62026 DADINKOWA 1 1 SINGLE 63005-63007(1) 76.7 98.2 128.1
82017 YENAGOA 1 82018 AHOADA 1 2 SINGLE 82017-82018(1) 138.3 174.5 126.2
82017 YENAGOA 1 82018 AHOADA 1 1 SINGLE 82017-82018(2) 138.3 174.5 126.2
22000 AYEDE 1 22006 IBADAN NORTH 1 SINGLE 22002-22008(1) 138.3 172.9 125
82005 EKET 1 82024 IBOM IPP 1 1 SINGLE 82024-82031(1) 150.4 184.5 122.7
82005 EKET 1 82024 IBOM IPP 1 2 SINGLE 82024-82031(1) 150.4 184.5 122.7
82007 PHCT MAIN1 82036 RUMUSOI 1 2 SINGLE 82007-82036(1) 138.3 169.5 122.5
82007 PHCT MAIN1 82036 RUMUSOI 1 1 SINGLE 82007-82036(2) 138.3 169.5 122.5
82013 ONNE 1 82040 TRAMADI 2 SINGLE 82013-82040(1) 138.3 157.5 113.9
82013 ONNE 1 82040 TRAMADI 1 SINGLE 82013-82040(2) 138.3 157.5 113.9
82007 PHCT MAIN1 82014 RIVERS_IPP 2 SINGLE 82007-82014(1) 138.3 155.2 112.2
82007 PHCT MAIN1 82014 RIVERS_IPP 1 SINGLE 82007-82014(2) 138.3 155.2 112.2
52015 ZARIA 1 52016 FUNTUA 1 1 SINGLE 32016-52004(1) 99.3 110.4 111.2
Source: JICA Study Team Note: It should be noted that with regard to the overloaded 330 kV lines in 2020 (Benin-Omotosho), remedial actions are already
planned and these lines will not be overloaded in 2025.
7-4-5-2 Transformers
7-52
The upgrading of 6 x 330/132 kV 3-W and A/T transformers which are overloaded above their 100% rating MVA under normal (base case) operation, is required, as listed in Table 7-4.22.
The upgrading of 12 x 132/33 kV and 132/11 kV transformers which are overloaded above their 100% rating MVA under normal (base case) operation, is required, as listed in Table 7-4.23.
The upgrading of the following types of transformers overloaded above their 85% rating MVA under normal (base case) operation shall be upgraded, as listed in Table 7-4.24: a) 2 x 330/132 kV 3-w and A/T, b) 15 x 132/33 kV and 132/11 kV transformers
7-4-5-3 Reactive Power Compensation
(1) SVC requirements
No SVC at Gombe is necessary by 2020.
(2) Reactors
The new reactors required in the Dry Season Peak and Dry Season Off-Peak cases are shown in Table 7-4.32. Only reactors at Gombe, Yola and Maiduguri must be in operation. The new reactor at Maiduguri is shown in bold:
Table 7-4.32 Reactor requirements for 2020
Bus Number
Bus Name Voltage
(kV) Id
In Service
B-Shunt (MVar)
63005 MAIDUGURI 3 330.00 330 2 1 -75.00
Source: JICA Study Team
(3) Capacitors
The new capacitors required in the Dry Season Peak, Dry Season Off-Peak and Wet Season Off-Peak cases are shown in Table 7-4.33:
Table 7-4.33 Capacitor requirements for 2020
Bus Number
Bus Name Voltage
(kV) Id
In Service
B-Shunt (MVar)
22017 ONDO2 1 132 1 1 24
42008 IRRUA 1 132 1 1 24
52011 GUSAU 1 132 1 1 50
Source: JICA Study Team
7-4-6 Fault Analysis
Short-circuit calculations were carried out for three-phase faults under all load scenarios. As a result of the calculations, design parameters for new substations and lines, short-circuit levels on existing substations and the impact of the expansion measures are shown. It is important to calculate the short-circuit currents since they are a measure to indicate the strength of both systems which will be interconnected.
The short-circuit calculations were performed according to the IEC 60909 standard and the following
7-53
values were determined at all 330 and 132 kV substations in the TCN network:
3-phase symmetrical short-circuit power Sk3 (MVA) Ik3” total symmetrical short-circuit current for three-phase solid faults
The calculations are based on the operational condition available in the corresponding load-flow scenarios.
The results of the preliminary fault analysis are summarized in Annex 7.4.10 (Table 1) for all 330 and 132 kV substations. The generators sub-transient reactance are used.
The most critical 330 and 132 kV substations are shown in Table 7-4.34.
Table 7-4.34 Fault analysis results 2020
Bus Number
Bus Name Voltage
(kV) I
(A) Bus
Number Bus Name
Voltage (kV)
I (A)
43002 BENIN 3 330 30,340 82000 AFAM 1-2-3 132 29,882
83000 AFAM IV 3 330 29,491 82002 AFAM IV 132 29,767
83002 ALAOJI 3 330 28,225 12003 IKEJA W 1BB1 132 28,156
83001 ALAOJI NIPP3 330 27,810 82019 OMOKU 1 132 26,663
43011 B_NORTH_3 330 27,132 12042 OKE_ARO_1 132 25,624
Source: JICA Study Team
The most critical 330 kV substations are BENIN, AFAM IV, ALAOJI and BENIN NORTH, with fault levels ranging from 30.3 kA to 27.1 kA for a 3ph busbar fault.
The most relatively critical 132 kV substation is AFAM and IKEJA WEST, with fault levels of 29.8 and 28.1 kA. It is clear from this analysis that the TCN standard switchgear ratings of 31.5 kA will be inadequate in future when new power plants are commissioned in later years.
a) Install switchgear with higher capacity breakers (63 kA).
b) Study different topological configurations of the elements connected to the different bus sections.
c) Install Current Limiting Reactors (CLR) aiming to reduce the short-circuit current contributions from adjacent bus sections.
7-54
7-5 Expansion Plan for 2025
7-5-1 Static Security Analysis, Year 2025
7-5-1-1 Transmission lines
The network configuration for 2025 is shown in the PSS/E SLD of Annex 7.5.1
7-5-1-2 Evacuation from Mambilla HPP
(1) New transmission lines
A major development for 2025 is the operation of the first units of the Mambilla HPP. The new transmission lines required to evacuate the power from Mambilla will have to be designed to evacuate full power, assuming power of 2,400 MW is to be evacuated from the Mambilla Hydro Power Plant:
1. If the N-1 criterion is to be maintained, as per the current Grid Code, the following is proposed:
a) 330/132/33 kV substation at Wukari
b) Double-Circuit with Quad Bison conductors from Mambilla to Wukari
c) Double-Circuit with Quad Bison conductors from Wukari to Makurdi
d) Double-Circuit with Quad Bison conductors from Mambilla to Jailingo (to close the 330-kV loop)
2. Due to the importance of the power station and in line with international practice by other utilities, it is proposed to apply the N-2 criteria only for the transmission lines leaving the power plant. If this is adopted, it would be necessary to have:
a) Two Double Circuits with Quad Bison conductors from Mambila to Wukari
b) Two Double Circuits with Quad Bison conductors from Mambila to Jailingo
Each Quad Bison circuit will be rated 1,550MVA approx. The scheme is shown on the Single-Line Diagram of Figure 7-5.1.
In both cases, two evacuation routes must be maintained (one towards Makurdi and another towards Jalingo) at all times, since 2,400MW will not be able to be evacuated through one route only, given that bottlenecks will occur downstream, beyond Makurdi and Jalingo respectively.
7-55
Source: JICA Study Team
Figure 7-5.1 Evacuation from Mambilla HPP
(2) PV analysis
A PV analysis was carried out to determine the maximum power that can be evacuated from Mambilla HPP (MHPP).
The starting scenario was set up with an initial generation of 1,000 MW at MHPP and both base case and contingency (N-1) conditions were analyzed. It was determined that:
Under base case (normal) conditions, an additional 2,000 MW can be evacuated, i.e. a total of 3,000 MW, before a 330-kV line in the TCN system reaches its limit.
Under contingency conditions, an additional 1,700 MW can be evacuated, i.e. total 2,700 MW, before a line in the TCN system reaches its thermal limit (777 MVA), in this case the Gombe-Yola 330 kV line (cct1) when the other Gombe-Yola line (cct 2) is tripped. This is shown in the graphs of Figure 7-5.2.
QUAD QUAD
QUAD
1
63006JALINGO_3
1
63002YOLA 3
483
67
504
194
1
2
63000GOMBE 3
340
66
357
19
340
66
357
19
1
2
SW
0
138
112
134
74
1
33023LAFIA 3
395
25
381
79
395
25
381
79
619
52
636
60
619
52
636
60
175
8
24
175
8
177
24
571
230
295
571
230
578
295
63009WUKARI 3
531
63
521
14
179
609
71
531
63
521
14
609
71
622
179 141
97
141
97
73003MAKURDI_3
73004ALIADE_3
177
33022APO_NEW 3
63001JOS 3
166
102
96
84
63003BAUCHI 3
622
493
62
101
505
199
491
108
63008MAMBILA 3
63015MAYOBELWA
578
499
240
95
240
95
240
95
240
95
240
95
240
95
240
95
240
95
240
95
240
95
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
1240
114R
7-56
Source: JICA Study Team
Figure 7-5.2 PV Analysis for Mambilla Evacuation
Considering that the Mambilla plant is rated 3,000 MW and is highly unlikely to reach production exceeding 2,400 MW, it is concluded that all power can be evacuated without any additional reinforcements in the transmission system required.
(3) Specifications of transmission lines
The following data is used: the 330-kV conductor is 4-bundle ACSR350 per phase, spaced at 400 mm. The conductor types (aluminum conductor steel reinforced):
7-57
ACSR 350 ‘Bison’ (381-AL1/49-ST1A; 54 Al wires diameter 3.0 mm; seven Fe wires diameter 3.0 mm, i.e. 54/7), Outside diameter 27 mm. The Basic Conductor Characteristics are in Table 7-5.1
Table 7-5.1 Basic Conductor Characteristics for 330 kV OHL
Description Value
Cross-section
Aluminum (mm2) 381.6
Steel (mm2) 49.4
Total (mm2) 431
Stranding and wire diameter
Aluminum (mm) 54 / 3.0
Steel (mm) 7 / 3.0
Overall diameter (mm) 27
(4) 330 kV Transmission Line R, X and B
The tower design is shown in Figure 7-5.3 and the conductors’ arrangements in Figure 7-5.4.
Source: JICA Study Team Figure 7-5.3 Tower Design
7-58
Based on the above, with d=400mm (1.32 ft):
d=400mm=1.32ft
D12= 10.5m= 34.44ft D23=10.5m=34.44ft
D13=21m=68.88ft
Source: JICA Study Team
Figure 7-5.4 Conductors Spacing 330 kV Line
In general:
2-strand bundle 3-strand bundle 4-strand bundle
d d d
The Geometric Mean Radius (GMR) of bundled conductors:
𝐷𝑠𝑏 = √𝐷𝑠. 𝑑 𝐷𝑠
𝑏 = √𝐷𝑠. 𝑑23 𝐷𝑠𝑏 = 1.09 √𝐷𝑠. 𝑑34
where Ds is the GMR of one stranded conductor.
For Bison conductors, the GMR (=Ds) of one conductor, as taken from tables, is:
GMR=Ds=0.0363 ft
For bundled conductors the equivalent GMR is
𝐷𝑠𝑏 = √𝐷𝑠. 𝑑 for 2-bundle conductors (1)
𝐷𝑠
𝑏 = √𝐷𝑠. 𝑑23 for 3-bundle conductors (2) 𝐷𝑠
𝑏 = 1.09 √𝐷𝑠. 𝑑34 for 4-bundle conductors (3)
In this case, for 4-b (Quad):
GMR(=Ds) of one conductor from tables
7-59
𝐷𝑠𝑏 = 1.09√𝐷𝑠. 𝑑34
= 1.09√0.0363 × 1.3234 = 0.586 𝑓𝑡
The equivalent spacing between phases is:
𝐷𝑒𝑞 = 𝐷𝑚 = √𝐷12. 𝐷23. 𝐷313 = √34.44 × 34.44 × 68.88
3= 43.4 𝑓𝑡
Inductive Reactance:
𝑋𝐿 = 4.657 . 10−3 . 𝑓. logDm
Dsb = 0.4353 ohms/mile = 0.27 ohms/km (for SC)
= 0.25 ohms/km (for DC)
Capacitance:
𝐶𝑛 =0.0388
log𝐷𝑒𝑞
𝐷𝑠 𝑐𝑏
μF/mile
where 𝐷𝑠 𝑐𝑏 is the equivalent GMR for capacitance calculations and derived from eqs. (1), (2) and (3)
used for inductance calculations, except that the Ds is replaced by the radius r of the conductor in ft, i.e.
𝑟 =𝐷𝑜𝑢𝑡
2 ×12 ft, where Dout is the conductor outside diameter in inches
Accordingly, for capacitance:
𝐷𝑠 𝑐𝑏 = √𝑟. 𝑑 for 2-bundle conductors (4)
𝐷𝑠 𝑐
𝑏 = √𝑟. 𝑑23 for 3-bundle conductors (5) 𝐷𝑠 𝑐
𝑏 = 1.09 √𝑟. 𝑑34 for 4-bundle conductors (6)
For Bison conductors: 𝑟 =𝐷𝑜𝑢𝑡
2 ×12=
1.062
2 ×12= 0.04425 ft
𝐷𝑠 𝑐𝑏 = 1.09√𝑟. 𝑑34
= 1.09√0.04425 ×. 1.3234= 0.6156 𝑓𝑡
𝐶𝑛 =0.0388
log𝐷𝑒𝑞
𝐷𝑠 𝑐𝑏
= 0.0388
log43.4
0.6156
= 0.021 𝜇𝐹/𝑚𝑖𝑙𝑒 = 0.013 𝜇𝐹/𝑘𝑚 (for SC)
= 0.014 𝜇𝐹/𝑘𝑚 (for DC)
Susceptance B=ωC=314 x 0.013 = 4.08 μmho/km = 4.08 μS/km), for SC = 4.39 μS/km), for DC
Resistance: R=0.0762 ohms/km (R=0.019 ohms/km for four bundle conductors)
The electrical parameters in PSS/E of the DC 330 kV line Mambila-Wukari and Mambilla-Jalingo are summarized in Table 7-5.2.
7-60
Table 7-5.2 Double-Circuit 330 kV line characteristics
PSS/E input data
Substation
Name
Substation
Name
L
(km)
R
(Ω/km)
L
(mH/km) X (Ω/km) C (μF/km)
R
(ohms)
X
(ohms)
C
(μF)
Mabila Wukari 159 0.019 0.7962 0.25 0.014 3.021 39.750 2.2260
Mabila Jalinko 95 0.019 0.7962 0.25 0.014 1.805 23.750 1.3300
Source: JICA Study Team
(5) Line surge impedance and thermal rating
1) Surge Impedance Loading Limits - Natural Line Rating
As power flows along a transmission line, there is an electrical phase shift, which increases with distance and power flow. As this phase shift increases, the system in which the line is embedded can become increasingly unstable during electrical disturbances.
Typically, for very long lines, the power flow must be limited to what is commonly called the Surge Impedance Loading (SIL) of the line.
Surge Impedance Loading is equal to the product of the end bus voltages divided by the surge (characteristic) impedance of the line. Since the characteristic impedance of various HV and EHV lines is relatively similar, the SIL depends approximately on the square of the system voltage:
𝑆𝐼𝐿 =𝑘𝑉2
𝑍𝑠
where Zs is the surge impedance of the line: 𝑍𝑠 = √𝐿
𝐶 =√
0.7962𝑥1000
0.014 = 238.5 ohms
𝑺𝑰𝑳 = 𝟑𝟑𝟎𝟐
𝟐𝟑𝟖. 𝟓= 𝟒𝟓𝟔 𝐌𝐖
Typically, stability limits may determine the maximum allowable power flow on lines that are more than approx. up to 250 km in length.
2) Thermal Limits
Thermal power flow limits on overhead lines are intended to limit the temperature attained by the energized conductors and the resulting sag and loss of tensile strength. In most cases, the maximum conductor temperature applied to modern transmission lines reflect ground clearance concerns rather than annealing of aluminum.
Thermal limits are not a function of line length. Thus for a given line design, lines of 1 km and 500 km long typically have the same thermal limit.
The thermal transmission capacities of the 330 kV OHL have been calculated as follows:
Voltage 330 kV
7-61
Conductor Type 3 x AC 381/49 Wind Speed 0.6 m/s Air temperature 40 °C Maximum conductor temperature 75 °C
Thermal Ratings: Capacity 1,555 MVA Capacity 1,400 MW
7-5-1-3 2025 Load demand
Table 7-5.3 shows that the increase in load demand follows an approximately equivalent increase (in percentage terms) in the load forecast.
Table 7-5.3 Load demand per DisCo
DisCo Load demand 2020
(MVA) Increase 2020-2025
Load demand 2025
(MVA)
1-Ikeja 1,166 76% 2,058
2-Ibadan 1,104 107% 2,285
3-Abuja 865 169% 2,329
4-Benin 954 94% 1,852
5-Kaduna 495 136% 1,169
6-Jos 309 109% 646
7-Enugu 924 81% 1,668
8-Port Harcourt 794 122% 1,762
9-ΕΚΟ 1,087 69% 1,837
10-Kano 708 121% 1,565
11-Yola 230 131% 532
Country MW 8,636 105% 17,703
Export* MW 387 - 1,540
Tota Load MW 9,023 113% 19,243
Source: JICA Study Team Ref: 330 kV export lines: To Sakete 360MW, To Faraku 400MW, To Zabori 631MW
7-5-1-4 Study cases 2025
Table 7-5.4 shows the two scenarios studied for 2025, to capture the extreme combinations of generation and load.
Table 7-5.4 2025 study cases
Case Description Generation Load (MW)
Dry Season
Peak
DP
Dry
Night
Peak Load
Reduced HPP generation (2228 MW)
No PV generation
Increased requirement from GTs
Peak load
(night)
17703 + export
(1540)
Dry Season
Off-Peak
DOP
Dry
Day
Off-Peak Load
Reduced HPP generation
PV generation
Increased requirement from GTs
Off-Peak load
(day)
15000 + export
(1540)
Source: JICA Study Team
7-62
7-5-2 2025 Base Case Load-flow Results
7-5-2-1 Dry Season Peak-2025
(1) Prerequisites for analysis
(a) Generation from PVs = 0 and (b) Reduced generation from HPP plants of 2,228 MW,
The running generation and load for each DisCo is as shown in Figure 7-5.5.
Source: JICA Study Team
Figure 7-5.5 Dry Season Peak Generation and Load per DisCo
Ikeja Ibadan Abuja Benin Kaduna Jos Enugu P Harc Eko Kano YolaTotalfor
NigeriaExport Totals
Run Genaration 2699 1168 3426 4430 218 84 1301 5415 900 9 500 20150
Load 2058 2268 2330 1827 1165 648 1666 1753 1837 1555 532 17639 1540 19179
Gen deficit/surplus 641 -1100 1096 2603 -947 -564 -365 3662 -937 -1546 -32 971
-2500
-1500
-500
500
1500
2500
3500
4500
5500
MW
Dry Season Peak
7-63
Table 7-5.5 Dry Season Peak Generation and Load per DisCo
Bus Number
Bus Name PGen
(MW) Bus
Number Bus Name
PGen (MW)
Bus Number
Bus Name PGen
(MW)
16040 AES BERG202 31 16004 EGBIN ST 5 274.8 76022 OKPAI STPH2 135
16041 AES BERG203 31 16005 EGBIN ST 6 274.8 16064 OLOR NIPPST1 108
16042 AES BERG204 31 16006 EGBIN ST_123 600 16065 OLOR NIPPST2 108
16043 AES BERG205 31 86050 ELEME 68 16060 OLORNIPPGT11 132
16045 AES BERG207 31 96012 ETHIOPE 450 16061 OLORNIPPGT12 100
16046 AES BERG208 31 46037 ETHIOPE GTS 344 16062 OLORNIPPGT21 100
16047 AES BERG209 31 46038 ETHIOPE ST 156 16063 OLORNIPPGT22 100
16048 AES BERG210 31 86068 GBARAIN_GTB1 112.5 16050 OLORUNSO GT1 30
16049 AES BERG211 31 86069 GBARAIN_GTB2 112.5 16051 OLORUNSO GT2 30
86012 AFAM VI GT11 150 86055 GEN_AMADI 100 16054 OLORUNSO GT5 30
86013 AFAM VI GT12 150 56010 GEN_KADUNA 200 16055 OLORUNSO GT6 30
86014 AFAM VI GT13 150 46023 GER NIPPGT21 140 16056 OLORUNSO GT7 30
86015 AFAM VI ST10 180 46024 GER NIPPGT22 140 86047 OMA_GT 225
86003 AFAM2 GT5-6 48 46025 GER NIPPGT23 140 86023 OMOKU1 GT1 75
86004 AFAM2GT 7-8 48 46020 GEREGU GT11 124 86024 OMOKU1 GT2 75
86005 AFAM3 GT9-10 50 56003 GURARA GBUS 18 86021 OMOKU2 GT1 113
86006 AFAM3GT11-12 50 86025 IBOM GT1 32 86022 OMOKU2 GT2 113
86080 AKWA-IBOM NU 600 86026 IBOM GT2 32 26026 OMOTNIPP GT1 110
86039 ALAOJI_GTB1 112.5 86027 IBOM GT3 32 26027 OMOTNIPP GT2 110
86040 ALAOJI_GTB2 112.5 86028 IBOM II 260 26028 OMOTNIPP GT3 110
86041 ALAOJI_GTB3 112.5 46031 IHOVBOR_GTB1 110 26029 OMOTNIPP GT4 110
86042 ALAOJI_GTB4 112.5 46032 IHOVBOR_GTB2 110 26020 OMOTOSO GT1 70
86043 ALAOJI2_STB1 257 46033 IHOVBOR_GTB3 110 26022 OMOTOSO GT3 70
86031 ALSCON GT1 90 46034 IHOVBOR_GTB4 110 26024 OMOTOSO GT5 62
46027 ASCO G1 55 66033 JBS WIND 70 26025 OMOTOSO GT7 62
46028 ASCO G2 55 36006 JEBBA 2G1 90 96008 ONDO IPP 405
46035 AZURA GT 280 36007 JEBBA 2G2 90 16012 PARAS 270
46036 AZURA ST 140 36008 JEBBA 2G3 90 16011 PARASGT1-9 93
16008 BRESSON GTS 80 36009 JEBBA 2G4 40 46070 PROTON 135
96009 CABLE INLAND 900 36011 JEBBA 2G6 90 86070 QUA IBOE PP 480
86062 CALABAR_GTB1 100 36004 KAINJ 1G11 80 86035 RIVERS _GT1 190
86061 CALABAR_GTB2 100 36005 KAINJ 1G12 80 46050 SAP_NIPP_GT1 100
86060 CALABAR_GTB3 100 36000 KAINJ 1G5 80 46051 SAP_NIPP_GT2 100
86063 CALABAR_GTB4 100 36001 KAINJ 1G6 80 46052 SAP_NIPP_GT3 100
76011 CENTURY IPP 480 36002 KAINJ 1G7-8 160 46012 SAPELE GT1-2 175
86030 CUMMINS 135 36003 KAINJ 1G9-10 160 46013 SAPELE GT3-4 95
46010 DELTAIV GT19 133 46080 KOJI NUCLEAR 600 36012 SHIROR 411G1 140
46011 DELTAIV GT20 133 55075 KT WF 33 9 36013 SHIROR 411G2 140
66005 DKOWA G1 14 16010 LAFARAGE 2 100 36014 SHIROR 411G3 80
86065 EGBEMA_GTB1 100 66007 MAMBILA GT1 250 96016 TURBINE DR 300
86066 EGBEMA_GTB2 100 66008 MAMBILA GT2 250 96017 YELLOW STONE 162
86067 EGBEMA_GTB3 100 76000 OKPAI GT11 145 46029 ZUMA 540
16000 EGBIN GT 1 274.8 76001 OKPAI GT12 145 86071 ZUMA (GAS) 337
16001 EGBIN GT 2 274.8 76020 OKPAI GT4PH2 135 36024 ZUNGE_G1 150
16002 EGBIN GT 3 274.8 76021 OKPAI GT5PH2 135 36025 ZUNGE_G2 150
16003 EGBIN GT 4 274.8 76002 OKPAI ST18 126 36027 ZUNGE_G4 10
Source: JICA Study Team
7-64
The power flows are shown in Figure 7-5.6.
Source: JICA Study Team
Figure 7-5.6 2025 Dry Season Peak Power Flows in 330 kV System
7-5-2-2 Dry Season Off-Peak-2025
(1) Prerequisites for analysis
(a) Generation from PVs = 750MW and (b) Reduced generation from HPP plants of 1,390 MW,
The running generation and load for each DisCo are shown in Figure 7-5.7.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1163 MW
8 TO 4 297 MW
3 TO 2 -568 MW
7 TO 4 486 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 449 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
6 JOS EDC
1 IKEJA EDC
4 TO 2 1083 MW
G
G
DISCOS
2 TO 1 1365 MW
4 TO 3 544 MW
Diagram created using'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2025\DP 2025 model Yash with SGRD July 8 reinf.sav''D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yach SGRD.sld'
GG
1 TO 9 231 MW
GG
5 TO 6 -88 MW
6 TO 11 144 MW
G
4 TO 9 336 MW
4 TO 1 1086 MW
G
G
TCN 2025 MODELDISCO DEMANDTHU, JUL 19 2018 11:39
1.002
0.997
12 6
18
0.999
0.990
1.016
306 28
306 28
306 28
306 28
83004
IKOT-EKPENE_
73006UGWUAJI_3
73001
ONITSHA 3
73005ASABA_3
1.019
1.005
286
25
1.018149
20
149
20
1.00473003
MAKURDI_3
1.021
1
1.001
44 10
1
1.012
32 9
10
32 9
10
32 9
10
32 9
10
0.996325
89
325
89
1.005
40
4 40
40
4 40
33007GWAGW BB1
1.011
14 5
37 145
37
146
73
0.993
23005AKURE 3
0.926
1.003
56 1 71
251
124
23001
OSOGBO 3
0.952
40 4
10
40 4
10
24 0
98
10
68
0.955
48 6
65
0.994
21 0
12 2
21 0
12 214
9
337
2
3
23003GANMO 3
23002OMOTOSHO3
0.9961.009
199
82
199
82
342
102342
102
0.945
21 5
57
0.979
0.974
1
2
0.981
26 8
55 26 8
55
26 8
55
26 8
55
13003IKEJA W 3
13029
OGIJO 3
0.977
16 0
28 16 0
28
21 0
3921 0
39
13030MFM 3
0.967
42 128
42 128
0.982
62 5
12 7
62 5
12 7
42 6
94
42 6
94
1.045
88
10
89 90
SW
0 154
42
0.975
50
26
50
26
180
107
18 0
10 7 18 0
10 7 18 0
10 7
44 8
15 1
284
15 284
15
13002
EGBIN 3
0.971
0.980
59 0
15 7
0.986
21
3 1
19
21
3 1
19
64 6
20 0
64 6
20 0
0.996
19 7
60
19 7
60
1.000
252
64
252
64
33 8
94 33 8
94
167
35
167
35
13025EPE 3
13000AJA 3
13031OKO_OBA_313034
LEKKI 33013027
ALAGBON_3
13001
AKANGBA 3
45 0
24
61 10 5
1
33001KATAMPE 3
0.989
160 32
160 32
1.030
312 27
312 27
83007ONNIE_3
1.015
340
48
340
48
356
21 356
21
1
83002ALAOJI 3
1.01918 51 18 51 235
24
77 977 9 235
24
1.013
55
38 55
38
0.996
144
121
144 12
11.019
234
2 23
4
2
83010IKOT ABASI_3
1.030
2
132
13
83000AFAM IV 3
83005OWERRI_3
0.989
297 14
16
61
16
61
0.998
429
65
429
65
374 94
374 94
73004
ALIADE_3
63001JOS 3
0.978
104
21104
21
73010
ABAKALIKI_3
1.048
164 2
5
1
63002YOLA 3
1.046
27
5
20
49
0.968
146
54 14
6
54
13032
NEW_AGBARA_3
0.952
24 3
64
1360
141
23000
AYEDE 3
1.01743000
AJAOKUTA 3
43002BENIN 3
1.007 115
34
43001ALADJA 3
43003DELTA IV 3
1.009
11 5
34
271
56
271
56
271
56
43004SAPELE 3
43011B_NORTH_3
1.017 272 49
272 49
0.997
90 4190 41
43009
OBAJANA_3
1.015
24
5
57
24
5
57
83006
EGBEMA_3
83009
OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000
GOMBE 3
169
11
2
1 2
33020
SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
33021KAINJI 3
1.00996
59
33005
KAINJI G.S.3
33003
JEBBA T.S.3
104
11
104
20
59 0
15 7
44
65
164 2
5
154
42
1.015
111
81
123
27
33009
ZUNGERU
33004
JEBBA G.S.3
33022APO_NEW 3
0.965
33023LAFIA 3
0.998
293 63
30 0
92
50 957
50 957
135
76 135
76
63003BAUCHI 3 1.034
57 1
129
73
63008MAMBILA 3
1.041
1.016
351 35351 351.000
43006EFFURUN 3
126
18
73002
OKPAI 3
1.006
1.006
366 5
366 5
73030IHIALA 3
23006
IBADAN
1.000
13026OKE_ARO_3
229
8
47 11 4
47 6
330 37
330
1
2
1.032
63009WUKARI 3
197
19
197
19
83001
ALAOJI NIPP3
73007
NNEWI 3
0
338
1
2
1
13004SAKETE 3
1.003
1.003
13028ARIGBAJO
11 4 82 82
63006
JALINGO_3
37
6
11 9
67
119
47
26
7
44
13012
PARAS
0.991
15 2
115 2
1
287
91
287
91
33011
FARAKU
0.985
201
57
200
78201
57
200
78
400
157
43012ZUMA 1.013
335
10335
10
59
9
41
59
9
41
53020MILLENIUM
1.004
34
61
34
56
45
60
45 9
63015MAYOBELWA 1.04726
9
43
14 4
17 14 4
17
18
46
18 31
18
46
18 31
123
27 12
3
36
123
27
123
36
12 6
18
127
27
15
4 5
9
154
43
15
4 5
9
154
43
47 3
56
6242 7
62
228
42
43007AZURA
284
46
281
25
43010ETHIOPE
90001
1.01511 11
13
9000290003
1.000
90004
0.953 25 9
90005
1.004
57 7
33
5566
55 66
90006
0.996 92 2 39
91
12991
129
25 1
42
25 1
42
90007
1.017
1147 56
562
24 56
2
24
440
29
440
29
43008
LOKOJA _3
0.978
1.000
90009
1.000
18 2
314 15
3
313
150
13035
IJORA 3
0.968
291
14
291
14409
75
409
75
43005GEREGU
47 3
56
13005OLORUNSOGO3
44 8
15 1
23010
SHAGAMU
0.977
122
70122
70
21 5
57
Export 1540 MW
Total Generation 20152 MWNigeria Load 17634 MW
Generation from HPP 2228 MW
Generation per DISCO Loads per DISCO
3-Abuja 3426 MW
4-Benin 4430 MW
9-Eko 900 MW
7-Enugu 1301 MW
2-Ibadan 1168 MW
1-Ikeja 2701 MW
6-Jos 84 MW
5-Kaduna 218 MW
10-Kano 9 MW
8-Pt Harco 5415 MW
11-Yola 500 MW
Generation from PV 0 MW
Total Load 19174 MW
9-Eko 1837 MW
7-Enugu 1666 MW
2-Ibadan 2266 MW
6-Jos 648 MW
5-Kaduna 1165 MW
10-Kano 1453 MW
8-Pt Harco 1753 MW
11-Yola 532 MW
1-Ikeja 2058 MW
3-Abuja 2329 MW
4-Benin 1827 MW
25 0
66
250
66
1250
48R
1
1
1
1
1250
48R
36033
ABUJA TPP
375
250
125
500
0
MV
A F
low
TCN330kV TRANSMISSINO NETWORK
TCN2025MODEL
Total Generation: 20152 MW
Nigeria Load: 17634 MW
Export: 1540 MW
Total Load: 19174 MW
Generation from PV: 0 MW
Generarion from HPP: 2228 MW
7-65
Source: JICA Study Team
Figure 7-5.7 Dry Season Off-Peak Generation and Load per DisCo
The power flows are shown in Figure 7-5.8.
Source: JICA Study Team
Figure 7-5.8 2025 Dry Season Off- Peak Power Flows in 330 kV System
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 977 MW
8 TO 4 309 MW
3 TO 2 -658 MW
7 TO 4 555 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 399 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 975 MW
G
G
G
DISCOS
2 TO 1 1036 MW
4 TO 3 917 MW
G
G
Diagram created using
'D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\2025\DoP 2025 model Yash with SGRD July 19 reinf.sav''D:\NIGERIA JICA-YACHIYO\PSSE Yachiyo MP\Diagrams-SLDs-Use Power Exch only\Power Exchanges 330kV model Discos Yach SGRD.sld'
GG
3 TO 5 1596 MW
1 TO 9 161 MW
G G
5 TO 6 -183 MW
10 TO 6 0 MW
5 TO 10 -488 MW
6 TO 11 199 MW
G
4 TO 9 136 MW
4 TO 1 788 MW
G
G
TCN 2025 MODELDISCO DEMANDTHU, JUL 19 2018 22:25
1.016
1.010
143
19
1.014
1.013
1.023
269 7
269 7
269 7
269 7
83004IK OT -E K P E NE _
73006
UGWUA JI_3
73001ONIT S HA 3
73005A S A B A _3
1.026
1.018
298
23
1.027
155
29155
29
1. 03073003
MA K URDI_3
1.033
1
0 80
1.019
92 24
1
1.022
21 9
20
21 9
20
21 9
20
21 9
20
1.025243
45
243
45
1. 021
234 14
234 14
33007
GWA GW B B 1
1.023
30
16
30
16
30
62
1.005
23005
A K URE 3
0.964
1.015
501 38
209
93
23001OS OGB O 3
0.980
361
5
361
5
225
65
10
72
0.979
49 9
37
0.999
22 3
80
22 3
80
212
223
2
3
23003
GA NMO 3
23002
OMOT OS HO3
33002B K E B B I 3 0.950
1.0000.999
134
28
135
28
350
43350
43
234 47
0. 973
28 9
60
1.000
0.992
1
2
1.000
195
54 195
54
195
54
195
54
13003
IK E JA W 3
13029
OGIJO 3
0.996
111
44 111
44
15 3
48
15 3
48
13030MF M 3
0.988
17 95 17 95
0.997
56 2
83
56 2
83
398
49
398
49
1.034
78
41
79 62
1
0 53
2
0 53SW
0
63007
DA MA T URU 3 1.043
97 64
63005MA IDUGURI 3 1.028
52
66
2
0 79
0. 996
71
41
71
41
183
93
183
93
183
93 183
93
49 1
10 7
262
4 262
4
13002E GB IN 3
0.990
0.997
521
103
1.001
205
73 205
73
56 8
13 4
56 8
13 4
1.009
165
47
165
47
1.012
211
42
211
42
284
70 284
70
68
53
68
53
13025
E P E 3
13000A JA 3
13031
OK O_OB A _313034LE K K I 33013027
A LA GB ON_3
13001
A K A NGB A 3
346
40
45
73
1
33001K A T A MP E 3
1.020
124 20124 20
1. 036
328 19
328 19
83007
ONNIE _3
1.024
411
48
411
48
388
34 388
34
1
83002A LA OJI 3
1.02713 41 13 41 281
27
64 17
64 17
281
27
1. 022
84
21 84
21
1. 010
114 88 114 88
1.025
25614 25614
83010
IK OT A B A S I_3
1.037
14
17 14
17
83000
A F A M IV 3
83005
OWE RRI_3
1.012
282 12
2 57
2 57
1. 024
401
78 401
78
353 84
353 84
73004
A LIA DE _3
63001JOS 3
1.005
88 488 4
73010A B A K A LIK I_3
1.019
98
12
1
0 78
63002Y OLA 3
1.028
182 2
3
53001K A NO 3
0.968
0
70
0.966
152
14
0
70
53005
K A NO_NE W330
1.009
318
10
53003
Z A RIA _330
53000
K A DUNA 3
53002
K A T S INA 3
0.985
1
1
1
65
1
11
65
0.989
127 54
127
5413032
NE W_A GB A RA _3
0.973
24 7
55
1360
141
23000A Y E DE 3
1.02043000
A JA OK UT A 3
43002
B E NIN 3
1.017 200
15
43001
A LA DJA 3
43003
DE LT A IV 3
1.014
20 0
15
111
21
111
21
111
21
43004
S A P E LE 3
43011
B _NORT H_3
1.020
0 10 1
1. 016
65 1965 19
43009
OB A JA NA _3
1.025
233 34
233 34
83006
E GB E MA _3
83009OMOK U_3
83008CA LA B A R_P S _3
83003
A DIA GB O_3
63000GOMB E 3
179 14
2
1 2
33020S HIRORO 3
33008
WE S T MA IN_3
73000NHA V E N 3
0.985
89
93
89
93
53004
F UNT UA 3
1.017
38
44
38
44
53007T MA F A RA 3
1.006
53008
GUS A U 3
124
27 124
27
109
64 109
64
263
17263
17
33021
K A INJI 3
0.99965
31
33005
K A INJI G.S .3
33003
JE B B A T .S .3
124
13
125
17
521
103
234 47
234 47
91
50
98
12
97 64
52
66
1. 022
88
85
67 6
33009
Z UNGE RU
33004
JE B B A G.S .3
33022A P O_NE W 3
0.999
33023
LA F IA 3
1.028
218 6
22 1
65
41246
41246
132
72 132
72
63003
B A UCHI 3 1.037
57
30
107
46
63008
MA MB ILA 3
1.027
1.024
351 15
351 151. 000
43006
E F F URUN 3
143
19
73002OK P A I 3
1.017
1.018
369 13
369 13
73030
IHIA LA 3
23006
IB A DA N
1.000
13026
OK E _A RO_3
220
6
53012DUT S E 3
1.000
53011
K A Z A URE 3
0.980
1 125
1 58
225
8
225
1
0 11
2
0 78
1. 039
63009
WUK A RI 3
1.013
202
33
202
33
83001
A LA OJI NIP P 3
73007
NNE WI 3
0
329
30
338
1
2
1
13004
S A K E T E 3
112
62
113
23
1.015
1.015
13028A RIGB A JO
125 101 101
63006JA LINGO_3
8
58
33010
Z A B ORI
0.902
320
132
315
124 320
132
315
124631
247
115
75
115
53
445 83
SW 0
13012
P A RA S
1.006
16 7
36
16 7
36
302
41
302
41
33011
F A RA K U
0.974
201
58
200
78201
58
200
78
400
157
43012Z UMA 1.023
234
71
234
71
332 13
332 13
53013DA URA
0.980
19
1519
15
9
289
28
53016JOGA NA
0.978 48 107
4898
21 6
15
213
53
65
0
65
0
53020MILLE NIUM
1.021
83
46
83
41
92
45
93 23
63015
MA Y OB E LWA 1.022
172
1
4
54
5
49
70
49 5
49
70
49 5 67 6
67
3
67 6
67
3
143
19
144
26
168
38
168
22
168
38
168
22
47 3
5
32 4
42
320
93
32 4
42
320
93
219
30
43007A Z URA
189 21
188
12
112
62
113
23
43010
E T HIOP E
90001
1.02310 12
75
9000290003
1.000
90004
0.981 274
90005
1.030
429
10
50 6 38
50 6 38
90006
1.025
773
65
131
137
131
137
27 8
51
27 8
51
90007
1.020
667
121
330
9
330
9
90008
1.017
687
33
348
42
348
42
43008LOK OJA _3
1.009
1.000
90009
1.000
26 2
33006
S OK OT O 3
26 1 113
261
108
13035
IJORA 3
0.988
268
4
268
4368
45
368
45
43005
GE RE GU
47 3
5
13005
OLORUNS OGO3
49 1
10 7
23010
S HA GA MU
0.997
106
49106
49
28 9
60
1.000
190
35
32021
NIA ME Y 1
0.85660 18
52010GA Z OUA 1
S W
72
Export 1541 MW
Total Generation 17232 MWNigeria Load 14950 MW
Genera tion from H PP 1390 MW
Generation per DISCO Loads per DISCO
3-Abuja 1932 MW
4-Benin 3520 MW
9-Eko 900 MW
7-Enugu 1301 MW
2-Ibadan 1168 MW
1-Ikeja 2523 MW
6-Jos 214 MW
5-Kaduna 340 MW
10-Kano 189 MW
8-Pt Harco 4815 MW
11-Yola 330 MW
Genera tion from PV 750 MW
Total Load 16491 MW
9-Eko 1551 MW
7-Enugu 1409 MW
2-Ibadan 1930 MW
6-Jos 547 MW
5-Kaduna 984 MW
10-Kano 1321 MW
8-Pt Harco 1488 MW
11-Yola 450 MW
1-Ikeja 1738 MW
3-Abuja 1968 MW
4-Benin 1564 MW
250
10 4
0
96
1250
84R
1
1
1
1
10
93R
36033
A B UJA T P P
375
250
125
500
0
MV
A F
low
TCN330kV TRANSMISSINO NETWORK
TCN2025MODEL Total Generation: 17232 MW Nigeria Load: 14950 MW Export: 1541 MW Total Load: 16491 MW Generation from PV: 750 MW
Generarion from HPP: 1390 MW
7-66
7-5-3 Contingency (N-1) Analysis for 330 kV Circuits
The contingency N-1 analysis carried out for the 330 kV lines has shown that the following 330 kV DC lines are overloaded and require reinforcement by converting to Quad conductors.
Table 7-5.6 Overloaded 330 kV lines under N-1
Substation Name Substation Name Rating (MVA)
Flow (MVA)
Loading (%)
Length (km)
AJA LEKKI 856 1,372 160.4 7
ALAGBON LEKKI 856 1,184 138.5 14
LOKOJA ZUMA 856 1,117 130.7 24
Source: JICA Study Team
Reconductoring to Quad-bundle conductors has already been implemented by TCN. This is also assumed to be possible for these lines, but must be verified to ensure the structures are suitable. If not, the DC lines will need to be replaced.
7-5-4 2025 Base Case Load-flow Results
7-5-4-1 Overloads of 330 kV or 132 kV Lines
There are no overloaded 330 kV or 132 kV lines which are overloaded under normal operation (base case).
7-5-4-2 Overloads of Transformers
The 330/132 kV 3-W and A/T transformers overloaded above their 100% rating MVA under normal (base case) operation, in addition to those reported for the 2020 case, are listed in Table 7-5.7 and must be upgraded.
Table 7-5.7 Overloaded 330/132 kV transformers
Bus Number
Bus Name Voltage
(kV) Bus
Number Bus Name
Voltage (kV)
cct Load
(MVA) Rating (MVA)
Loading (%)
83003 ADIAGBO_3 330 3WNDTR ADIAGB T1A WND 1 1 188.2 150 125.5
83003 ADIAGBO_3 330 3WNDTR ADIAGB T1B WND 1 2 188.2 150 125.5
12000 AJA 132 132 3WNDTR AJA T4 WND 1 1 68.9 45 153.2
13000 AJA 3 330 3WNDTR AJA T2A WND 1 3 194.6 150 129.8
42000 AJAOKUTA 1 132 3WNDTR AJAOK T1A WND 2 1 86 80 107.5
42000 AJAOKUTA 1 132 3WNDTR AJAOK T2A WND 2 1 86 80 107.5
42000 AJAOKUTA 1 132 3WNDTR AJAOK T3A WND 2 1 86 80 107.5
13001 AKANGBA 3 330 3WNDTR AKANGBA5T4A WND 1 1 152.4 150 101.6
13001 AKANGBA 3 330 3WNDTR AKANGBA5T4B WND 1 1 152.4 150 101.6
12016 AKOKA 1 132 3WNDTR AKOKA T1 WND 1 1 53.8 45 119.6
23005 AKURE 3 330 3WNDTR AKURE T1A WND 1 1 182.2 150 121.5
23005 AKURE 3 330 3WNDTR AKURE T1B WND 1 2 182.2 150 121.5
12022 APAPA RD 1 132 3WNDTR APAPA RD T1 WND 1 1 46.4 45 103.2
23000 AYEDE 3 330 3WNDTR AYEDE TR1 WND 1 1 198.9 150 132.6
23000 AYEDE 3 330 3WNDTR AYEDE TR2 WND 1 1 197.1 150 131.4
23000 AYEDE 3 330 3WNDTR AYEDE TR3 WND 1 1 197.1 150 131.4
42003 DELTA 1 132 43003 DELTA IV 3 330 1 270.1 150 180.1
42003 DELTA 1 132 43003 DELTA IV 3 330 2 270.1 150 180.1
23003 GANMO 3 330 3WNDTR GANMO TR1A WND 1 1 212.4 150 141.6
72036 IHIALA 1 132 3WNDTR IHIALA TR WND 2 1 124.2 120 103.5
7-67
Bus Number
Bus Name Voltage
(kV) Bus
Number Bus Name
Voltage (kV)
cct Load
(MVA) Rating (MVA)
Loading (%)
13003 IKEJA W 3 330 3WNDTR IKW T2B WND 1 3 163.1 150 108.7
12027 ISOLO 1 132 3WNDTR ISOLO TR3 WND 1 1 53.3 45 118.3
22012 JERICHO 1 132 3WNDTR JERICO TR1 WND 1 1 73.7 45 163.8
53001 KANO 3 330 3WNDTR KANO OLD T5A WND 1 2 169.6 150 113
53001 KANO 3 330 3WNDTR KANO T3A WND 1 1 169.6 150 113
52030 KUMB T1A BB 132 3WNDTR KANO T1A WND 2 1 242.5 225 107.8
73007 NNEWI 3 330 3WNDTR NNEWI T2A WND 2 1 91.8 67.5 136
22014 OMOTOSHO 1 132 3WNDTR OMOTOSHO TR1 WND 2 1 134.3 120 111.9
22024 OMOTOSHO 2 132 3WNDTR OMOTOSHO TR2 WND 2 1 137.7 120 114.8
73001 ONITSHA 3 330 3WNDTR ONITSH T3A WND 1 1 152.4 150 101.6
73001 ONITSHA 3 330 3WNDTR ONITSHA T4 WND 1 1 157.6 150 105.1
22001 OSOGBO 1 132 3WNDTR OSOGBO 4T1 WND 2 1 134.9 120 112.5
22001 OSOGBO 1 132 3WNDTR OSOGBO 4T6 WND 2 1 134.9 120 112.5
22001 OSOGBO 1 132 3WNDTR OSOGBO N T5 WND 2 5 134.9 120 112.5
82028 OWERRI 1 132 3WNDTR OWERRI TR1 WND 1 1 70.1 60 116.8
83005 OWERRI_3 330 3WNDTR OWERRI T1A WND 1 1 160.6 150 107.1
32027 WESTMAIN_1 132 3WNDTR EASTMAIN TR1 WND 2 1 135.3 120 112.7
32027 WESTMAIN_1 132 3WNDTR EASTMAIN2 WND 2 2 135.3 120 112.7
Source: JICA Study Team
The 132/33 kV and 132/11 kV transformers overloaded above their 100% MVA rating under normal (base case) operation, listed in Table 7-5.8, are in addition to those overloaded in 2020 and must be upgraded. Some of these transformers, shown in bold, have already been reported in the 2020 case as being overloaded above their 85% rating:
Table 7-5.8 Overloaded 132/33 kV transformers
Bus Number
Bus Name Voltage
(kV) Bus
Number Bus Name
Voltage (kV)
cct Load
(MVA) Rating
(MVA) Loading
(%)
82026 ABA 1 132 86020 ABA T1A 6.6 6.6 1 8.6 7.5 114
82026 ABA 1 132 85023 ABA T4A(MOB) 33 1 17.5 15 116.4
72016 ABAKALIKI 1 132 75001 ABAKALIKI 33 33 1 72.1 60 120.2
82000 AFAM 1-2-3 132 86000 AFAM 11 11 1 119.3 64 186.4
82018 AHOADA 1 132 85038 AHOADA T2 33 2 42.9 40 107.4
12000 AJA 132 132 15003 AJA 33 33 1 107.2 60 178.6
42000 AJAOKUTA 1 132 45033 AJAOKUTA T2 33 1 64.8 60 107.9
12004 AKANGBA BBII 132 15053 AKANGBA 33 33 1 67.8 60 113
12016 AKOKA 1 132 15067 AKOKA T2 33 1 47.6 40 119
22005 AKURE 1 132 25003 AKURE 33 33 1 40.9 30 136.4
22005 AKURE 1 132 25028 AKURE T2A 33 2 46.7 30 155.6
22005 AKURE 1 132 25018 AKURE T3A 33 33 1 82.6 60 137.7
12017 ALAGBON 1 132 15008 ALAGBON 33 33 1 70.9 66 107.4
12017 ALAGBON 1 132 15008 ALAGBON 33 33 2 70.9 66 107.4
12019 ALIMOSHO 1 132 15010 ALIMOSHO 33 33 1 37.8 30 125.9
12019 ALIMOSHO 1 132 15072 ALIMOSHO T1 33 3 48.5 30 161.6
42015 AMUKPE 1 132 45026 AMUKPE BB 33 33 1 68.3 60 113.9
12054 ARIGBAJO 1 132 15062 ARIGBAJO 33 33 1 61.1 60 101.9
12054 ARIGBAJO 1 132 15062 ARIGBAJO 33 33 2 61.1 60 101.9
22000 AYEDE 1 132 25004 AYEDE 33 33 1 107.1 100 107.1
22000 AYEDE 1 132 25045 AYEDE 33 33 3 81.3 60 135.5
42004 BENIN 1 132 45000 BENIN 33 33 1 67.8 60 112.9
42004 BENIN 1 132 45000 BENIN 33 33 9 67.8 60 112.9
7-68
Bus Number
Bus Name Voltage
(kV) Bus
Number Bus Name
Voltage (kV)
cct Load
(MVA) Rating
(MVA) Loading
(%)
52007 DAN AGUNDI 1 132 55001 DAN AGUNDI 3 33 1 73.2 60 122
12002 EGBIN 1 132 15033 EGBIN 33 33 1 46.9 40 117.2
12023 EJIGBO 1 132 15014 EJIGBO 33 33 1 46.2 30 153.9
12023 EJIGBO 1 132 15014 EJIGBO 33 33 2 46.2 30 153.9
12023 EJIGBO 1 132 15128 EJIGBO 33 33 1 46.2 30 153.9
12023 EJIGBO 1 132 15128 EJIGBO 33 33 2 46.2 30 153.9
12023 EJIGBO 1 132 15016 EJIGBO BBI 3 33 1 104.6 100 104.6
82005 EKET 1 132 85003 EKET 33 33 2 80.2 60 133.6
82005 EKET 1 132 85002 EKET T1B 33 1 96.3 45 213.9
82035 ELELENWO 1 132 85036 ELENLEWO 33 33 1 42.1 40 105.3
82035 ELELENWO 1 132 85036 ELENLEWO 33 33 2 42.1 40 105.3
22022 GANM0 T1 BB 132 25032 GANMO T1 33 1 118.5 60 197.5
62029 GASHUWA 1 132 65062 GASHUWA T2A 33 2 54.9 45 122
62029 GASHUWA 1 132 65061 GASHUWAT1A 33 1 54.9 45 122
52011 GUSAU 1 132 55004 GUSAU 33 33 1 40.6 30 135.4
52011 GUSAU 1 132 55046 GUSAU T1 33 2 35.6 30 118.5
22006 IBADAN NORTH 132 25007 IBADAN NORTH 33 1 88.3 60 147.2
22006 IBADAN NORTH 132 25042 IBADAN T2 BB 33 2 79.3 60 132.2
22028 IJEBU-ODE 1 132 25041 IJEBU T1 BB 33 1 60.6 60 101
12024 IJORA 1 132 15045 IJORA T1A&B 33 2 33.2 30 110.8
12024 IJORA 1 132 15046 IJORA T2B 33 2 36.1 30 120.4
12025 IKORODU 132 15050 IKORODU T3 33 3 102.5 100 102.5
82031 IKOT_ABASI 132 85092 IKOT ABAS 33 33 1 52.3 40 130.9
82031 IKOT_ABASI 132 85092 IKOT ABAS 33 33 2 52.3 40 130.9
22009 ILESHA 1 132 25010 ILESHA 33 33 1 40.1 40 100.3
22009 ILESHA 1 132 25031 ILESHA T1 33 2 40.1 40 100.3
12026 ILLUPEJU 1 132 16033 ILLUPEJU T2 11 3 31 30 103.2
12026 ILLUPEJU 1 132 16025 ILUPEJU 11 11 2 15.1 15 100.8
12026 ILLUPEJU 1 132 15027 ILUPEJU 33 33 1 32 30 106.7
42008 IRRUA 1 132 45002 IRRUA 33 33 1 79.1 60 131.9
22011 ISEYIN 1 132 25012 ISEYIN 33 33 1 46.8 45 104
22011 ISEYIN 1 132 25049 ISEYIN T2 33 33 1 40.8 30 136.1
12027 ISOLO 1 132 15028 ISOLO 33 33 1 77.6 60 129.4
12020 ITIRE 1 132 16034 ITERE T3 11 2 44.9 40 112.1
12020 ITIRE 1 132 16032 ITIRE 11 11 1 33.4 30 111.2
22008 IWO 1 132 25002 IWO 33 33 1 45.8 40 114.5
22008 IWO 1 132 25002 IWO 33 33 2 45.8 40 114.5
62020 JALINGO 1 132 65015 JALINGO 33B 33 1 32.4 30 108
22012 JERICHO 1 132 25013 JERICHO2 33 33 1 66.4 40 166.1
62001 JOS 1 132 65005 JOS T4 60MVA 33 2 99.7 60 166.2
52003 KADUNA TOWN 132 55006 KADUNA TOWN 33 1 33.6 30 111.9
52003 KADUNA TOWN 132 55061 KD TWN T1 33 2 33.6 30 111.9
62025 KAFANCHAN 1 132 65037 KAFANC M TR1 33 3 55.2 40 138.1
52001 KANO 1 132 55057 KUMB T2 33 1 53 40 132.5
52001 KANO 1 132 55059 KUMB T4 33 4 68.8 60 114.7
52029 KANO_NEW132 132 55070 KANOII 33 33 1 72.7 60 121.2
52029 KANO_NEW132 132 55070 KANOII 33 33 2 72.7 60 121.2
52012 KATSINA 1 132 55056 KATSINA T3 33 3 41.7 30 139.1
52042 KAZAURE 1 132 55092 KAZAURE 33 33 1 32.4 30 108
52042 KAZAURE 1 132 55092 KAZAURE 33 33 2 32.4 30 108
62024 MAKERI 1 132 65033 MAKERI 33 33 1 30.3 30 101.1
7-69
Bus Number
Bus Name Voltage
(kV) Bus
Number Bus Name
Voltage (kV)
cct Load
(MVA) Rating
(MVA) Loading
(%)
72002 NHAVEN 1 132 75039 NHAV TR2 33 2 32 30 106.6
72002 NHAVEN 1 132 75041 NHAV TR4 33 4 68 60 113.4
72011 NKALAGU 1 132 75044 NKALGU T1A 33 2 31.9 30 106.3
12055 ODOGUNYAN 1 132 15063 ODOGUNYA 33 33 1 84.4 60 140.6
12055 ODOGUNYAN 1 132 15063 ODOGUNYA 33 33 2 84.4 60 140.6
12032 OGBA 1 132 16027 OGBA 11 11 1 20.4 20 102
12029 OJO 1 132 15030 OJO 33 33 2 33.5 30 111.6
12029 OJO 1 132 15047 OJO T3_T4 33 5 85.2 60 142
22017 ONDO2 1 132 25017 ONDO1 33 33 1 63.7 60 106.2
72001 ONITSHA 1 132 75037 ONITSH TR14 33 5 42.9 40 107.2
72001 ONITSHA 1 132 75038 ONITSHA TR11 33 4 65.1 60 108.4
22001 OSOGBO 1 132 25026 OSOGBO 33 33 3 64.8 60 108
22001 OSOGBO 1 132 25029 OSOGBO T1 33 1 41.3 30 137.7
22001 OSOGBO 1 132 25030 OSOGBO T2 33 2 34.9 30 116.3
12033 OTTA 1 132 15079 OTTA T2 33 2 76.8 60 127.9
82028 OWERRI 1 132 85020 OWERR T1MOB 33 1 40.2 40 100.6
12034 OWOROSOKI 1 132 15020 OWOROSOKI 33 33 1 64.7 60 107.8
12037 PARAS_1 132 15116 AFR FOUNDRY 33 1 62.9 40 157.2
12037 PARAS_1 132 15115 PARAS IPP 33 1 43.8 40 109.6
12037 PARAS_1 132 15115 PARAS IPP 33 2 65.8 60 109.6
82008 PHCT TOWN1 1 132 85027 PHCT T1A 33 2 63.4 60 105.6
82009 PHCT TOWN2 1 132 86018 PHCT TOWN 11 11 1 65.6 60 109.3
82036 RUMUSOI 1 132 85060 RUMUSOI T133 33 1 70 60 116.7
82036 RUMUSOI 1 132 85061 RUMUSOI T233 33 1 70 60 116.7
62012 SAVANNAH 1 132 65010 SAVANNAH 33 33 1 18.4 15 122.5
22027 SHAGAMU 1 132 25040 SHAGAM T2 BB 33 2 38 30 126.6
22027 SHAGAMU 1 132 25035 SHAGAMU 33 33 1 59.1 30 197.1
12036 SHAGAMU
CEME 132 16007 SHAG CEM 11 11 1 16.1 15 107.4
12036 SHAGAMU
CEME 132 16038 SHAG CEM 11 11 2 16.1 15 107.4
32001 SHIRORO 1 132 35013 SHIRORO 33 33 1 51.3 30 171
32016 SOKOTO 1 132 35050 SOKOTO T3 33 3 41.8 30 139.5
32017 SULEJA 1 132 35047 SULEJA T3 33 2 41.4 30 138.1
32014 TEGINA 1 132 35015 TEGINA 33 33 1 42.6 30 142.1
42002 UGHELLI 1 132 45001 UGHELLI 33 33 1 92.6 60 154.3
82027 UMUAHIA 1 132 85024 UMUAHIA 33 33 1 44.5 40 111.2
82027 UMUAHIA 1 132 85024 UMUAHIA 33 33 2 44.5 40 111.2
82010 UYO 1 132 85007 UYO 33 33 3 95.2 60 158.7
82010 UYO 1 132 85030 UYO T2B 33 1 51 40 127.4
82010 UYO 1 132 85030 UYO T2B 33 2 51 40 127.4
7-5-4-3 Reactive Power Compensation Requirements
(1) SVC requirements
No SVC is needed in 2025, but more detailed and dedicated studies will subsequently be necessary stage to determine any need for such equipment in the post-2025 period.
In 2025, in addition to the reactors and capacitors listed in Table 7-5.9, Table 7-5.10, Table 7-5.11 and
7-70
Table 7-5.12, reactive power compensation (150 MVar capacitors) will be required at Bernin Kebbi due to export requirements to WAPP. It should be noted however that in 2030, the proposed supergrid will be extended with a Kainji-Bernin Kebbi line. Once this is implemented, there will be no further need for reactive power compensation at Bernin Kebbi.
With regards to Gombe, should additional reactive power compensation be required at lightly loaded conditions, instead of SVC, a more cost-effective option would be relocating from other S/S to Gombe approximately 100-150 MVar of reactors that, as this analysis has shown, are no longer needed there.
As was shown in the static security analysis for 2025, a more appropriate candidate for an SVC (or in fact only capacitors, given the lack of MVars) could be the Lagos/Ikeja/Eko region, where there is a reactive power deficit of approximately 400-500 MVar. It should be noted however that this deficit is expected to ease when the DisCos implement the reactive power control program at distribution level, as proposed and in line with the Grid Code requirements, as well as when transmission lines and transformers are upgraded, as has been shown in previous chapters of this report.
(2) Reactors
The status of reactors required in the Dry Season Peak case is shown in Table 7-5.9.
Table 7-5.9 Reactor requirements for the 2025 Dry Season Peak
Bus Number
Bus Name Voltage
(kV) Id In Service
B-Shunt (MVar)
63005 MAIDUGURI 3 330 2 1 -75
65001 YOLA T1 33 33 1 1 -30
65014 GOMBE T4A 33 1 1 -30
Source: JICA Study Team
The status of reactors required in the Dry Season Off-Peak case is shown in Table 7-5.10.
Table 7-5.10 Reactor requirements for the 2025 Dry Season Off-Peak
Bus Number
Bus Name Voltage
(kV) Id In Service
B-Shunt (MVar)
53001 KANO 3 330 1 1 -75
53005 KANO_NEW330 330 1 1 -75
63001 JOS 3 330 1 1 -75
63002 YOLA 3 330 1 1 -75
63002 YOLA 3 330 2 1 -75
63005 MAIDUGURI 3 330 2 1 -75
63000 GOMBE 3 330 1 1 -50
63000 GOMBE 3 330 2 1 -50
65001 YOLA T1 33 33 1 1 -30
65014 GOMBE T4A 33 1 1 -30
63006 JALINGO_3 330 1 1 -10
Source: JICA Study Team
7-71
(3) Capacitors
The status of capacitors required in the Dry Season Peak case is shown in Table 7-5.11.
Table 7-5.11 Capacitor requirements for the 2025 Dry Season Peak
Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
75004 AWKA 33 33 1 1 10
75012 OJI RIVER 33 33 1 1 10
15002 AGBARA 33 33 1 1 20
15011 ABEOKUTA OLD 33 2 1 20
15022 IKORODU 33 33 2 1 20
15027 ILUPEJU 33 33 1 1 20
15030 OJO 33 33 1 1 20
25004 AYEDE 33 33 1 1 20
25012 ISEYIN 33 33 1 1 20
25018 AKURE T3A 33 33 1 1 20
25035 SHAGAMU 33 33 1 1 20
25038 IJEBU-ODE 33 33 1 1 20
35000 AKWANGA 33 33 1 1 20
35001 APO 33 33 2 1 20
35009 KONTAGORA 33 33 1 1 20
35012 MINNA 33 33 1 1 20
35048 MINNA T2 33 2 1 20
42014 EFFURUN 1 132 2 1 20
42015 AMUKPE 1 132 1 1 20
45003 OKENE 33 33 1 1 20
52022 HADEJIA 1 132 1 1 20
55001 DAN AGUNDI 3 33 2 1 20
55010 KATSINA 33 33 1 1 20
55011 ZARIA 33 33 1 1 20
55032 MALUMFASHI_3 33 1 1 20
55051 DAKATA T2 33 1 1 20
55057 KUMB T2 33 1 1 20
55069 KD TWN T2 33 1 1 20
55072 KD TWN T3 33 1 1 20
72009 AWKA 1 132 1 1 20
75002 APIR 33 33 1 1 20
75017 YANDEV 33 33 1 1 20
75048 APIR_33B 33 1 1 20
15006 AKANGBA 33 33 1 1 24
15007 AKOKA T1 33 33 1 1 24
15009 ALAUSA 33 33 1 1 24
15010 ALIMOSHO 33 33 1 1 24
15014 EJIGBO 33 33 1 1 24
15015 IJORA 33 33 1 1 24
15018 OGBA 33 33 1 1 24
15028 ISOLO 33 33 1 1 24
15079 OTTA T2 33 1 1 24
15080 OLD ABEOK T2 33 3 1 24
15128 EJIGBO 33 33 1 1 24
22017 ONDO2 1 132 1 1 24
25011 ILORIN 33 33 1 1 24
7-72
Bus Number
Bus Name Voltage
(kV) Id
In Service
Capacity (MVar)
25012 ISEYIN 33 33 2 1 24
42008 IRRUA 1 132 1 1 24
45027 IRRUA BBII33 33 1 1 24
32012 KEFFI 1 132 1 1 25
82006 ITU 1 132 1 1 40
22015 OMUARAN 1 132 1 1 50
35036 GWAGWALAD 33 33 1 1 50
52022 HADEJIA 1 132 2 1 50
53001 KANO 3 330 2 1 50
53001 KANO 3 330 3 1 50
32006 APO 1 132 1 1 60
32017 SULEJA 1 132 1 1 60
12004 AKANGBA BBII 132 1 1 72
12032 OGBA 1 132 1 1 72
82010 UYO 1 132 1 1 100
Source: JICA Study Team
The status of capacitors required in the Dry Season Off-Peak case is shown in Table 7-5.12.
Table 7-5.12 Capacitor requirements for the 2025 Dry Season Off-Peak
Bus Number
Bus Name Voltage
(kV) Id In Service
Capacity (MVar)
15002 AGBARA 33 33 1 1 20
15011 ABEOKUTA OLD 33 2 1 20
15022 IKORODU 33 33 2 1 20
15027 ILUPEJU 33 33 1 1 20
25004 AYEDE 33 33 1 1 20
25012 ISEYIN 33 33 1 1 20
25018 AKURE T3A 33 33 1 1 20
25035 SHAGAMU 33 33 1 1 20
25038 IJEBU-ODE 33 33 1 1 20
35001 APO 33 33 2 1 20
35012 MINNA 33 33 1 1 20
42014 EFFURUN 1 132 2 1 20
42015 AMUKPE 1 132 1 1 20
45003 OKENE 33 33 1 1 20
52022 HADEJIA 1 132 1 1 20
55001 DAN AGUNDI 3 33 2 1 20
55010 KATSINA 33 33 1 1 20
15006 AKANGBA 33 33 1 1 24
15007 AKOKA T1 33 33 1 1 24
15009 ALAUSA 33 33 1 1 24
15010 ALIMOSHO 33 33 1 1 24
15014 EJIGBO 33 33 1 1 24
15015 IJORA 33 33 1 1 24
15028 ISOLO 33 33 1 1 24
15079 OTTA T2 33 1 1 24
15128 EJIGBO 33 33 1 1 24
22017 ONDO2 1 132 1 1 24
25011 ILORIN 33 33 1 1 24
25012 ISEYIN 33 33 2 1 24
42008 IRRUA 1 132 1 1 24
7-73
Bus Number
Bus Name Voltage
(kV) Id In Service
Capacity (MVar)
45027 IRRUA BBII33 33 1 1 24
52022 HADEJIA 1 132 2 1 24
32012 KEFFI 1 132 1 1 25
82006 ITU 1 132 1 1 40
32021 NIAMEY 1 132 2 1 45
22015 OMUARAN 1 132 1 1 50
32006 APO 1 132 1 1 60
12004 AKANGBA BBII 132 1 1 72
82010 UYO 1 132 1 1 100
Source: JICA Study Team
7-5-5 Expansion Plan for 2025
In addition to the projects undertaken by TCN and NIPP, the following 330 and 132 kV lines, shown in Table 7-5.13, are included in the 2025 model. These are also in addition to those included in the 2020 model. A priority ranking from 1 to 3 has been included in the table, with 1 denoting the highest priority.
Table 7-5.13 Additional lines required by 2025 (1)
No Area From To
Voltage (kV)
Length (km)
Remarks Priority/ Ranking
1 Ejio (Arigbajo) Ayede SC 330 50
Turn-in/out Ejio (Arigbajo)-Osogbo line at Ayede, or have one direct line Ikeja West-Ayede, instead of two lines: Ikeja West Ejio (Arigbajo) and Ejio (Arigbajo)-Osogbo
1
2
Part of North-Wes
t Ring
Birnin-Kebbi Sokoto DC 330 130 in parallel of existing 132 kV 3
3 Sokoto Talata Mafara DC 330 100
3
4 Talata Mafara Gusau DC 330 125
3
5 Gusau Funtua DC 330 70
2
6 Funtua Zaria DC 330 70 2
7 Olorusongo Ejio (Arigbajo) DC 330 20
JICA. Already a DC. 4 circuits are required, or conversion of the two circuits from twin to Quad-bundle conductors.
2
8 Katsina Daura DC 330 40 Undertaken by TCN as part of the Northern Corridor Transmission projects 2, to be financed by AFD
2
9 Daura Kazaure DC 330 25 Undertaken by TCN as part of the Northern Corridor Transmission projects 2, to be financed by AFD
2
10
Part of North-East
Ring
Damaturu Maiduguri DC 330 260 If not by 2020, implement as soon as possible thereafter (An SC already exists.)
3
11 Gombe Daimaturu DC 330 160 If not by 2020, implement as soon as possible thereafter (An SC already exists.)
3
12 Gombe Yola DC 330 240 If not by 2020, implement as soon as possible thereafter (An SC already exists.)
3
13 Yola Jalingo DC 330 160 If not by 2020, implement as soon as possible thereafter (1 SC via Mayo Belwa)
3
14 Mambila
evacuation Mambila Jalingo 2xDC 330 95
2xDC only if N-2 is adopted, otherwise 1xDC
1
7-74
No Area From To
Voltage (kV)
Length (km)
Remarks Priority/ Ranking
15 Mambila Wukari 2xDC 330 159 2xDC only if N-2 is adopted, otherwise 1xDC
1
16 Wukari Makurdi DC 330 159
1
16 Wukari Lafia DC 330 95 after 2025 3
18 Shiroro Kaduna DC 330 96
or upgrade to 4-b (Quad). Two DC project with Quad conductors is undertaken by TCN as part of the Northern Corridor Transmission projects 2, to be financed by AFD
3
19 Ejio (Arigbajo) Ajegunle (New
Agbara) DC 330 40 JICA. 2
20 Ejio (Arigbajo) Likosi (Ogijo) DC 330 48 JICA. 2
21 Ajegunle (New
Agbara) Badagry DC 132 32 JICA. 2
22 Ejio (Arigbajo) New Ajeokuta DC 132 37 JICA. 2
23 Gwangwalada Shiroro DC 330 a SC exists 1
24 Benin North Omotosho DC 330 110 Quad conductors. May be required before 2025 and as early as 2022 for the evacuation of new Ethiope PP
1
25 Zungeru Kainji DC 330 200 2
26 Zungeru Shiroro DC 330 25 2
27
Part of the future
Supergrid
Ikot-Ekpene Makurdi DC 330 320 1
28 Makurdi Gwangwalada DC 330 180 1
29 Ajaokouta Gwangwalada DC 330 150 1
30 Osogbo Gwangwalada DC 330 250 1
31 Gwangwalada Funtua DC 330 250 1
Source: JICA Study Team
Furthermore, since a number of undervoltages were encountered in the Dry Season Peak case and also to meet the N-1 security criterion, the following additions, shown in Table 7-5.14, were made at 132 kV level:
Table 7-5.14 Additional 132 kV lines required by 2025 (2)
No From To
Voltage (kV)
Length (km)
Remarks Priority/ Ranking
1 Shiroro Tegina SC 132 65 SC only exists. Add a second SC 1
2 Tegina Kontagora SC 132 90 SC only exists. Add a second SC 1
3 Kontagora Yelwa-Yauri SC 132 88 SC only exists. Add a second SC 1
5 Ganmo Ilorin SC 132 10.5 SC only exists. Add a second SC 3
6 Obajana Egbe DC 132 97 new DC 1
7 Omotosho Ondo DC 132 98 new DC 1
8 Benin Irrua SC 132 88 SC only exists. Add a second SC 2
9 Irrua Ukpilla SC 132 43 SC only exists. Add a second SC 2
10 Ukpilla Okene SC 132 33 SC only exists. Add a second SC 3
11 Shagamu Ijebu-Ode SC 132 41 SC only exists. Add a second SC 3
12 Dakata Gagarawa SC 132 89 SC only exists. Add a second SC 3
13 Gagarawa Hadejia SC 132 60 SC only exists. Add a second SC 3
14 Dakata Kumboso SC 132 30 SC only exists. Add a second SC 3
15 Obajana Okene DC 132 97 New DC 2
16 Kainji Iseyin DC 132 200 New DC 1
Source: JICA Study Team
Due to the thermal overloads encountered under normal (N-0) operation, it is necessary for a number of 132kV lines rated 125 MVA to be reconductored with ZTACIR conductors or ACCC Oriole CTC Global conductors, already used by TCN.
7-75
The following lines shall be reconductored, as per Table 7-5.15.
The table shows the new ratings after reconductoring:
Table 7-5.15 132 kV lines to be reconductored
From Bus Bus name To bus Bus name Id Rating
(MVA)
Length
(km)
12002 EGBIN 1 12025 IKORODU 1 225 20
12002 EGBIN 1 12025 IKORODU 2 225 20
12046 OGIJO 1 22027 SHAGAMU 1 1 188 16
12046 OGIJO 1 22027 SHAGAMU 1 2 188 16
22000 AYEDE 1 22006 IBADAN NORTH 1 188 12
22000 AYEDE 1 22006 IBADAN NORTH 2 188 12
22000 AYEDE 1 22012 JERICHO 1 2 188 6
82001 ALAOJI 1 82026 ABA 1 1 188 10
82001 ALAOJI 1 82026 ABA 1 2 188 10
82005 EKET 1 82024 IBOM IPP 1 1 188 45
82005 EKET 1 82024 IBOM IPP 1 2 188 45
82007 PHCT MAIN1 82009 PHCT TOWN2 1 1 188 6
82007 PHCT MAIN1 82036 RUMUSOI 1 1 188 10
82007 PHCT MAIN1 82036 RUMUSOI 1 2 188 10
82019 OMOKU 1 82036 RUMUSOI 1 1 225 20
82019 OMOKU 1 82036 RUMUSOI 1 2 225 20
Source: JICA Study Team
7-6 Examination of the Need for a Supergrid
7-6-1 Requirement for Supergrid (330, 500 or 750 kV)
The load-flow simulations with generation and load, as detailed in the previous Section, showed that without a major upgrade of the transmission system, widespread undervoltages and overloads will proliferate throughout the system and at all voltage levels, leading to high system losses. It is therefore considered necessary and appropriate at this stage to roll out the new “supergrid” in full, i.e. a backbone for bulk transmission at 330, 500 or 750 kV. In addition to the supergrid transmission lines, other 330 kV transmission lines have also been considered and assessed, as per TCN’s request, such as:
Yola-Little Gombi-Biu-Damaturu Damaturu-Potiskum-Azare-Dutse-Jogana Osogbo-Okene-Ajeokuta-Ayangba-Makurdi Mambila-Kashimbila-Ogoja-Ibom-Calabar Ugheli (Delta)-Onne (PH) Ugheli-Okpai
The following lines, requested to be assessed by TCN, were already introduced in 2025:
Zunkeru-Kainji Zunkeru-Shiroro
With regards to the conductor necessary for each supergrid option, the following arrangements are
7-76
recommended:
At 330 kV a Double-Circuit is proposed with 4-bundle (Quad) Bison conductors for each circuit. At 500 kV a Single-Circuit is proposed with 4-bundle (Quad) Bison conductors. At 750 kV a Single-Circuit is proposed with 5-bundle Bison conductors, which is typical at this
voltage level due to corona phenomenon.
The main electrical characteristics are summarized in Table 7-6.1.
Table 7-6.1 Conductor parameters for the proposed supergrid
Voltage Level
No of
Conductors of bundle
R (omhs/km)
L (mH/km)
X (Ω/km)
C (μF/km)
C (nF/km)
Thermal Rating (MVA)
Zs (ohms)
SIL (MW)
330 kV DC 4 0.019 0.7962 0.25 0.014 14 2x1,550 238.5 456
500 kV SC 4 0.019 0.8908 0.2797 0.0127 12.7 2,350 264.8 944
750 kV SC 5 0.015 0.9201 0.2889 0.0123 12.3 4,400 273.5 2,057
Source: JICA Study Team
The proposed tower configurations for a typical SC 500 and/or 750 kV EHV grid are shown in Figure 7-6.1.
Source: JICA Study Team
Figure 7-6.1 Towers for 500 and 750 kV EHV Grids
7-77
7-6-1-1 Comparison of Load-flow Results Between the Two EHV Options
The comparison of load-flow results for 2030 between the two EHV options is summarized in Table 7-6.2. The system loading is taken between the peak and off-peak values.
Table 7-6.2 Load-flow results for 2030
Voltage
Level
(kV)
O/V and U/V of
330 kV and above
(outside 0.9-1.05)
O/L of 330 kV
above 80%
Losses
(MW) Remarks
330 None 7 circuits* 1,124 (4.69%) Lower losses than 500 kV (line losses are higher
but no transformer losses are involved)
500 None 12 circuits * 1,264 (5.25%) 206 MW (0.85%) higher losses compared to
the 750-kV option
750 None 6 circuits** 1,058 (4.42%) Slighter lower losses than the 330-kV option
Source: JICA Study Team
(1) 330 kV System
BUS# X-- NAME --X BASKV AREA BUS# X-- NAME --X BASKV AREA CKT LOADING RATING PERCENT
23001 OSOGBO 3 330.00* 2 23003 GANMO 3 330.00 2 1 626.5 777.3 80.6
23005 AKURE 3 330.00 2 43011 EYEAN_3 330.00* 4 3 641.0 777.3 82.5
43000 AJAOKUTA 3 330.00 4 43005 GEREGU 330.00* 4 1 647.7 777.3 83.3
43000 AJAOKUTA 3 330.00 4 43005 GEREGU 330.00* 4 2 647.7 777.3 83.3
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 1 648.7 777.3 83.5
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 2 648.7 777.3 83.5
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 3 648.7 777.3 83.5
(2) 500 kV System
BUS# X-- NAME --X BASKV AREA BUS# X-- NAME --X BASKV AREA CKT LOADING RATING PERCENT
13000 AJA 3 330.00* 1 13034 LEKKI 330 330.00 1 1 637.0 777.0 82.0
13000 AJA 3 330.00* 1 13034 LEKKI 330 330.00 1 2 637.0 777.0 82.0
13028 ARIGBAJO 330.00* 1 23000 AYEDE 3 330.00 2 1 689.7 777.3 88.7
23001 OSOGBO 3 330.00* 2 23003 GANMO 3 330.00 2 1 651.0 777.3 83.7
23005 AKURE 3 330.00 2 43011 EYEAN_3 330.00* 4 3 760.6 777.3 97.9
43000 AJAOKUTA 3 330.00 4 43005 GEREGU 330.00* 4 1 648.6 777.3 83.4
43000 AJAOKUTA 3 330.00 4 43005 GEREGU 330.00* 4 2 648.6 777.3 83.4
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 1 651.2 777.3 83.8
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 2 651.2 777.3 83.8
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 3 651.2 777.3 83.8
43008 LOKOJA _3 330.00 4 43012 ZUMA 330.00* 4 1 662.9 777.3 85.3
43008 LOKOJA _3 330.00 4 43012 ZUMA 330.00* 4 2 662.9 777.3 85.3
(3) 750 kV System
BUS# X-- NAME --X BASKV AREA BUS# X-- NAME --X BASKV AREA CKT LOADING RATING PERCENT
23005 AKURE 3 330.00 2 43011 EYEAN_3 330.00* 4 3 648.8 777.3 83.5
43000 AJAOKUTA 3 330.00* 4 43005 GEREGU 330.00 4 1 662.1 777.3 85.2
43000 AJAOKUTA 3 330.00* 4 43005 GEREGU 330.00 4 2 662.1 777.3 85.2
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 1 631.4 777.3 81.2
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 2 631.4 777.3 81.2
43002 BENIN 3 330.00 4 43004 SAPELE 3 330.00* 4 3 631.4 777.3 81.2
7-78
7-6-1-2 Conclusion on Supergrid/EHV Options
The load-flow simulations have shown that without a major upgrade of the transmission system, widespread undervoltages and overloads will proliferate system-wide and at all voltage levels, meaning high system losses.
It is therefore considered necessary and appropriate at this stage to introduce the full new “supergrid”, i.e. a backbone for bulk transmission at either 330, 500 or 750 kV. It was found necessary to introduce part of this supergrid.
A number of configurations have been examined and compared in terms of efficacy in voltage support, system losses and easing the line loadings of the existing and planned 330 kV systems.
The optimum configuration of a 330, 500 or 750 kV EHV grid is shown in Figure 7-6.2.
Table 7-6.3 Evaluation of 330, 500 or 750 kV supergrid
Voltage level Voltage support
System loss Stability Cost Comprehensive
evaluation
330 kV A A A B 1
500 kV B A B A 2
750 kV B A B C 3
Source: JICA Study Team
Figure 7-6.2 Supergrid Configuration
8 PT HARCO EDC
7 ENUGU EDC
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETW ORK
G
G
G
G
G
G
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
G
G
G
DISCOS
4 TO 3 -42 MW
G
G
Diagram created using'D:\NIGERIA - YEC\PSSE Yachiyo MP\2030\Master 2030-330kV SG Yach reinf.sav'
'D:\NIGERIA - YEC\PSSE Yachiyo MP\Dwgs SLDs- Power Exch\Power Exchanges 330kV model Yach SGRD only 2020-2040.sld'
GG
GG
5 TO 10 -567 MW
G
G
G
TCN 2030 MODELDISCO DEMANDSUN, AUG 12 2018 14:04
FUNTUA
GWANGWALADA
KAINJI
B.KEBBI
MAKURDI
AJAOKUTA
BENIN
EGBIN
OSOGBO
IKOT EGBENEExport 1828 MW
Total Generation 28580 MWNigeria Load 25350 MW
Generation from HPP 3240 MW
Generation per DISCO Loads per DISCO
3-Abuja 5399 MW
4-Benin 5834 MW
9-Eko 1350 MW
7-Enugu 1051 MW
2-Ibadan 1415 MW
1-Ikeja 3035 MW
6-Jos 105 MW
5-Kaduna 212 MW
10-Kano 649 MW
8-Pt Harco 8029 MW
11-Yola 1501 MW
Generation from PV 640 MW
Total Load 27178 MW
9-Eko 2240 MW
7-Enugu 1981 MW
2-Ibadan 3246 MW
6-Jos 1035 MW
5-Kaduna 2114 MW
10-Kano 2544 MW
8-Pt Harco 2375 MW
11-Yola 942 MW
1-Ikeja 2920 MW
3-Abuja 3493 MW
4-Benin 2460 MW
7-79
The supergrid will encompass the following substations: Ikot-Ekpene, Benin, Egbin, Ajegunle (New Agbara), Osogbo, Gwangwalada, Makurdi, Ajeokuta, Funtua, Kainji, Bernin Kebbi.
From technical perspectives, both the 330 and 500 kV options are adequate. Furthermore, taking into consideration that:
Capacity of 330 kV supergrid lines: 3,100 MVA Capacity of 500 kV supergrid lines: 2,350 MVA Difference in losses between 330 and 500 kV supergrids: Marginal Impact on O/U voltages and overloads: 330 kV advantageous Higher static N-1 security of the 330 kV supergrid due to the Double-Circuit lines involved
It appears that the 330 kV supergrid system is technically the preferred option.
There is no justification to adopt and/or consider further any higher (750 kV) option for the EHV grid, particularly when the implications in cost differences are taken into account.
The higher transmission capacity (4,400 MVA) is not required at this stage and the marginal differences in losses cannot offset the high investment cost required in the planning horizon of this Master Plan.
7-6-1-3 Supergrid Transmission Lines
The following table summarizes the Double-Circuit 330kV transmission lines required to complete the supergrid for the 2030 system requirements. Part of this supergrid transmission system is required by 2025, as mentioned in the previous sections:
Table 7-6.4 Supergrid lines for 2030
From To Thermal rating (MVA) Length (km) Remarks
Ikot-Ekpene Benin 2 x 1,550 300
Ikot-Ekpene Makurdi 2 x 1,550 320 Required in 2025
Benin Egbin 2 x 1,550 230
Egbin Ajegunle (New Agbara) 2 x 1,550 50
Benin Osogbo 2 x 1,550 200
Ajegunle (New Agbara) Osogbo 2 x 1,550 150
Osogbo Kainji 2 x 1,550 200
Benin Ajeokuta 2 x 1,550 150
Ajeokuta Gwangwalada 2 x 1,550 150 Required in 2025
Gwangwalada Makurdi 2 x 1,550 180 Required in 2025
Gwangwalada Kainji 2 x 1,550 250
Gwangwalada Funtua 2 x 1,550 260 Required in 2025
Gwangwalada Osogbo 2 x 1,550 250 Required in 2025
Kainji Bernin Kebbi 2 x 1,550 300
Source: JICA Study Team (*) Note on the introduction of the “supergrid” in 2025:
The supergrid is to be fully rolled out in 2030 and its necessity is demonstrated in Section 7-6. However, due to the forecast high increase in load demand in the Abuja region and elsewhere by 2025 plus resulting overloads and undervoltages, the most cost-effective approach will involve introducing part of the supergrid in 2025, to avoid other temporary and potentially costly measures which will not be needed after the full roll-out of the supergrid in 2030. A full analysis of the supergrid and justifications for the selection of the appropriate voltage level and conductor type option is given in Section 7-6.
7-80
In addition to the supergrid transmission lines, other 330 kV transmission lines have also been considered and assessed, as per TCN’s request, such as:
Yola-Little Gombi-Biu-Damaturu Damaturu-Potiskum-Azare-Dutse-Jogana Osogbo-Okene-Ajeokuta-Ayangba-Makurdi Mambila-Kashimbila-Ogoja-Ibom-Calabar Ugheli (Delta)-Onne (PH) Ugheli-Okpai
However, with the introduction of the supergrid, these lines will be lightly loaded. Furthermore, during off-peak loading periods their charging MVar will necessitate the operation of reactors, particularly in the north-eastern area of Nigeria. Accordingly, before a final decision is made, it is recommended that their benefits be reassessed at a later stage, once more updated information is available on load demand in the corresponding regions.
7-81
7-7 Expansion Plan for 2030
7-7-1 2030 Base Cases Load-flow Analysis
7-7-1-1 Load demand
The demand load in 2030 in each DisCo area is shown in Table 7-7.1.
Table 7-7.1 Load demand per DisCo
DisCo Load Demand 2025
(MW) Increase
(2025-2030) Load Demand 2030
(MW)
IKEDC 1-Ikeja 2,058 42% 2,921
IBEDC 2-Ibadan 2,285 43% 3,267
AEDC 3-Abuja 2,329 50% 3,500
BEDC 4-Benin 1,852 34% 2,489
KAEDCO 5-Kaduna 1,169 81% 2,117
JEDC 6-Jos 646 60% 1,035
EEDC 7-Enugu 1,668 19% 1,979
PHEDC 8-Port Harcourt 1,762 35% 2,385
EKEDC 9-Eko 1,837 22% 2,240
KEDCO 10-Kano 1,565 64% 2,570
YOLA 11-Yola 532 77% 942
Total - 17,703 43.75% 25,447
Export* - 1,541 - 1,831
Total load - 19,244 - 27,278
Source: JICA Study Team Ref: 330 kV export lines: To Sakete 550 MW, To Faraku 500 MW, To Zabori 631 MW
The total generation assumed to be running in each DisCo area is shown in Table 7-7.2 and Figure 7-7.1. It includes 640 MW from PV and 3,240 MW from HPP.
Table 7-7.2 Generation per DisCo running in 2030
DisCo Generation (MW)
IKEDC 1-Ikeja 3,041
IBEDC 2-Ibadan 1,415
AEDC 3-Abuja 5,399
BEDC 4-Benin 5,834
KAEDCO 5-Kaduna 212
JEDC 6-Jos 105
EEDC 7-Enugu 1,051
PHEDC 8-Port Harcourt 8,029
EKEDC 9-Eko 1,350
KEDCO 10-Kano 649
YOLA 11-Yola 1,501
Source: JICA Study Team
The load and total running generation for each DisCo is shown graphically in Figure 7-7.1.
7-82
Source: JICA Study Team
Figure 7-7.1 2030 Generation and Loads Per DisCo
Analytically, the generation assumed running is listed in Table 7-7.3. The new generation added, or increase in power plant output, in comparison to the 2025 case, is shown in bold.
Table 7-7.3 Generation running in 2030
Bus Number
Bus Name PGen
(MW) Bus
Number Bus Name
PGen (MW)
Bus Number
Bus Name PGen
(MW)
86012 AFAM VI GT11 150 86069 GBARAIN_GTB2 102 46026 NIPP2 ST 257
86013 AFAM VI GT12 150 86055 GEN_AMADI 45 96007 OATS 270
86014 AFAM VI GT13 105 56010 GEN_KADUNA 194 96021 ODUGPANI NIP 508
86015 AFAM VI ST10 180 46023 GER NIPPGT21 140 96020 ODUGPANI NIP 229
86003 AFAM2 GT5-6 48 46024 GER NIPPGT22 140 76000 OKPAI GT11 149
86004 AFAM2GT 7-8 48 96015 GEREGU 2 266 76001 OKPAI GT12 148
86005 AFAM3 GT9-10 54 96014 GEREGU 2 248 76020 OKPAI GT4PH2 135
86006 AFAM3GT11-12 54 46020 GEREGU GT11 124 76021 OKPAI GT5PH2 135
86080 AKWA-IBOM NU 1800 56003 GURARA GBUS 18 76002 OKPAI ST18 126
86039 ALAOJI_GTB1 112.5 96002 HUDSON 135 76022 OKPAI STPH2 135
86040 ALAOJI_GTB2 112.5 86025 IBOM GT1 32 16064 OLOR NIPPST1 100
86041 ALAOJI_GTB3 112.5 86026 IBOM GT2 32 16065 OLOR NIPPST2 100
86042 ALAOJI_GTB4 112.5 86027 IBOM GT3 32 16060 OLORNIPPGT11 100
86043 ALAOJI2_STB1 257 86028 IBOM II 497 16061 OLORNIPPGT12 100
86031 ALSCON GT1 90 96013 IHOVBOR 2 229 16062 OLORNIPPGT21 100
86032 ALSCON GT2 117 46031 IHOVBOR_GTB1 110 16063 OLORNIPPGT22 100
46027 ASCO G1 50 46032 IHOVBOR_GTB2 110 16050 OLORUNSO GT1 30
46028 ASCO G2 50 46033 IHOVBOR_GTB3 110 16055 OLORUNSO GT6 15
96011 AZIKEL 440 46034 IHOVBOR_GTB4 110 16057 OLORUNSO GT8 30
46035 AZURA GT 280 66033 JBS WIND 70 86047 OMA_GT 450
96001 BRESSON 135 36006 JEBBA 2G1 80 86022 OMOKU2 GT2 102
16008 BRESSON GTS 80 36007 JEBBA 2G2 80 26026 OMOTNIPP GT1 115
96009 CABLE INLAND 1350 36008 JEBBA 2G3 80 26027 OMOTNIPP GT2 115
7-83
Bus Number
Bus Name PGen
(MW) Bus
Number Bus Name
PGen (MW)
Bus Number
Bus Name PGen
(MW)
86061 CALABAR_GTB2 100 36009 JEBBA 2G4 80 26030 OMOTOSHO 2+ 230
86060 CALABAR_GTB3 100 36011 JEBBA 2G6 80 26020 OMOTOSO GT1 74
76011 CENTURY IPP 223 36004 KAINJ 1G11 80 96008 ONDO IPP 400
96006 CHEVRON TEX 702 36005 KAINJ 1G12 80 16012 PARAS 270
86030 CUMMINS 135 36000 KAINJ 1G5 80 16011 PARASGT1-9 54
46006 DELTA IV 2-1 140 36001 KAINJ 1G6 80 46070 PROTON 135
46007 DELTA IV 2-2 140 36002 KAINJ 1G7-8 160 86070 QUA IBOE PP 468
46008 DELTA IV 2-3 140 36003 KAINJ 1G9-10 160 86035 RIVERS _GT1 172
46010 DELTAIV GT19 133 76013 KASHIMB HPP 21 46050 SAP_NIPP_GT1 100
46011 DELTAIV GT20 133 56011 KAZAURE PV1 80 46051 SAP_NIPP_GT2 100
66005 DKOWA G1 14 56012 KAZAURE PV2 80 46052 SAP_NIPP_GT3 100
96018 EGBEMA II 114 56013 KAZAURE PV3 80 46012 SAPELE GT1-2 180
86067 EGBEMA_GTB3 100 56014 KAZAURE PV4 80 46013 SAPELE GT3-4 90
16000 EGBIN GT 1 254.1 56015 KAZAURE PV5 80 46060 SAPELE ROT 140
16001 EGBIN GT 2 254.1 56016 KAZAURE PV6 80 46061 SAPELE ROT 2 140
16002 EGBIN GT 3 254.1 56017 KAZAURE PV7 80 46062 SAPELE ROT 2 130
16003 EGBIN GT 4 254.1 56018 KAZAURE PV8 80 36012 SHIROR 411G1 120
16004 EGBIN ST 5 254.1 46080 KOJI NUCLEAR 1800 36013 SHIROR 411G2 120
16005 EGBIN ST 6 254.1 55075 KT WF 33 9 36014 SHIROR 411G3 120
86050 ELEME 68 16010 LAFARAGE 2 200 96016 TURBINE DR 300
86056 ESSAR GTS 150 66008 MAMBILA GT2 250 96004 WESCOM 225
86057 ESSAR ST 140 66009 MAMBILA GT3 250 96017 YELLOW STONE 324
96012 ETHIOPE 450 66010 MAMBILA GT4 250 46029 ZUMA 810
46037 ETHIOPE GTS 310 66011 MAMBILA GT5 250 86071 ZUMA (GAS) 337
46038 ETHIOPE ST 140 66014 MAMBILA GT8 250 36024 ZUNGE_G1 150
86048 GBARAIN 2 GT 511 66015 MAMBILA GT9 250 36025 ZUNGE_G2 150
86068 GBARAIN_GTB1 102 96005 MBH 270
Source: JICA Study Team
7-84
Source: JICA Study Team
Figure 7-7.2 Configuration of the 330-kV grid in 2030
7-7-2 Summary of the Load-flow Calculations for 2030
The ratings of the 330kV DC option are found adequate for meeting the Grid Code requirements. Using this option, the transmission system loading is shown in Figure 7-7.3.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1433 MW
8 TO 4 380 MW
3 TO 2 -514 MW
7 TO 4 1001 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETW ORK
G
G
G
G
G
G
6 TO 3 650 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 891 MW
G
G
G
DISCOS
2 TO 1 1502 MW
4 TO 3 -37 MW
G
G
Diagram created using'D:\NIGERIA - YEC\PSSE Yachiyo MP\2030\Master 2030-330kV SG Yach reinf.sav''D:\NIGERIA - YEC\PSSE Yachiyo MP\Dwgs SLDs- Power Exch\Power Exchanges 330kV model Yach SGRD 2020-2030.sld'
GG
3 TO 5 2610 MW
1 TO 9 -1 MW
GG
5 TO 6 -70 MW
10 TO 6 0 MW
5 TO 10 -569 MW
6 TO 11 -402 MW
G
4 TO 9 485 MW
4 TO 1 1331 MW
G
G
TCN 2030 MODELDISCO DEMANDSUN, JUL 22 2018 15:57
0.990
0.988
253
15
0.988
0.968
1.003
38
8
21
38
8
21
38
8
21
38
8
21
83004
IKOT-EKPENE_
73006UGWUAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.999
632
30
0.99919
0
46
19
0
46
0.96173003MAKURDI_3
0.957
1
0.956
35
36
1
0.983
456
85
456
85
456
85
456
85
1.00041
6
6 41
6
6
0.994
59
3
14
8
59
3
14
833007
GWAGW BB1
1.004
189
51 189
51
191
81
0.989
23005AKURE 3
0.910
0.997
609 69
65
155
23001
OSOGBO 3
0.959
379
14
379
14
104
139
0.947
677
31
0.988
238
99
238
99
39
32
5
2
3
23003GANMO 3
23002OMOTOSHO3
33002
BKEBBI 3 0.971
0.9911.001
199
97
199
97
256
88256
88
25
4
24
0.944
37
65
0.981
0.973
1
2
0.982
328
21 328
21
328
21
328
21
13003IKEJA W 3
13029OGIJO 3
0.976
233
9 233
9
362
50
362
50
13030MFM 3
0.967
50
133
0.979
393
4141
248
79
248
79
0.960
10
4
25
10
5
57
1 2
SW
13
5
63007
DAMATURU 3 0.947
23
0
20
63005
MAIDUGURI 3 0.918
10
3
59
2
0.978
34
28
34
28
150
100
150
100
150
100 150
100
433
174
263
8 263
8
13002EGBIN 3
0.969
0.977
628
107
0.983
104
139
104
139
722
162
722
162
0.991
275
37
275
37
0.996
370
58
370
58
480
62 480
62
241
14
241
14
13025
EPE 3
13000
AJA 3
13031
OKO_OBA_3
13034
LEKKI 330
13027
ALAGBON_3
13001
AKANGBA 3
586
94
74
85
1
33001KATAMPE 3
0.987
24
4
74
24
4
74
1.011
41
8
10
41
8
10
83007
ONNIE_3
0.997
16
2
69
16
2
69
50
1
58
50
1
58
1
83002
ALAOJI 3
1.002 0 66
0 66
10
9
34
20
2
820
2
8 10
9
34
1.006 3
92
8 39
2
8
0.995
74 84 7
4 84
1.006
26
612
26
612
83010IKOT ABASI_3
1.016 14
8
17
14
8
17
83000
AFAM IV 3
83005
OWERRI_3
0.967
12
7
77
16
6
30
16
6
30
0.959
46
6
22
46
6
22
41
4
72
41
4
72
73004ALIADE_3
63001JOS 3
0.957
10
5
14
10
5
14
73010ABAKALIKI_3
0.942
28
0
48
1
63002YOLA 3
0.978
53001
KANO 3
0.907
0
410
410.901
382
59
53005KANO_NEW330
0.938
383
53
53003ZARIA_330
53000KADUNA 3
53002
KATSINA 3
0.925
36
8
36
63
36
8 36
63
0.982
10
1
14 1
01
14
13032NEW_AGBARA_3
0.972
127
21
1550
50
23000AYEDE 3
1.01243000
AJAOKUTA 3
43002BENIN 3
0.995 46
0
16
43001
ALADJA 3
43003
DELTA IV 3
1.004
257
83
452
50
452
50
452
50
43004
SAPELE 3
43011B_NORTH_3
1.013
58
7
59
58
7
59
0.978
22
5
81
22
5
81
43009OBAJANA_3
1.009
34
5
71
34
5
71
83006
EGBEMA_3
83009
OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
29
8
23
2
1 2
33020SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
0.952
17
2
10
17
2
10
53004
FUNTUA 3
0.941
68
19
68
19
53007
TMAFARA3
0.947
53008
GUSAU 3
48
14 48
14
183
24 183
24
312
37312
37
33021
KAINJI 3
1.001102
48
33005KAINJI G .S.3
33003JEBBA T.S.3
231
20
232
38
628
107
25
4
24
25
4
24
35
31
28
0
48
23
0
20
22
10
3
59
0.989
170
522
01
57
33009ZUNGERU
33004JEBBA G.S.3
33022
APO_NEW 3
0.910
33023
LAFIA 3
0.935
36
2
90
373
72
670
48
670
48
166
47 166
47
63003
BAUCHI 3 0.956
42
12
18
5
33
63008
MAMBILA 3
1.013
0.997
35
1
22
35
1
22
1.000
43006
EFFURUN 3
253
15
73002OKPAI 3
0.991
0.990
42
3
36
42
3
36
73030IHIALA 3
23006IBADAN
1.000
13026
OKE_ARO_3
49
3
0
53012
DUTSE 3
1.000
53011
KAZAURE 3
0.935
1.000
4575
454
59
1
79
59
1
1
2
0.994
63009
WUKARI
53010
EN ARFICA PV
0.941
67
27
67
27
83001
ALAOJI NIPP3
73007
NNEWI 3
0
329
30
338
1
2
1
13004
SAKETE 3
2
10
2
30
0.997
0.997
13028ARIGBAJO
75 153153
63006JALINGO_3
47
6
79
4
33010
ZABORI
0.961
31
9 2
315
0
31
9 2
315
0631
0
212
25
21
3
9
19
8
212
25
213
9
13012PARAS
0.989
50
750
7
185
58
185
58
33011
FARAKU
0.995
252
16
250
0252
16
250
0
500
0
43012
ZUMA 1.006
62
5
28
62
5
28
10
19
98
10
19
98
53013
DAURA
0.935
83
52 83
52
231
76231
76
53016
JOGANA
0.916 105
81
10674
334
5
326
5
12
54
12
54
53020
MILLENIUM
0.955
98
14
98
18
45
294
5
33
63015
MAYOBELWA 0.94849
2
10
245
29 245
29
86
25
85
45
86
25 8
5
45
20
1
57 2
01
632
01
57
201
63
253
15
25
6
38
55
67
56
49
55
67
56
49
448
88
474
70
463
28
474
70
463
28
48
9
13
43007AZURA
49
1
51
481
2
2
10
2
30
43010ETHIOPE
SW
12
08
90001
1.0022008
109
90002
1563
119
370
32370
32
90003
0.982
85
5
10
7
90004
0.960 466
811
105811105
248
15
248
15
90005
0.962
520
85
63485
63485
90006
1.000
1158
580
131
126131
126
352 112
352 112
90007
1.012
17
65
24
2
11
10
2 11
10
2
84
5
16
5 8
45
16
5
90008
0.941
1087
25
558
93
558
93
43008LOKOJA _3
0.960
0.988
90009
1.001
419
130
39
1
12
23
91
12
2
184
67
184
67
1031
33006
SOKOTO 3
81 191
8118
4
0.967
306
15
306
15441
45441
45
23007ADO EKITI 3
0.836
43013OKENE 3
0.915
384
126
53021
AZARE 3
0.913
63016
GOMBI 3
0.862
63017
BIU 3
0.889
63018
POTISKUM 3
0.880
73031KASHIMBILLA3
1.006
73032AYANGBA 3 0.924
83011OGOJA 3
0.895
0
0
83012IKOM 3 0.9100 0
43005GEREGU
448
88
90010
_1
0.989
676
184
339
6
339
6 675
69 675
69
13005OLORUNSOGO3
433
174
23010SHAGAMU
0.978
131
58131
58
37
65
393
50
13
3
13035
IJORA 3
90011
0.971
70177
35
7
11
35
7
11
1.000
190
20
32021
NIAMEY 1
0.805
1
58
16
52010
GAZOUA 1
SW
49
1.000
SW
568
12003IKEJA W 1BB1
Export 1829 MW
Total Generation 28601 MWNigeria Load 25390 MW
Generation from HPP 3240 MW
Generation per DISCO Loads per DISCO
3-Abuja 5399 MW
4-Benin 5834 MW
9-Eko 1350 MW
7-Enugu 1051 MW
2-Ibadan 1415 MW
1-Ikeja 3056 MW
6-Jos 105 MW
5-Kaduna 212 MW
10-Kano 649 MW
8-Pt Harco 8029 MW
11-Yola 1501 MW
Generation from PV 640 MW
Total Load 27219 MW
9-Eko 2240 MW
7-Enugu 1984 MW
2-Ibadan 3256 MW
6-Jos 1035 MW
5-Kaduna 2116 MW
10-Kano 2547 MW
8-Pt Harco 2379 MW
11-Yola 940 MW
1-Ikeja 2921 MW
3-Abuja 3499 MW
4-Benin 2471 MW
250
35
250
35
250
35
250
35
0
0
0
0
250
35
250
35
0
0
1
44
1250
53R
1250
53R
250
53R
1250
53R
1250
53R
1250
53R
11
44R
36033
ABUJA TPP
7-85
Source: JICA Study Team
Figure 7-7.3 Transmission Line Loadings in 2030
No overloads or voltage violation encountered in the 330 and 132 kV systems.
One or two minor voltage violations at 132 kV (0.84 pu) will be corrected when the 132-kV network is reinforced to meet the N-1 criterion, as proposed earlier.
7-7-3 Reactive Power Compensation
In addition to the requirements described for the 2025 case, the following reactive power compensation would be required by 2030:
At 330 kV Gombe substation, 100 MVar Capacitors or SVC.
With regards to Bernin Kebbi, for the 2025 case, power compensation (150 MVar capacitors) will be required at Bernin Kebbi due to export requirements to WAPP. It should be noted however that in 2030 the proposed supergrid will be extended with a Kainji-Bernin Kebbi line. Once this implemented, there will be no further need for reactive power compensation at Bernin Kebbi.
Due to the sharp increase in forecast load in Abuja, the largest reactive power compensation is required at the Abuja area (Gwangwalada 330kV substation) of approx. 700 MVar. It is recommended that this,
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1433 MW
8 TO 4 380 MW
3 TO 2 -514 MW
7 TO 4 1001 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETW ORK
G
G
G
G
G
G
6 TO 3 650 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 891 MW
G
G
G
DISCOS
2 TO 1 1502 MW
4 TO 3 -37 MW
G
G
Diagram created using'D:\NIGERIA - YEC\PSSE Yachiyo MP\2030\Master 2030-330kV SG Yach reinf.sav''D:\NIGERIA - YEC\PSSE Yachiyo MP\Dwgs SLDs- Power Exch\Power Exchanges 330kV model Yach SGRD 2020-2030.sld'
GG
3 TO 5 2610 MW
1 TO 9 -1 MW
GG
5 TO 6 -70 MW
10 TO 6 0 MW
5 TO 10 -569 MW
6 TO 11 -402 MW
G
4 TO 9 485 MW
4 TO 1 1331 MW
G
G
TCN 2030 MODELDISCO DEMANDSUN, JUL 22 2018 15:57
0.990
0.988
253
15
0.988
0.968
1.003
38
8
21
38
8
21
38
8
21
38
8
21
83004
IKOT-EKPENE_
73006UGWUAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.999
632
30
0.99919
0
46
19
0
46
0.96173003MAKURDI_3
0.957
1
0.956
35
36
1
0.983
456
85
456
85
456
85
456
85
1.00041
6
6 41
6
6
0.994
59
3
14
8
59
3
14
8
33007GWAGW BB1
1.004
189
51 189
51
191
81
0.989
23005AKURE 3
0.910
0.997
609 69
65
155
23001
OSOGBO 3
0.959
379
14
379
14
104
139
0.947
677
31
0.988
238
99
238
99
39
32
5
2
3
23003GANMO 3
23002OMOTOSHO3
33002
BKEBBI 3 0.971
0.9911.001
199
97
199
97
256
88256
88
25
4
24
0.944
37
65
0.981
0.973
1
2
0.982
328
21 328
21
328
21
328
21
13003IKEJA W 3
13029OGIJO 3
0.976
233
9 233
9
362
50
362
50
13030MFM 3
0.967
50
133
0.979
393
4141
248
79
248
79
0.960
10
4
25
10
5
57
1 2
SW
13
5
63007
DAMATURU 3 0.947
23
0
20
63005
MAIDUGURI 3 0.918
10
3
59
2
0.978
34
28
34
28
150
100
150
100
150
100 150
100
433
174
263
8 263
8
13002EGBIN 3
0.969
0.977
628
107
0.983
104
139
104
139
722
162
722
162
0.991
275
37
275
37
0.996
370
58
370
58
480
62 480
62
241
14
241
14
13025
EPE 3
13000
AJA 3
13031
OKO_OBA_3
13034
LEKKI 330
13027
ALAGBON_3
13001
AKANGBA 3
586
94
74
85
1
33001KATAMPE 3
0.987
24
4
74
24
4
74
1.011
41
8
10
41
8
10
83007
ONNIE_3
0.997
16
2
69
16
2
69
50
1
58
50
1
58
1
83002
ALAOJI 3
1.002 0 66
0 66
10
9
34
20
2
820
2
8 10
9
34
1.006
39
2
8 39
2
8
0.995
74 84 7
4 84
1.006
26
612
26
612
83010IKOT ABASI_3
1.016 14
8
17
14
8
17
83000
AFAM IV 3
83005
OWERRI_3
0.967
12
7
77
16
6
30
16
6
30
0.959
46
6
22
46
6
22
41
4
72
41
4
72
73004ALIADE_3
63001JOS 3
0.957
10
5
14
10
5
14
73010ABAKALIKI_3
0.942
28
0
48
1
63002YOLA 3
0.978
53001
KANO 3
0.907
0
410
410.901
382
59
53005KANO_NEW330
0.938
383
53
53003ZARIA_330
53000KADUNA 3
53002
KATSINA 3
0.925
36
8
36
63
36
8 36
63
0.982
10
1
14 1
01
14
13032NEW_AGBARA_3
0.972
127
21
1550
50
23000AYEDE 3
1.01243000
AJAOKUTA 3
43002BENIN 3
0.995 46
0
16
43001
ALADJA 3
43003
DELTA IV 3
1.004
257
83
452
50
452
50
452
50
43004
SAPELE 3
43011B_NORTH_3
1.013
58
7
59
58
7
59
0.978
22
5
81
22
5
81
43009OBAJANA_3
1.009
34
5
71
34
5
71
83006
EGBEMA_3
83009
OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
29
8
23
2
1 2
33020SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
0.952
17
2
10
17
2
10
53004
FUNTUA 3
0.941
68
19
68
19
53007
TMAFARA3
0.947
53008
GUSAU 3
48
14 48
14
183
24 183
24
312
37312
37
33021
KAINJI 3
1.001102
48
33005KAINJI G .S.3
33003JEBBA T.S.3
231
20
232
38
628
107
25
4
24
25
4
24
35
31
28
0
48
23
0
20
22
10
3
59
0.989
170
52
20
1
57
33009ZUNGERU
33004JEBBA G .S.3
33022
APO_NEW 3
0.910
33023
LAFIA 3
0.935
36
2
90
373
72
67048
670
48
166
47 166
47
63003
BAUCHI 3 0.956
42
12
18
5
33
63008
MAMBILA 3
1.013
0.997
35
1
22
35
1
22
1.000
43006
EFFURUN 3
253
15
73002OKPAI 3
0.991
0.990
42
3
36
42
3
36
73030IHIALA 3
23006IBADAN
1.000
13026
OKE_ARO_3
49
3
0
53012
DUTSE 3
1.000
53011
KAZAURE 3
0.935
1.000
4575
454
59
1
79
59
1
1
2
0.994
63009
WUKARI
53010
EN ARFICA PV
0.941
67
27
67
27
83001
ALAOJI NIPP3
73007
NNEWI 3
0
329
30
338
1
2
1
13004
SAKETE 3
2
10
2
30
0.997
0.997
13028ARIGBAJO
75 153153
63006JALINGO_3
47
6
79
4
33010
ZABORI
0.961
31
9 2
315
0
31
9 2
315
0631
0
212
25
21
3
9
19
8
212
25
213
9
13012PARAS
0.989
50
750
7
185
58
185
58
33011
FARAKU
0.995
252
16
250
0252
16
250
0
500
0
43012
ZUMA 1.006
62
5
28
62
5
28
10
19
98
10
19
98
53013
DAURA
0.935
83
52 83
52
231
76231
76
53016
JOGANA
0.916
105
8110674
334
5
326
5
12
54
12
54
53020
MILLENIUM
0.955
98
14
98
18
45
29
45
33
63015
MAYOBELWA 0.94849
2
10
245
29 245
29
86
25
85
45
86
25
85
45
20
1
57 2
01
63
20
1
57
201
63
253
15
25
6
38
55
67
56
49
55
67
56
49
448
88
474
70
463
28
474
70
463
28
48
9
13
43007AZURA
49
1
51
481
2
2
10
2
30
43010ETHIOPE
SW
12
08
90001
1.0022008
109
90002
1563
119
370
32370
32
90003
0.982
85
5
10
7
90004
0.960 466
811
105811105
248
15
248
15
90005
0.962
520
85
63485
63485
90006
1.000
1158
580
131
126131
126
352 112
352 112
90007
1.012
17
65
24
2
11
10
2 11
10
2
84
5
16
5 8
45
16
5
90008
0.941
1087
25
558
93
558
93
43008LOKOJA _3
0.960
0.988
90009
1.001
419
130
39
1
12
23
91
12
2
184
67
184
67
1031
33006
SOKOTO 3
81 191
8118
4
0.967
306
15
306
15441
45441
45
23007ADO EKITI 3
0.836
43013OKENE 3
0.915
384
126
53021
AZARE 3
0.913
63016
GOMBI 3
0.862
63017
BIU 3
0.889
63018
POTISKUM 3
0.880
73031KASHIMBILLA3
1.006
73032AYANGBA 3 0.924
83011OGOJA 3
0.895
0
0
83012IKOM 3 0.9100 0
43005GEREGU
448
88
90010
_1
0.989
676
184
339
6
339
6 675
69 675
69
13005OLORUNSOGO3
433
174
23010SHAGAMU
0.978
131
58131
58
37
65
393
50
13
3
13035
IJORA 3
90011
0.971
70177
35
7
11
35
7
11
1.000
190
20
32021
NIAMEY 1
0.805
1
58
16
52010
GAZOUA 1
SW
49
1.000
SW
568
12003IKEJA W 1BB1
Export 1829 MW
Total Generation 28601 MWNigeria Load 25390 MW
Generation from HPP 3240 MW
Generation per DISCO Loads per DISCO
3-Abuja 5399 MW
4-Benin 5834 MW
9-Eko 1350 MW
7-Enugu 1051 MW
2-Ibadan 1415 MW
1-Ikeja 3056 MW
6-Jos 105 MW
5-Kaduna 212 MW
10-Kano 649 MW
8-Pt Harco 8029 MW
11-Yola 1501 MW
Generation from PV 640 MW
Total Load 27219 MW
9-Eko 2240 MW
7-Enugu 1984 MW
2-Ibadan 3256 MW
6-Jos 1035 MW
5-Kaduna 2116 MW
10-Kano 2547 MW
8-Pt Harco 2379 MW
11-Yola 940 MW
1-Ikeja 2921 MW
3-Abuja 3499 MW
4-Benin 2471 MW
250
35
250
35
250
35
250
35
0
0
0
0
250
35
250
35
0
0
1
44
1250
53R
1250
53R
250
53R
1250
53R
1250
53R
1250
53R
11
44R
36033
ABUJA TPP
375
250
125
500
0
MV
A F
low
TCN330kV TRANSMISSINO NETWORK
TCN2030MODEL
Total Generation: 28601 MW
Nigeria Load: 25390 MW
Export: 1829 MW
Total Load: 27219 MW
Generation from PV: 640 MW
Generarion from HPP: 3240 MW
7-86
too, be the subject of a separated and dedicated reactive power compensation study, to determine the optimum locations and sizes required. Such a study shall be conducted at a later stage, when the current information on generation expansion plans and load forecast is updated.
However, if the Gwangwalada Power Plant of 1,000MW is in operation in 2030, instead of later, there will be no need for reactive power compensation in that area.
20 MVar capacitor at Gashuwa 132 kV
60 MVar capacitor at Apo 132 kV
25 MVar capacitor at Keffi 132 kV
40 MVar capacitor at Uba 132kV
7-87
7-8 Expansion Plan for 2035
7-8-1 2035 Base Cases Load-flow Analysis
7-8-1-1 Transmission system
Figure 7-8.1 below shows the 330kV transmission system in 2035.
Source: JICA Study Team
Figure 7-8.1 Configuration of 330 kV grid in 2035
Table 7-8.1 shows that the increase in load demand in 2035.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1405 M W
8 TO 4 585 M W
3 TO 2 -159 M W
7 TO 4 1710 M W
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 1042 M W
7 TO 6 1626 M W
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 911 M W
G
G
G
DISCOS
2 TO 1 1914 M W
4 TO 3 -207 M W
G
G
Diagram c reated us ing' D:\NIGERIA - YEC\PSSE Yac hiy o M P\2035\M as ter 2035-330k V SG Yac h re in f1.s av '' D:\NIGERIA - YEC\PSSE Yac hiy o M P\Dwgs SLDs - Power Ex c h\Power Ex c hanges 330k V m odel Yac h SGRD 2020-2030.s ld '
GG
3 TO 5 2446 M W
1 TO 9 -136 M W
GG
5 TO 6 -440 M W
10 TO 6 0 M W
5 TO 10 -555 M W
6 TO 11 -717 M W
G
4 TO 9 708 M W
4 TO 1 1712 M W
G
G
TCN 2035 MODELDISCO DEMANDSAT, JUL 28 2018 18:59
0.998
0.975
424
12
0.986
0.991
1.013
38
7
2
38
7
2
38
7
2
38
7
2
83004IKOT- EKPENE_
73006
UGW UAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.992
778
43
0.995
29
2
39
29
2
39
1.01073003
MAKURDI_3
1.008
1
0.971
22
3
12
1
0.987
385
34
385
34
385
34
385
34
0.98044
7
60
44
7
60
0.985
48
3 82
48
3 82
33007GW AGW BB1
0.993
349
93 349
93
355
86
0.973
23005
AKURE 3
0.869
0.985
682 88
168
189
23001OSOGBO 3
0.930
406
13
406
13
62
164
0.910
676
86
0.969
176
112
176
112
19
3
36
3
2
3
23003
GANMO 3
23002
OMOTOSHO3
33002
BKEBBI 3 1.000
0.9720.983
199
102
199
102
208
88208
88
29
2
39
0.913
111
48
0.958
0.955
1
2
0.964
419
12 419
12
419
12
419
12
13003
IKEJA W 3
13029OGIJO 3
0.956
240
7 240
7
423
57
423
57
13030MFM 3
0.949
13
126
0.962
464
5050
241
104
241
104
0.990
22
0
25
22
4
35
1 2
SW
38
0
63007
DAMATURU 3 0.951
34
2
30
63005
MAIDUGURI 3 0.903
15
9
65
2
0.955
51
5
51
5
150
99
150
99
150
99 150
99
402
219
269
40 269
40
13002EGBIN 3
0.952
0.961
684
121
0.967
103
137 10
3
137
792
187
792
187
0.978
304
48
304
48
0.984
413
79
413
79
532
82 532
82
350
6
350
6
13025
EPE 3
13000
AJA 3
13031OKO_OBA_3
13034LEKKI 330
13027ALAGBON_3
13001
AKANGBA 3
604
75
83
117
1
33001
KATAMPE 3
0.965
27
1
83
27
1
83
1.012
53
2 12
53
2 12
83007ONNIE_3
1.000
13
0
11
61
30
11
6
62
8
10
3 6
28
10
3
1
83002
ALAOJI 3
1.003
56
51
56
51
70
70
31
7
27
31
7
27
70
70
1.013
35
2
46
35
2
46
0.999
115 1
01
11
5 10
1
1.010
22
933
22
933
83010
IKOT ABASI_3
1.018 16
3
20
16
3
20
83000
AFAM IV 3
83005
OW ERRI_3
0.989
30
50
25
6
46
25
6
46
1.005
36
6
82
36
6
82
31
7 75
31
7 75
73004ALIADE_3
63001
JOS 3
0.981
10
6
11
10
6
11
73010
ABAKALIKI_3
0.932
29
6
10
8
1
63002YOLA 3
0.976
53001KANO 3
0.905
0
410
410.896
628
72
53005
KANO_NEW 330
0.926
682
187
53003ZARIA_330
53000
KADUNA 3
53002
KATSINA 3
0.948
43
54
43
107
43
54 43
107
0.962
16
3
31 1
63
31
13032
NEW _AGBARA_3
0.943
96
33
1550
181
23000
AYEDE 3
1.010
43000AJAOKUTA 3
43002
BENIN 3
0.983
70
7
6
43001
ALADJA 3
43003
DELTA IV 3
0.998
372
116
393
108
393
108
393
108
43004
SAPELE 3
43011B_NORTH_3
1.011
51
3
70
51
3
70
0.963
30
0
11
5
30
0
11
5
43009OBAJANA_3
1.010
23
9
53
23
9
53
83006EGBEMA_3
83009OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
47
6
33
2
1 2
33020
SHIRORO 3
33008W ESTMAIN_3
73000
NHAVEN 3
0.958
17
8
66
17
8
66
53004
FUNTUA 3
0.920
15
13
15
13
53007TMAFARA3
0.942
53008
GUSAU 3 105
44 105
44
182
19 182
19
390
83390
83
33021KAINJI 3
0.983115
48
33005
KAINJI G.S.3
33003JEBBA T.S.3
403
16
408
2
684
121
29
2
39
29
2
39
220
54
29
6
10
8
34
2
30
51
15
9
65
0.992
41
77
11
2
55
33009ZUNGERU
33004JEBBA G.S.3
33022APO_NEW 3
0.920
33023
LAFIA 3
0.981
48
1
13
9
499
73
558
7
558 7
290
88 290
88
63003BAUCHI 3 0.995
15
4
14
31
0
4
63008
MAMBILA 3
1.033
1.000
35
1
15
35
1
15
1.000
43006EFFURUN 3
424
12
73002OKPAI 3
1.006
1.002
60
0
28
60
0
28
73030
IHIALA 3
23006
IBADAN
1.000
13026OKE_ARO_3
56
5
37
53012
DUTSE 3
1.000
53011
KAZAURE 3
0.947
1.000
30 99
3030
75
5
13
4
75
5
1
2
1.008
63009W UKARI
53010
EN ARFICA PV
0.930
18
5
11
51
85
11
5
83001
ALAOJI NIPP3
73007
NNEW I 3
0
329
30
338
1
2
1
426
36 426
36
433
49
13004
SAKETE 3
42
26
42
65
0.985
0.986
13028ARIGBAJO
99 410410
63006JALINGO_3
57
7
13
4
30
33010ZABORI
0.952
38
0
13
6
375
123
38
0
13
6
375
123750
247
227
63
22
9
52
10
4 3
227
63
229
52
SW
78
1
13012PARAS
0.973
68
268
2
203
88
203
88
33011FARAKU
0.950
278
83
275
90278
83
275
90
550
181
43012ZUMA 1.000
51
6
875
16
87
10
44
15
8
10
44
15
8
53013DAURA
0.947
66
3 66
3
282
39282
39
53016JOGANA
0.91324
95
2487
396
4
385
43
4
110
4
110
53020
MILLENIUM
0.971
41
4
41
9
233
55
23
7
19
63015
MAYOBELW A 0.937
60
6
19
441
65 441
65
41
46
41 2
6
41
46
41 2
6
11
2
55 1
12
63
11
2
55
112
63
424
12
43
4
17
16
3 1
05
16
4
92
16
3
10
5
16
4
92
448
139
623
139
605
2
623
139
605
2
55
9
66
43007AZURA
59
7 88
582
7
42
26
42
65
43010
ETHIOPE
SW
23
90001
1.0132186
80
90002
1545
102
535
42535
42
90003
0.962
10
22
21
4
90004
0.931 574
884
169884
169
102
39
102
39
90005
1.010
45
226
558
4
558
4
90006
0.980
375
365
83
121 83
121
564
43
564
43
90007
1.010
17
01
29
6
11
2
12
2 11
2
12
2
71
9
72
71
9
72
90008
0.920
1264
77
65
3
13
0
65
31
30
43008
LOKOJA _3
0.942
0.975
90009
0.983
446
113
30
2
14
53
02
14
5
345
53
345
53
1487
33006SOKOTO 3
210 234
20
9
23
1
0.949
353
6
353
6494
58494
58
23007ADO EKITI 3
0.789
43013OKENE 3
0.901
668
200
53021AZARE 3
0.917
63016
GOMBI 3
0.866
63017
BIU 3
0.909
63018POTISKUM 3
0.904
73031
KASHIMBILLA3
1.016
73032
AYANGBA 3 0.949
83011OGOJA 3
0.923
0
0
83012IKOM 3 0.9360 0
43005
GEREGU
448
139
90010
_1
0.973
214
440
508
59
508
59 613
147 613
147
13005
OLORUNSOGO3
402
219
23010SHAGAMU
0.960
128
59128
59
111
48
464
13
12
6
13035
IJORA 3
90011
1.000
811
91
41
5 64
41
5
64
1.000
193
31
32021NIAMEY 1
0.840
1
59
19
52010GAZOUA 1
SW
56
1.000
SW
793
12003IKEJA W 1BB1
E xport 2002 MW
Total Generation 34313 MW
Nigeria Load 30597 MW
Ge n e ra tio n fro m HPP 4 2 3 9 M W
Generation per DISCO Loads per DISCO
3-Abuja 6789 MW
4-Benin 6465 MW
9-Eko 1350 MW
7-Enugu 1667 MW
2-Ibadan 1314 MW
1-Ikeja 2640 MW
6-Jos 1605 MW
5-Kaduna 712 MW
10-Kano 1029 MW
8-Pt Harco 9022 MW
11-Yola 2350 MW
Ge n e ra tio n fro m PV 8 4 0 M W
Total Load 32599 MW
9-Eko 2381 MW
7-Enugu 2042 MW
2-Ibadan 4019 MW
6-Jos 1079 MW
5-Kaduna 2531 MW
10-Kano 3528 MW
8-Pt Harco 2792 MW
11-Yola 1446 MW
1-Ikeja 3534 MW
3-Abuja 4393 MW
4-Benin 2853 MW
250
52
250
52
250
52
250
52
250
52
100
59
250
52
250
52
250
52
250
52
1250
70R
1250
70R
250
70R
1250
70R
250
70R
100
63R
1250
70R
1250
70R
250
70R
1250
70R
12
00
90
0H 96029
GW AGW ALAD
7-88
Table 7-8.1 Load demand per DisCo
DisCo Load Demand 2030
(MW) Increase
(2030-2035) Load Demand 2035
(MW)
IKEDC 1-Ikeja 2,921 21.06% 3,536
IBEDC 2-Ibadan 3,267 24.08% 4,054
AEDC 3-Abuja 3,500 25.66% 4,398
BEDC 4-Benin 2,489 16.54% 2,901
KAEDCO 5-Kaduna 2,117 19.61% 2,533
JEDC 6-Jos 1,035 4.24% 1,079
EEDC 7-Enugu 1,979 2.93% 2,037
PHEDC 8-Port Harcourt 2,385 17.49% 2,802
EKEDC 9-Eko 2,240 6.33% 2,382
KEDCO 10-Kano 2,570 38.06% 3,549
YOLA 11-Yola 942 53.72% 1,448
Total - 25,447 20.72% 30,719
Export* - 1,830 - 2,000
Total load - 27,277 - 32,719
Source: JICA Study Team Ref: 330 kV export lines: To Sakete 550 MW, To Faraku 550 MW, To Zabori 750 MW
7-8-1-2 Generation
The total generation assumed to be running in each DisCo area is shown in Table 7-8.2, as well as in Figure 7-8.1. It includes 840 MW from PV and 4,239 MW from HPP.
Table 7-8.2 Generation per DisCo running in 2035
DisCo Generation (MW)
IKEDC 1-Ikeja 2,640
IBEDC 2-Ibadan 1,314
AEDC 3-Abuja 6,789
BEDC 4-Benin 6,465
KAEDCO 5-Kaduna 712
JEDC 6-Jos 1,605
EEDC 7-Enugu 1,667
PHEDC 8-Port Harcourt 9,022
EKEDC 9-Eko 1,350
KEDCO 10-Kano 1,029
YOLA 11-Yola 2,350
Source: JICA Study Team
7-8-2 Summary of the Load-flow Calculations for 2035
The loading of the transmission system is shown in Figure 7-8.2.
7-89
Source: JICA Study Team
Figure 7-8.2 Transmission Line Loadings in 2035
7-8-2-1 Transmission Line Overloads and Voltage Violations
No overloads or voltage violations encountered in the 330 and 132 kV systems.
Two or three minor voltage violations at 132 kV (0.84 pu) will be corrected when the 132-kV network is reinforced to meet the N-1 criterion, as proposed earlier.
7-8-3 New Transmission Lines and Reactive Power Requirements
7-8-3-1 New transmission lines
The 330 kV DC line Zuma-Lokoja (25 km) is overloaded due to the Zuma power plant output. Reconductoring is recommended to Quad conductors.
The 330 kV DC line Makurdi-Lafia is overloaded due to the new Ramos 900 MW coal-fired power plant.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1405 M W
8 TO 4 585 M W
3 TO 2 -159 M W
7 TO 4 1710 M W
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 1042 M W
7 TO 6 1626 M W
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 911 M W
G
G
G
DISCOS
2 TO 1 1914 M W
4 TO 3 -207 M W
G
G
Diagram c reated us ing' D:\NIGERIA - YEC\PSSE Yac hiy o M P\2035\M as ter 2035-330k V SG Yac h re in f1.s av '' D:\NIGERIA - YEC\PSSE Yac hiy o M P\Dwgs SLDs - Power Ex c h\Power Ex c hanges 330k V m odel Yac h SGRD 2020-2030.s ld '
GG
3 TO 5 2446 M W
1 TO 9 -136 M W
GG
5 TO 6 -440 M W
10 TO 6 0 M W
5 TO 10 -555 M W
6 TO 11 -717 M W
G
4 TO 9 708 M W
4 TO 1 1712 M W
G
G
TCN 2035 MODELDISCO DEMANDSAT, JUL 28 2018 18:59
0.998
0.975
424
12
0.986
0.991
1.013
38
7
2
38
7
2
38
7
2
38
7
2
83004IKOT- EKPENE_
73006
UGW UAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.992
778
43
0.995
29
2
39
29
2
39
1.01073003
MAKURDI_3
1.008
1
0.971
22
3
12
1
0.987
385
34
385
34
385
34
385
34
0.98044
7
60
44
7
60
0.985
48
3 82
48
3 82
33007GW AGW BB1
0.993
349
93 349
93
355
86
0.973
23005
AKURE 3
0.869
0.985
682 88
168
189
23001OSOGBO 3
0.930
406
13
406
13
62
164
0.910
676
86
0.969
176
112
176
112
19
3
36
3
2
3
23003
GANMO 3
23002
OMOTOSHO3
33002
BKEBBI 3 1.000
0.9720.983
199
102
199
102
208
88208
88
29
2
39
0.913
111
48
0.958
0.955
1
2
0.964
419
12 419
12
419
12
419
12
13003
IKEJA W 3
13029OGIJO 3
0.956
240
7 240
7
423
57
423
57
13030MFM 3
0.949
13
126
0.962
464
5050
241
104
241
104
0.990
22
0
25
22
4
35
1 2
SW
38
0
63007
DAMATURU 3 0.951
34
2
30
63005
MAIDUGURI 3 0.903
15
9
65
2
0.955
51
5
51
5
150
99
150
99
150
99 150
99
402
219
269
40 269
40
13002EGBIN 3
0.952
0.961
684
121
0.967
103
137 10
3
137
792
187
792
187
0.978
304
48
304
48
0.984
413
79
413
79
532
82 532
82
350
6
350
6
13025
EPE 3
13000
AJA 3
13031OKO_OBA_3
13034LEKKI 330
13027ALAGBON_3
13001
AKANGBA 3
604
75
83
117
1
33001
KATAMPE 3
0.965
27
1
83
27
1
83
1.012
53
2 12
53
2 12
83007ONNIE_3
1.000
13
0
11
61
30
11
6
62
8
10
3 6
28
10
3
1
83002
ALAOJI 3
1.003
56
51
56
51
70
70
31
7
27
31
7
27
70
70
1.013
35
2
46
35
2
46
0.999
115 101 1
15 1
01
1.010
22
933
22
933
83010
IKOT ABASI_3
1.018 16
3
20
16
3
20
83000
AFAM IV 3
83005
OW ERRI_3
0.989
30
50
25
6
46
25
6
46
1.005
36
6
82
36
6
82
31
7 75
31
7 75
73004ALIADE_3
63001
JOS 3
0.981
10
6
11
10
6
11
73010
ABAKALIKI_3
0.932
29
6
10
8
1
63002YOLA 3
0.976
53001KANO 3
0.905
0
410
410.896
628
72
53005
KANO_NEW 330
0.926
682
187
53003ZARIA_330
53000
KADUNA 3
53002
KATSINA 3
0.948
43
54
43
107
43
54 43
107
0.962
16
3
31 1
63
31
13032
NEW _AGBARA_3
0.943
96
33
1550
181
23000
AYEDE 3
1.010
43000AJAOKUTA 3
43002
BENIN 3
0.983
70
7
6
43001
ALADJA 3
43003
DELTA IV 3
0.998
372
116
393
108
393
108
393
108
43004
SAPELE 3
43011B_NORTH_3
1.011
51
3
70
51
3
70
0.963
30
0
11
5
30
0
11
5
43009OBAJANA_3
1.010
23
9
53
23
9
53
83006EGBEMA_3
83009OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
47
6
33
2
1 2
33020
SHIRORO 3
33008W ESTMAIN_3
73000
NHAVEN 3
0.958
17
8
66
17
8
66
53004
FUNTUA 3
0.920
15
13
15
13
53007TMAFARA3
0.942
53008
GUSAU 3 105
44 105
44
182
19 182
19
390
83390
83
33021KAINJI 3
0.983115
48
33005
KAINJI G.S.3
33003JEBBA T.S.3
403
16
408
2
684
121
29
2
39
29
2
39
220
54
29
6
10
8
34
2
30
51
15
9
65
0.992
41
77
11
2
55
33009ZUNGERU
33004JEBBA G.S.3
33022APO_NEW 3
0.920
33023
LAFIA 3
0.981
48
1
13
9
499
73
558
7
558 7
290
88 290
88
63003BAUCHI 3 0.995
15
4
14
31
0
4
63008
MAMBILA 3
1.033
1.000
35
1
15
35
1
15
1.000
43006EFFURUN 3
424
12
73002OKPAI 3
1.006
1.002
60
0
28
60
0
28
73030
IHIALA 3
23006
IBADAN
1.000
13026OKE_ARO_3
56
5
37
53012
DUTSE 3
1.000
53011
KAZAURE 3
0.947
1.000
30 99
3030
75
5
13
4
75
5
1
2
1.008
63009W UKARI
53010
EN ARFICA PV
0.930
18
5
11
51
85
11
5
83001
ALAOJI NIPP3
73007
NNEW I 3
0
329
30
338
1
2
1
426
36 426
36
433
49
13004
SAKETE 3
42
26
42
65
0.985
0.986
13028ARIGBAJO
99 410410
63006JALINGO_3
57
7
13
4
30
33010ZABORI
0.952
38
0
13
6
375
123
38
0
13
6
375
123750
247
227
63
22
9
52
10
4 3
227
63
229
52
SW
78
1
13012PARAS
0.973
68
268
2
203
88
203
88
33011FARAKU
0.950
278
83
275
90278
83
275
90
550
181
43012ZUMA 1.000
51
6
875
16
87
10
44
15
8
10
44
15
8
53013DAURA
0.947
66
3 66
3
282
39282
39
53016JOGANA
0.91324
95
2487
396
4
385
43
4
110
4
110
53020
MILLENIUM
0.971
41
4
41
9
233
55
23
7
19
63015
MAYOBELW A 0.937
60
6
19
441
65 441
65
41
46
41 2
6
41
46
41 2
6
11
2
55 1
12
631
12
55
112
63
424
12
43
4
17
16
3 1
05
16
4
92
16
3
10
5
16
4
92
448
139
623
139
605
2
623
139
605
2
55
9
66
43007AZURA
59
7 88
582
7
42
26
42
65
43010
ETHIOPE
SW
23
90001
1.0132186
80
90002
1545
102
535
42535
42
90003
0.962
10
22
21
4
90004
0.931 574
884
169884
169
102
39
102
39
90005
1.010
45
226
558
4
558
4
90006
0.980
375
365
83
121 83
121
564
43
564
43
90007
1.010
17
01
29
6
11
2
12
2 11
2
12
2
71
9
72
71
9
72
90008
0.920
1264
77
65
3
13
0
65
31
30
43008
LOKOJA _3
0.942
0.975
90009
0.983
446
113
30
2
14
53
02
14
5
345
53
345
53
1487
33006SOKOTO 3
210 234
20
9
23
1
0.949
353
6
353
6494
58494
58
23007ADO EKITI 3
0.789
43013OKENE 3
0.901
668
200
53021AZARE 3
0.917
63016
GOMBI 3
0.866
63017
BIU 3
0.909
63018POTISKUM 3
0.904
73031
KASHIMBILLA3
1.016
73032
AYANGBA 3 0.949
83011OGOJA 3
0.923
0
0
83012IKOM 3 0.9360 0
43005
GEREGU
448
139
90010
_1
0.973
214
440
508
59
508
59 613
147 613
147
13005
OLORUNSOGO3
402
219
23010SHAGAMU
0.960
128
59128
59
111
48
464
13 1
26
13035
IJORA 3
90011
1.000
811
91
41
5 64
41
5
64
1.000
193
31
32021NIAMEY 1
0.840
1
59
19
52010GAZOUA 1
SW
56
1.000
SW
793
12003IKEJA W 1BB1
E xport 2002 MW
Total Generation 34313 MW
Nigeria Load 30597 MW
Ge n e ra tio n fro m HPP 4 2 3 9 M W
Generation per DISCO Loads per DISCO
3-Abuja 6789 MW
4-Benin 6465 MW
9-Eko 1350 MW
7-Enugu 1667 MW
2-Ibadan 1314 MW
1-Ikeja 2640 MW
6-Jos 1605 MW
5-Kaduna 712 MW
10-Kano 1029 MW
8-Pt Harco 9022 MW
11-Yola 2350 MW
Ge n e ra tio n fro m PV 8 4 0 M W
Total Load 32599 MW
9-Eko 2381 MW
7-Enugu 2042 MW
2-Ibadan 4019 MW
6-Jos 1079 MW
5-Kaduna 2531 MW
10-Kano 3528 MW
8-Pt Harco 2792 MW
11-Yola 1446 MW
1-Ikeja 3534 MW
3-Abuja 4393 MW
4-Benin 2853 MW
250
52
250
52
250
52
250
52
250
52
100
59
250
52
250
52
250
52
250
52
1250
70R
1250
70R
250
70R
1250
70R
250
70R
100
63R
1250
70R
1250
70R
250
70R
1250
70R
12
00
90
0H 96029
GW AGW ALAD
375
250
125
500
0
MV
A F
lo
w
TCN330kV TRANSMISSINO NETWORK
TCN2035MODEL
Total Generation: 34313 MW
Nigeria Load: 30587 MW
Export: 2002 MW
Total Load: 32599 MW
Generation from PV: 840 MW
Generarion from HPP: 4239 MW
7-90
A new Wukari-Lafia 330 kV DC line (95 km) is proposed, which will remove these overloads and improve voltage profiles.
The following 330 kV lines are overloaded between 101 and 107% under normal (N-0) operation and need to be converted to Quad conductors
Aja - Lekki
Benin North - Akure
To meet the N-1 criterion and also remove undervoltages, a conversion to a DC circuit is recommended for the following SC 132 kV lines:
Kwaya Kusar - Biu
Biu - Damboa
Damboa - Maiduguri
To meet the N-1 criterion and also eliminate overload, new transmission lines are required, as listed in Table 7-8.3.
Table 7-8.3 New transmission lines and reinforcements required for 2035
Substation Name
Substation Name
Voltage (kV)
Length (km)
Type Proposed Solution
Wukari Lafia 330 95 DC New DC transmission line
Zuma Lokoja 330 25 DC Reconductoring of DC to Quad conductor
Aja Lekki 330 7 DC Reconductoring of DC to Quad conductor
Benin North Akure 330 130 SC Reconductoring to Quad conductor or
conversion to DC
Kwaya Kusar Biu 132 42 SC Convert from SC to DC
Biu Damboa 132 140 SC Convert from SC to DC
Damboa Maiduguri 132 64 SC Convert from SC to DC
Source: JICA Study Team
7-8-3-2 Reactive Power Compensation
In addition to the requirements described for the 2030 case, the following reactive power compensation would be required by 2035:
Due to the sharp increase in forecast load in Abuja, reactive power compensation is required at the Abuja area (Gwangwalada 330 kV substation).
However, if the Gwangwalada Power Plant of 1,200 MW is in operation in 2035, instead of later, there will be no need for reactive power compensation in that area.
250 MVar capacitors at Gombe 330 kV
700 MVar capacitors at Bernin Kebbi 330 kV
300 MVar capacitors at Ikeja West 132 kV
7-91
7-8-3-3 Comparison of Load-flow Results Between the EHV Options
The comparison of load-flow results for 2035 between the two EHV options is summarized in Table 7-8.4.
Table 7-8.4 LF results for 2035
Voltage Level (kV)
Generation (MW)
O/V and U/V of 330 kV and above (outside 0.9-1.05)
O/L of 330 kV above 80%
Losses (MW)
Remarks
330 28763 5 buses 16 circuits* 1,471 (5.11%) Slightly lower losses compared to the
500-kV option
500 28974 10 buses 20 circuits * 1,737 (5.99%) 266 MW (0.91%) higher losses
compared to the 330-kV option
750 28688 1 bus 12 circuits** 1,359 (4.73%) Slightly lower losses compared to the
330-kV option
Source: JICA Study Team
7-8-3-4 Conclusion on EHV Options for 2035
The conclusions are the same as for 2030 cases. Based on technical considerations both the 330 and 500 kV options are adequate. Furthermore, taking into consideration that:
Capacity of 330 kV supergrid lines: 3,100 MVA
Capacity of 500 kV supergrid lines: 2,350 MVA
Difference in losses between 330 and 500 kV supergrids: Marginal
Impact on O/U voltages and overloads: 330 kV advantageous
Higher static N-1 security of the 330 kV supergrid due to Double-Circuit lines involved
It appears that the 330 kV supergrid system is technically the preferred option.
There is no justification for adopting and/or further considering any higher (750 kV) option for the EHV grid, particularly when the implications in cost differences are taken into account. The higher transmission capacity (4,400 MVA) is not required at this stage and the marginal differences in losses cannot offset the high investment cost required in the planning horizon of this Master Plan.
7-92
7-9 Expansion Plan for 2040
7-9-1 2040 Base Cases Load-flow Analysis
7-9-1-1 Transmission system
Figure 7-9.1 below shows the 330kV transmission system in 2040.
Source: JICA Study Team
Figure 7-9.1 Configuration of 330 kV grid in 2040
7-9-1-2 Load demand
Table 7-9.1 shows that the increase in load demand follows approximately the same increase (in percentage) as in the load forecast detailed in Section 5.4.2.
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1267 MW
8 TO 4 700 MW
3 TO 2 -195 MW
7 TO 4 1985 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 1215 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 1045 MW
G
G
G
DISCOS
2 TO 1 1894 MW
4 TO 3 -213 MW
G
G
Diagram created using'D:\NIGERIA - YEC\PSSE Yachiyo MP\2040\Master 2040-330kV SG Yach reinf1.sav'
'D:\NIGERIA - YEC\PSSE Yachiyo MP\Dwgs SLDs- Power Exch\Power Exchanges 330kV model Yach SGRD 2020-2040.sld'
GG
3 TO 5 2804 MW
1 TO 9 -328 MW
G G
5 TO 6 -481 MW
10 TO 6 0 MW
5 TO 10 -652 MW
6 TO 11 -240 MW
G
4 TO 9 806 MW
4 TO 1 1881 MW
G
G
TCN 2035 MODELDISCO DEMANDSUN, JUL 29 2018 12:57
0.979
0.948
490
19
0.963
0.965
1.000
42
3
7
42
3
7
42
3
7
42
3
7
83004IKOT-EKPENE_
73006UGWUAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.976
839
28
0.98035
0
33
35
0
33
0.96373003MAKURDI_3
0.982
1
0.9652
45
18
1
0.971
448
2
448
2
448
2
448
2
0.98054
6
15
54
6
15
0.962
60
4
18
7
60
4
18
7
33007GWAGW BB1
0.979
341
126 341
126
347
115
0.967
23005AKURE 3
0.792
0.963
783 106
257
253
23001OSOGBO 3
0.871
469
23
469
23
51
202
0.834
873
188
0.915
229
112
229
112
26
3
43
9
2
3
23003GANMO 3
23002OMOTOSHO3
33002BKEBBI 3 0.980
0.9180.940
199
99
199
99
210
122210
122
32
3
85
0.864
60
28
0.931
0.938
1
2
0.944
460
10 460
10
460
10
460
10
13003IKEJA W 3
13029OGIJO 3
0.937
240
46 240
46
490
46490
4613030MFM 3
0.934
35
92
0.948
528
115115
336
133
336
133
0.980
28
0
18
28
8
45
1 2
SW
34
0
63007DAMATURU 3 0.960
28
5
8
63005MAIDUGURI 3 0.931
12
7
55
2
0.927
10
40
10
40
150
97
150
97 150
97 150
97
597
336
403
77 403
77
13002EGBIN 3
0.939
0.950
754
163
0.958
174
195 1
74
195
875
243
875
243
0.969
311
48
311
48
0.975
433
86
433
86
549
84 549
85
398
39
398
39
13025EPE 3
13000AJA 3
13031OKO_OBA_3
13034LEKKI 330
13027ALAGBON_3
13001AKANGBA 3
714
130
106 122
1
33001KATAMPE 3
0.960
33
4
12
63
34
12
6
1.012
55
6
22
55
6
22
83007ONNIE_3
0.988
13
7
10
01
37
10
0
79
9
83
79
9
83
1
83002ALAOJI 3
0.991 12
4
54
12
4
54
54
59
41
2
53
41
2
53
54
59
1.005
23
4
66
23
4
66
0.991
14 1
13
14 1
130.999
22
422
22
422
83010IKOT ABASI_3
1.016 18
8
13
18
8
13
83000AFAM IV 3
83005OWERRI_3
0.964
72
76
26
6
31
26
6
31
0.958
51
6
18
51
6
18
45
8
10
3 4
58
10
3
73004ALIADE_3
63001JOS 3
0.965
20
19
20
19
73010ABAKALIKI_3
0.897
14
7
96
1
63002YOLA 3
0.933
53001KANO 3
0.980
0
480
48
SW
605
0.966
734
167
53005KANO_NEW330
0.923
732
171
53003ZARIA_330
53000KADUNA 3
53002KATSINA 3
0.985
4
0
4
64
4
0 4
64
0.944
25
8
10
52
58
10
5
13032NEW_AGBARA_3
0.925
101
37
1550
181
23000AYEDE 3
0.99743000
AJAOKUTA 3
43002BENIN 3
0.960 83
2
29
43001ALADJA 3
43003DELTA IV 3
0.979
337
134
469
146
469
146
469
146
43004SAPELE 3
43011B_NORTH_3
0.998 64
6
14
3
64
6
14
3
0.933
36
5
15
7
36
5
15
7
43009OBAJANA_3
0.998
19
6
91
19
6
91
83006EGBEMA_3
83009OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
54
5
62
2
1 2
33020SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
0.932
21
8
80
21
8
80
53004FUNTUA 3
0.906
27
58
27
58
53007TMAFARA3
0.923
53008GUSAU 3
144
21 144
21
178
83 178
83
451
91451
91
33021KAINJI 3
0.939106
57
33005KAINJI G .S.3
33003JEBBA T.S.3
468
22
476
13
754
163
32
3
85
32
3
85
241
15
14
7
96
28
5
81
74
12
7
55
0.974
51
121
12
1
19
33009ZUNGERU
33004JEBBA G .S.3
33022APO_NEW 3
0.863
33023LAFIA 3
0.928
52
1
21
5
545
93
66318
66318
322
71 322
71
63003BAUCHI 3 0.972
22
0
29
36
6
13
63008MAMBILA 3
1.020
0.989
35
1
42
35
1
42
1.000
43006EFFURUN 3
490
19
73002OKPAI 3
0.994
0.988
75
0
29
75
0
29
73030IHIALA 3
23006IBADAN
1.000
13026OKE_ARO_3
61
8
21
53012DUTSE 3
0.974
53011KAZAURE 3
0.992
1.000
5 174
597
94
6
18
4
94
6
1
2
0.966
63009WUKARI
53010EN ARFICA PV
0.919
30
0
15
73
00
15
7
83001ALAOJI NIPP3
73007NNEWI 3
0
329
30
338
1
2
1
440
61
440
61
447
89
13004SAKETE 3
63
12
64
48
0.963
0.963
13028ARIGBAJO
174 260260
63006JALINGO_3
73
9
18
4
97
33010ZABORI
0.931
38
1
14
0
375
123
38
1
14
0
375
123750
247
225
62
22
65
2
10
8
22
225
62
226
52
SW
11
05
13012PARAS
0.960
115
69
115
69
249
176
249
176
33011FARAKU
0.904
278
89
275
90278
89
275
90
550
181
43012ZUMA 0.982
79
3
12
9
79
3
12
9
13
13
19
9
13
13
19
9
53013DAURA
0.992
64
40 64
40
329
98329
98
53016JOGANA
0.972101
74
100 83
414
112
401
162
70
70
70
7039
8
53020MILLENIUM
0.962
4
63
4
67
258
16
26
2
9
63015MAYOBELWA 0.8897
88
99
415
92 415
92
33
83
33
16
33
83
33
16 12
1
19 1
21
27
12
1
19
121
27
490
19
50
3
45
20
5 1
20
20
6
11
1
20
5 1
20
20
6
11
1
448
234
679
1
659
158
679
1
659
158
61
1
67
43007AZURA
77
4
13
2
745
79
63
12
64
48
43010ETHIOPE
SW
15
80
90001
0.9992622
407
90002
1749
339
614
94614
94
90003
0.944
12
04
35
0
90004
0.873 817
10323181032318
256
143
256
143
90005
0.963
39
209
696106
696106
90006
0.979
696
1374
60
197
60
197
650
8
650 8
90007
0.996
21
12
47
7
97
15
6 97
15
6
92
4
20
8 92
4
20
8
90008
0.906
1448
155
75
31
95
75
31
95
43008LOKOJA _3
0.923
0.948
90009
0.939
554
99
36
2
15
23
62
15
2
393
27
393
27
1892
33006SOKOTO 3
322 315
32
1
31
7
0.935
414
30
414
30562
98562
98
23007ADO EKITI 3
0.698
43013OKENE 3
0.869
1027
307
53021AZARE 3
0.972
79
1
79
1
63016GOMBI 3
0.909
381
73
381
73
63017BIU 3
0.928
17084
17084
281 111281 111
63018POTISKUM 3
0.967
146
22 146
22
18
6
57
18
6
57
73031KASHIMBILLA3
1.026
73032AYANGBA 3 0.925
83011OGOJA 3
1.027
0
0
83012IKOM 3 1.0160 0
43005GEREGU
448
234
90010_1
0.967
317
139
521
108
521
108 859
319
859
319
13005OLORUNSOGO3
597
336
23010SHAGAMU
0.939
134
67134
67
60
28
528
35
92
13035IJORA 3
90011
0.980
902 212
46
4
71
46
4 71
130
100
1.000
191
31
32021NIAMEY 1
0.868
1
59
2052010
GAZOUA 1
SW
58
1.000
SW
998
12003IKEJA W 1BB1
Export 2000 MW
Total Generation 39916 MWNigeria Load 35598 MW
Genera tion from H PP 4369 MW
Generation per DISCO Loads per DISCO
3-Abuja 7949 MW
4-Benin 7635 MW
9-Eko 1350 MW
7-Enugu 1904 MW
2-Ibadan 1575 MW
1-Ikeja 4125 MW
6-Jos 1745 MW
5-Kaduna 832 MW
10-Kano 1019 MW
8-Pt Harco 10842 MW
11-Yola 2470 MW
Genera tion from PV 990 MW
Total Load 37598 MW
9-Eko 2509 MW
7-Enugu 2114 MW
2-Ibadan 4923 MW
6-Jos 1131 MW
5-Kaduna 3043 MW
10-Kano 4021 MW
8-Pt Harco 3292 MW
11-Yola 1678 MW
1-Ikeja 4295 MW
3-Abuja 5316 MW
4-Benin 3275 MW
250
98
200
101
250
98
250
98
250
98
250
98
250
98
250
98
250
98
250
98
1250
117R
1200
114R
250
117R
1250
117R
250
117R
250
117R
1250
117R
1250
117R
250
117R
1250
117R
12
00
90
0H
96029GWAGWALAD
7-93
Table 7-9.1 Load demand per DisCo
DisCo Load Demand 2035
(MW) Increase
(2035-2040) Load Demand 2040
(MW)
IKEDC 1-Ikeja 3,536 21.61% 4,300
IBEDC 2-Ibadan 4,054 24.70% 5,055
AEDC 3-Abuja 4,398 21.31% 5,336
BEDC 4-Benin 2,901 16.90% 3,391
KAEDCO 5-Kaduna 2,533 20.23% 3,045
JEDC 6-Jos 1,079 4.83% 1,131
EEDC 7-Enugu 2,037 3.67% 2,112
PHEDC 8-Port Harcourt 2,802 17.94% 3,305
EKEDC 9-Eko 2,382 5.44% 2,512
KEDCO 10-Kano 3,549 13.38% 4,023
YOLA 11-Yola 1,448 16.05% 1,680
Total - 30,719 16.83% 35,890
Export - 2,000 - 2,000
Total load - 32,719 - 37,890
Source: JICA Study Team Ref: 330 kV export lines: To Sakete 550 MW, To Faraku 550 MW, To Zabori 750 MW
7-9-1-3 Generation
The total generation assumed to be running in each DisCo area is shown in Table 7-9.2 as well as in Figure 7-9.1 and includes 990 MW from PV and 4,369 MW from HPP.
Table 7-9.2 Generation per DisCo running in 2040
DisCo Generation (MW)
IKEDC 1-Ikeja 4,125
IBEDC 2-Ibadan 1,575
AEDC 3-Abuja 7,949
BEDC 4-Benin 7,635
KAEDCO 5-Kaduna 832
JEDC 6-Jos 1,745
EEDC 7-Enugu 1,904
PHEDC 8-Port Harcourt 10,842
EKEDC 9-Eko 1,350
KEDCO 10-Kano 1,019
YOLA 11-Yola 2,470
Source: JICA Study Team
It should be noted that to meet the high load forecast for 2040, an additional power plant is necessary with a minimum capacity of 1,000 MW (such as Ethiope ph 2) to be located near Egbin S/S.
7-9-2 Summary of Load-flow Calculations for 2040
The loading of the transmission system is shown in Figure 7-9.2.
7-94
Source: JICA Study Team
Figure 7-9.2 Transmission Line Loadings in 2040
7-9-2-1 Transmission Line Overloads and Voltage Violations
No voltage violation encountered in the 330 and 132 kV systems.
A few minor voltage violations at 132 kV will be corrected when the 132-kV network is reinforced to meet the N-1 criterion, as proposed earlier.
With regards to thermal overloads of the 330-kV system, the following lines are overloaded and need to be reinforced:
Aladja - Delta IV
Osogbo – Ganmo
7-9-3 New Transmission Lines and Reactive Power Requirements
7-9-3-1 New transmission lines
The following new 330 kV transmission lines are recommended at this stage in the North and North-East of the country:
8 PT HARCO EDC
7 ENUGU EDC
8 TO 7 1267 MW
8 TO 4 700 MW
3 TO 2 -195 MW
7 TO 4 1985 MW
G
G
G
G
G
G
TCN 330kV TRANSMISSION NETWORK
G
G
G
G
G
G
6 TO 3 1215 MW
7 TO 6 1626 MW
G
G
4 BENIN EDC
3 ABUJA EDC
9 EKO EDC
2 IBADAN EDC
5 KADUNA EDC
10 KANO EDC
6 JOS EDC
11 YOLA EDC
1 IKEJA EDC
4 TO 2 1045 MW
G
G
G
DISCOS
2 TO 1 1894 MW
4 TO 3 -213 MW
G
G
Diagram created using'D:\NIGERIA - YEC\PSSE Yachiyo MP\2040\Master 2040-330kV SG Yach reinf1.sav'
'D:\NIGERIA - YEC\PSSE Yachiyo MP\Dwgs SLDs- Power Exch\Power Exchanges 330kV model Yach SGRD 2020-2040.sld'
GG
3 TO 5 2804 MW
1 TO 9 -328 MW
G G
5 TO 6 -481 MW
10 TO 6 0 MW
5 TO 10 -652 MW
6 TO 11 -240 MW
G
4 TO 9 806 MW
4 TO 1 1881 MW
G
G
TCN 2035 MODELDISCO DEMANDSUN, JUL 29 2018 12:57
0.979
0.948
490
19
0.963
0.965
1.000
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73006UGWUAJI_3
73001ONITSHA 3
73005ASABA_3
0.999
0.976
839
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0
33
35
0
33
0.96373003MAKURDI_3
0.982
1
0.965
24
5
18
1
0.971
448
2
448
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448
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448
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0.98054
6
15
54
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0.962
60
4
18
7
60
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0.979
341
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126
347
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23005AKURE 3
0.792
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257
253
23001OSOGBO 3
0.871
469
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469
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51
202
0.834
873
188
0.915
229
112
229
112
26
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43
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23003GANMO 3
23002OMOTOSHO3
33002BKEBBI 3 0.980
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199
99
199
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122
32
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60
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13029OGIJO 3
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240
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490
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336
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97
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97 150
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597
336
403
77 403
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13002EGBIN 3
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754
163
0.958
174
195 174
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875
243
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0.969
311
48
311
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433
86
433
86
549
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398
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398
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13025EPE 3
13000AJA 3
13031OKO_OBA_3
13034LEKKI 330
13027ALAGBON_3
13001AKANGBA 3
714
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106 122
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422
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422
83010IKOT ABASI_3
1.016 18
8
13
18
8
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83000AFAM IV 3
83005OWERRI_3
0.964
72
76
26
6
31
26
6
31
0.958
51
6
18
51
6
18
45
8
10
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58
10
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73004ALIADE_3
63001JOS 3
0.965
20
19
20
19
73010ABAKALIKI_3
0.897
14
7
96
1
63002YOLA 3
0.933
53001KANO 3
0.980
0
480
48
SW
605
0.966
734
167
53005KANO_NEW330
0.923
732
171
53003ZARIA_330
53000KADUNA 3
53002KATSINA 3
0.985
4
0
4
64
4
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0.944
25
8
10
52
58
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13032NEW_AGBARA_3
0.925
101
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1550
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23000AYEDE 3
0.99743000
AJAOKUTA 3
43002BENIN 3
0.960 83
2
29
43001ALADJA 3
43003DELTA IV 3
0.979
337
134
469
146
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43004SAPELE 3
43011B_NORTH_3
0.998 64
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0.933
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36
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43009OBAJANA_3
0.998
19
6
91
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91
83006EGBEMA_3
83009OMOKU_3
83008CALABAR_PS_3
83003ADIAGBO_3
63000GOMBE 3
54
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33020SHIRORO 3
33008WESTMAIN_3
73000NHAVEN 3
0.932
21
8
80
21
8
80
53004FUNTUA 3
0.906
27
58
27
58
53007TMAFARA3
0.923
53008GUSAU 3
144
21 144
21
178
83 178
83
451
91451
91
33021KAINJI 3
0.939106
57
33005KAINJI G .S.3
33003JEBBA T.S.3
468
22
476
13
754
163
32
3
85
32
3
85
241
15
14
7
96
28
5
81
74
12
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55
0.974
51
121
12
1
19
33009ZUNGERU
33004JEBBA G .S.3
33022APO_NEW 3
0.863
33023LAFIA 3
0.928
52
1
21
5
545
93
66318
66318
322
71 322
71
63003BAUCHI 3 0.972
22
0
29
36
6
13
63008MAMBILA 3
1.020
0.989
35
1
42
35
1
42
1.000
43006EFFURUN 3
490
19
73002OKPAI 3
0.994
0.988
75
0
29
75
0
29
73030IHIALA 3
23006IBADAN
1.000
13026OKE_ARO_3
61
8
21
53012DUTSE 3
0.974
53011KAZAURE 3
0.992
1.000
5 174
597
94
6
18
4
94
6
1
2
0.966
63009WUKARI
53010EN ARFICA PV
0.919
30
0
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73
00
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83001ALAOJI NIPP3
73007NNEWI 3
0
329
30
338
1
2
1
440
61
440
61
447
89
13004SAKETE 3
63
12
64
48
0.963
0.963
13028ARIGBAJO
174 260260
63006JALINGO_3
73
9
18
4
97
33010ZABORI
0.931
38
1
14
0
375
123
38
1
14
0
375
123750
247
225
62
22
6
52
10
8
22
225
62
226
52
SW
11
05
13012PARAS
0.960
115
69
115
69
249
176
249
176
33011FARAKU
0.904
278
89
275
90278
89
275
90
550
181
43012ZUMA 0.982
79
3
12
9
79
3
12
9
13
13
19
9
13
13
19
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53013DAURA
0.992
64
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329
98329
98
53016JOGANA
0.972
101
74 100 83
414
112
401
162
70
70
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7039
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53020MILLENIUM
0.962
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63
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258
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26
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63015MAYOBELWA 0.8897
88
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92 415
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0.963
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209
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0.979
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197 6
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15
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393
27
393
27
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33006SOKOTO 3
322 315
32
1
31
7
0.935
414
30
414
30562
98562
98
23007ADO EKITI 3
0.698
43013OKENE 3
0.869
1027
307
53021AZARE 3
0.972
79
1
79
1
63016GOMBI 3
0.909
381 7
3
381
73
63017BIU 3
0.928
17084
17084
281 111281 111
63018POTISKUM 3
0.967
146
22 146
22
18
6
57
18
6
57
73031KASHIMBILLA3
1.026
73032AYANGBA 3 0.925
83011OGOJA 3
1.027
0
0
83012IKOM 3 1.0160 0
43005GEREGU
448
234
90010_1
0.967
317
139
521
108
521
108 859
319
859
319
13005OLORUNSOGO3
597
336
23010SHAGAMU
0.939
134
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528
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92
13035IJORA 3
90011
0.980
902 212
46
4
71
46
4 71
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1.000
191
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32021NIAMEY 1
0.868
1
59
2052010
GAZOUA 1
SW
58
1.000
SW
998
12003IKEJA W 1BB1
Export 2000 MW
Total Generation 39916 MWNigeria Load 35598 MW
Genera tion from H PP 4369 MW
Generation per DISCO Loads per DISCO
3-Abuja 7949 MW
4-Benin 7635 MW
9-Eko 1350 MW
7-Enugu 1904 MW
2-Ibadan 1575 MW
1-Ikeja 4125 MW
6-Jos 1745 MW
5-Kaduna 832 MW
10-Kano 1019 MW
8-Pt Harco 10842 MW
11-Yola 2470 MW
Genera tion from PV 990 MW
Total Load 37598 MW
9-Eko 2509 MW
7-Enugu 2114 MW
2-Ibadan 4923 MW
6-Jos 1131 MW
5-Kaduna 3043 MW
10-Kano 4021 MW
8-Pt Harco 3292 MW
11-Yola 1678 MW
1-Ikeja 4295 MW
3-Abuja 5316 MW
4-Benin 3275 MW
250
98
200
101
250
98
250
98
250
98
250
98
250
98
250
98
250
98
250
98
1250
117R
1200
114R
250
117R
1250
117R
250
117R
250
117R
1250
117R
1250
117R
250
117R
1250
117R
12
00
90
0H
96029GWAGWALAD
375
250
125
500
0
MV
A F
low
TCN330kV TRANSMISSINO NETWORK
TCN2040MODEL
Total Generation: 39916 MW
Nigeria Load: 35598 MW
Export: 2000 MW
Total Load: 37598 MW
Generation from PV: 990 MW
Generarion from HPP: 4369 MW
7-95
Yola-Little Gombi-Biu-Damaturu
Damaturu-Potiskum-Azare-Dutse-Jogana
The required new transmission lines for 2040 are shown in Table 7-9.3.
Table 7-9.3 New transmission lines and reinforcements required for 2040
Substation Name
Substation Name
Voltage (kV)
Length (km)
Type Proposed Solution
Aladja Delta IV 330 32 SC Convert to DC
Osogbo Ganmo 330 50 SC Convert to DC
Yola Little Gombi 330 100 DC New DC transmission line
Little Gombi Biu 330 80 DC New DC transmission line
Biu Daimaturu 330 130 DC New DC transmission line
Daimaturu Potiscum 330 100 DC New DC transmission line
Potiscum Azare 330 100 DC New DC transmission line
Azare Dutse 330 90 DC New DC transmission line
Dutse Jogana 330 76 DC New DC transmission line
Source: JICA Study Team
7-9-3-2 Reactive Power Compensation
In addition to the requirements described for the 2035 case, reactive power compensation would be required by 2040, considering the following:
Due to the sharp increase in the forecast load in Abuja, there is an additional reactive power deficit in the Abuja area of approx. 1,500 MVar.
Additional reactive power deficit at Kano of approx. 600 MVar
Additional reactive power deficit at Bernin Kebbi of approx. 400 MVar
Additional reactive power deficit at Ikeja West of approx. 200 MVar
It is recommended that more detailed reactive power compensation studies be conducted at a later stage to determine the optimal sizes and locations of the reactive power equipment for 2040.
7-96
7-10 Cost Estimation of Transmission Network Development Plan
7-10-1 Basis for Cost Estimation
For calculation of cost of new transmission lines and substations of the proposed transmission system expansions, a simplified cost model has been prepared. For transmission lines it is based on cost per km of transmission line for each voltage level. For substations, the costs for high-voltage feeders have been estimated and comprise two components: one for high-voltage equipment and another for all other substation components (civil works, steel protection & control equipment, auxiliary power supply, etc.). Furthermore, the costs for main power transformers, reactors and capacitors have also been estimated.
For new 132/33 kV substations, the costs for new 33 kV switchgear have been taken into account. If increasing the transformer capacity in existing 132/33 kV substations, it has been assumed that additional 33 kV switchgear will also be installed. Based on this approach, cost estimation accuracy of ±25% can usually be assumed. Table 7-10.1 below shows the cost components considered in the cost estimation, based on experience with similar projects. The cost estimation is compared with TCN’s cost estimations and both agreed that they generally correlate effectively.
Table 7-10.1 Cost components
Unit Costs
Transmission Lines (million US$/km)
132 kV SC Line 0.17
330 kV SC Line 0.22
500 kV SC Line 0.28
750 kV SC Line 0.35
132 kV DC Line 0.26
330 kV DC Line 0.45
132 kV SC Line Reconductoring 0.04
330 kV SC Line Reconductoring 0.08
132 kV DC Line Reconductoring 0.08
330 kV DC Line Reconductoring 0.15
Substations (million US$)
132 kV HV equipment 0.70
330 kV HV equipment 1.00
500 kV HV equipment 1.30
750 kV HV equipment 2.20
132 kV feeder (= 132 kV HV equipment + Other components) 1.60
330 kV feeder (= 330 kV HV equipment + Other components) 1.90
30 MVA Transformer 132/11 kV 0.60
60 MVA Transformer 132/33 kV 0.80
150 MVA Transformer 330/132 kV 1.50
1000 MVA Transformer 750/330 kV 10.00
11 kV Switchgear 0.50
33 kV Switchgear 0.70
30 MVar Shunt Reactor – 33 kV (including 33 kV switchgear) 0.50
75 MVar Shunt Reactor – 330 kV 0.80
25 MVar Shunt Capacitor – 33 kV (including 33 kV switchgear) 0.25
25 MVar Shunt Capacitor – 132 kV 0.30
100 MVar Shunt Capacitor – 330kV 1.00
Other components (Civil Works, Steel, Protection, Station Control, Auxiliary Power Supply, Installation etc.)
0.90
Source: JICA Study Team
7-97
The following are needed to enhance the power transmission line:
SC : Installation of Single-Circuit transmission line/Installing a second parallel circuit
DC : Installation of Double-Circuit transmission line
RE(SC) : Reconductoring of Single-Circuit transmission line
RE(DC) : Reconductoring of Double-Circuit transmission line
7-10-2 Transmission Reinforcements Required by 2020
Power system studies have shown that most of the transmission system expansion required by 2025 is needed in northern Nigeria, particularly for the 330-kV system. Under the current transmission system expansion program of TCN and NIPP (see Annexes 7.2a and 7.2b) most of the transmission system expansions have been commissioned in the southern and central parts of Nigeria. Some of the transmission system expansions have already been completed and it is expected that the remainder will be commissioned by 2020 or very soon afterwards.
Based on the results of Chapter 8: Power System Analysis, the costs of additional 330 and 132 kV transmission lines, additional 330/132 kV, 132/33 kV and 132/11 kV transformers as well as additional shunt reactors and shunt capacitors have been estimated.
Although it will be challenging to implement all measures by 2020 as required for over 9 GW power supply of the Nigerian transmission network, a major part of the network expansions is related to the 132-kV network and to additional 330/132 kV and 132/33 kV transformers.
7-10-2-1 Cost estimation of each project
Table 7-10.2 to Table 7-10.8 show the cost estimations for the individual groups of system expansion measures, i.e. transmission lines, transformers and reactive power compensation.
Table 7-10.9 summarizes all additional investments in transmission lines and substations by 2020.
Table 7-10.2 Reinforcements of 132 kV lines overloaded under N-0
Source: JICA Study Team
Rated
VoltageLength
Cost of Alternative 1
（Length × Unit Cost）
Cost of Alternative 2
（Length × Unit Cost）Cost
(kV) (km)Reinforce
ment
Unit Cost
(Million US$/km)
Reinforce
ment
Unit Cost
(Million US$/km)(Million US$) (Million US$) (Million US$)
1 Ibom IPP - Ikot Abasi 132 30 SC 0.17 DC 0.26 5.1 7.8
5.1 7.8
1 Ibom IPP 0 1 0 0 0 1.6
2 Ikot Abasi 0 1 0 0 0 1.6
3.2
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Subtotal II
Alternative 1 Alternative 2
Subtotal I
Grand Total (Alternative 1)
Grand Total (Alternative 2)
330 kV
Feeder
132 kV
Feeder
Cost Estimation of Reinforcement of 132 kV Transmission Lines overloaded under N-0 by 2020
8.3
14.2
Transmission Line Substation
Substations
Overhead Lines
No. Project
7-98
Table 7-10.3 Reinforcements of 132 kV transmission lines overloaded under N-1
Source: JICA Study Team
Table 7-10.4 Upgrading requirements of 330/132 kV 3-winding transformers overloaded under N-0
Source: JICA Study Team
Table 7-10.5 Upgrading requirements of 132/33 kV and 132/11 kV transformers under N-0 by 2020
Source: JICA Study Team
Rated
VoltageLength
Cost of Alternative 1
（Length × Unit Cost）
Cost of Alternative 2
（Length × Unit Cost）Cost
(kV) (km)Reinforce
ment
Unit Cost
(Million US$/km)
Reinforce
ment
Unit Cost
(Million US$/km)(Million US$) (Million US$) (Million US$)
1 Gombe - T-Junction 132 40 SC 0.17 DC 0.26 6.8 10.4
2 Yola - T-Junction 132 56 SC 0.17 DC 0.26 9.5 14.6
3 Omoku - Rumusoi 132 20 RE 0.08 DC 0.26 1.6 5.2
4 PHCT Main - Rumusoi 132 10 RE 0.08 DC 0.26 0.8 2.6
5 Ajaokuta - Okene 132 60 SC 0.17 DC 0.26 10.2 15.6
6 Benin - Irrua 132 88 SC 0.17 DC 0.26 15.0 22.9
7 Mando - Kudenda 132 20 RE 0.08 DC 0.26 1.6 5.2
8 Osogbo - Iwo 132 80 SC 0.17 DC 0.26 13.6 20.8
9 Yenagoa - Gbarain 132 5 RE 0.08 DC 0.26 0.4 1.3
10 Afam 1-2-3 - Afam IV 132 1 RE 0.08 DC 0.26 0.1 0.3
11 Ikeja West - Alimoso 132 4 RE 0.08 DC 0.26 0.3 0.9
12 Biu - Dadinkowa 132 82 SC 0.17 DC 0.26 13.9 21.3
13 Yenagoa - Ahoada 132 46 RE 0.08 DC 0.26 3.7 12.0
14 Ayede - Idaban North 132 12 SC 0.17 DC 0.26 2.0 3.1
15 Eket - Ibom IPP 132 45 RE 0.08 DC 0.26 3.6 11.7
16 Onne - Tramadi 132 10 RE 0.08 DC 0.26 0.8 2.6
17 PHCT Main - Rivers IPP 132 12 RE 0.08 DC 0.26 1.0 3.1
18 Zaria - Funtua 132 7 SC 0.17 DC 0.26 1.2 1.8
86.1 155.4
1 Ajaokuta 0 1 0 0 0 1.6
2 Okene 0 1 0 0 0 1.6
3 Yenagoa 0 0 0 0 0 0.0
4 Gbarain 0 0 0 0 0 0.0
5 Osogbo 0 1 0 0 0 1.6
6 Iwo 0 1 0 0 0 1.6
7 Biu 0 1 0 0 0 1.6
8 Dadinkowa 0 1 0 0 0 1.6
9 Benin 0 1 0 0 0 1.6
10 Irrua 0 1 0 0 0 1.6
11 Ikeja West 0 0 0 0 0 0.0
12 Alimosho 0 0 0 0 0 0.0
13 Mando 0 0 0 0 0 0.0
14 Kudenda 0 0 0 0 0 0.0
15 PHCT Main 0 0 0 0 0 0.0
16 Rumusoi 0 0 0 0 0 0.0
17 Eket 0 0 0 0 0 0.0
18 Zaria 0 1 0 0 0 1.6
19 Funtua 0 1 0 0 0 1.6
20 Onne 0 1 0 0 0 1.6
21 Tramadi 0 0 0 0 0 0.0
17.6
Cost Estimation of Reinforcement of 132 kVTransmission Lines overloaded under N-1 by 2020
Alternative 1 Alternative 2 330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Subtotal I
103.7
Transmission Line Substation
Overhead Lines
Substations
Subtotal II
Grand Total - Alternative 1
No. Project
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Benin 2 2 0 2 0 10.0
2 Benin North 1 1 0 1 0 5.0
3 Birnin Kebbi 1 1 0 1 0 5.0
4 Ganmo 1 1 0 1 0 5.0
25.0
Cost Estimation of Upgrading of 330/132 kV 3-winding Transformers overloaded under N-1 by 2020
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Subtotal I
Subtotal II
25.0
Transmission Line Substation
Overhead Lines
Substations
Grand Total
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Suleja 0 1 0 1 0 0 1 2.7
2 Benin 0 3 3 0 0 3 0 9.3
3 Benin North 0 1 1 0 0 1 0 3.1
4 Kano 0 1 1 0 0 1 0 3.1
5 Funtua 0 1 1 0 0 1 0 3.1
6 Funtua 0 1 0 1 0 0 1 2.7
7 Ojo 0 1 1 0 0 1 0 3.1
8 Omuaran 0 1 1 0 0 1 0 3.1
30.2
Cost Estimation of Upgrading of Transformers overloaded under N-0 by 2020
330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
11kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
30 MVA、
132/11 kV
Transformer
Subtotal I
30.2
Transmission Line Substation
Overhead Lines
Substations
No. Project
Subtotal II
Grand Total
7-99
Table 7-10.6 Upgrading requirements of 330/132 kV, 132/33 kV and 132/11 kV transformers loaded
above 85% under N-0 by 2020
Source: JICA Study Team
Table 7-10.7 New reactors and capacitors
Source: JICA Study Team
Table 7-10.8 New transmission lines required by 2020
Source: JICA Study Team Note: The 330 kV lines which are part of the North-East Ring and North-West Ring, are considered in the cost estimation for 2025
because implementation by 2020 is not possible.
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Kano 1 1 0 0 1 0 0 5.0
2 Benin North 1 1 0 0 1 0 0 5.0
3 Odogunyan 0 1 1 0 0 1 0 3.1
4 Ganmo 0 1 1 0 0 1 0 3.1
5 Ejigbo 0 1 1 0 0 1 0 3.1
6 Ojo 0 1 1 0 0 1 0 3.1
7 Alimosho 0 1 1 0 0 1 0 3.1
8 Ughelli 0 1 1 0 0 1 0 3.1
9 Paras 0 1 1 0 0 1 0 3.1
10 Shagamu 0 1 1 0 0 1 0 3.1
11 Afam 1-2-3 0 1 0 1 0 0 1 2.7
12 Iwo 0 1 1 0 0 1 0 3.1
13 Shiroro 0 1 1 0 0 1 0 3.1
43.7Subtotal II
Grand Total
Cost Estimation of Upgrading of Transformers loded about 85% under N-0 by 2020
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
11kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
30 MVA、
132/11 kV
Transformer
43.7
Transmission Line Substation
Overhead Lines
Substations
Subtotal I
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Maiduguri 1 0 0 0 0 1 0 2.7
2 Ondo2 0 1 0 0 1 0 0 1.9
3 Irrua 0 1 0 0 1 0 0 1.9
4 Gusau 0 1 0 0 1 0 0 1.9
8.4
33 kV
Switchgear
11kV
Switchgear
8.4
Substations
Cost Estimation of New Reactors and Capacitors required by 2020
Subtotal I
Subtotal II
Grand Total
132 kV
Capacitor
330 kV
Reactor
32 kV
Reactor
Overhead Lines
Transmission Line Substation
No. Project330 kV
Feeder
132 kV
Feeder
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Kaduna - Kano 330 230 0.45 103.5
2 Akangba - Ijora 330 14 0.45 6.3
3 Ijora - Alagbon 330 8 0.45 3.6
4 Arigbso - New Agbara 330 40 0.45 18.0
5 Ugwaji - Abakaliki 330 85 0.45 38.3
6 Osogbo - Arigbajo 330 183 0.45 82.4
7 Ayede - Idaban North 132 15 0.26 3.9
8 New Agbara - Agbara 132 18 0.26 4.7
9 Ogijo - Redeem 132 14 0.26 3.6
10 Birmin Kebbi - Dosso 132 128 0.26 33.3
Subtotal I 297.5
1 Kaduna 4 2 1 2 2 16.1
2 Kano 2 1 1 1 1 8.4
3 Akangba 4 2 1 2 2 16.1
4 Ijora 4 2 1 2 2 16.1
5 Arigbajo 12 2 1 2 2 31.3
6 Agbara 0 2 1 0 1 4.7
7 New Agbara 4 2 1 2 2 16.1
8 Ugwaji 2 0 0 0 0 3.8
9 Abakaliki 2 0 0 0 0 3.8
10 Osogbo 0 2 0 0 0 3.2
11 Ayede 0 2 0 0 0 3.2
12 Ibadan North 0 2 0 0 0 3.2
13 Ogijo 0 2 0 0 0 3.2
14 Redeem 0 4 1 0 2 8.7
15 Dosso 0 2 0 0 0 3.2
16 Ibom IPP 0 2 0 0 0 3.2
17 Ikot Abasi 0 2 0 0 0 3.2
Subtotal II 147.5
Grand Total
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Cost Estimation of New 132 kV Transmission Lines required by 2020
445.0
Transmission Line Substation
New Substations / Extension of Substations
Overhead Lines
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
7-100
7-10-2-2 Summary of Additional Investments by 2020
Table 7-10.9 shows a summary of all additional investments in transmission lines and substations by 2020. The 330 kV North-East Ring and the 330-kV line Kainji - Birnin-Kebbi are also necessary to supply the forecast load of over 9 GW. However, considering the necessary implementation time, these lines are more likely to be available between 2020 and 2025. Accordingly, these costs are included in the 2025 investment costs.
Table 7-10.9 Summary of additional investments by 2020
Source: JICA Study Team
7-10-3 Transmission Reinforcements Required by 2025
To allow power transmission of approximately 20 GW by 2025, it will be necessary to build numerous new 330 and 132 kV transmission lines, to increase the transmission capacity of existing 132 kV transmission lines by reconductoring existing lines and installing additional 330/132 kV and 132/33(11) kV transformers.
7-10-3-1 Cost Estimation of Each Project
The cost estimate for additional 132 kV lines, 330/132 kV transformers and 132/33 (11) kV transformers is shown in Table 7-10.10 to Table 7-10.19.
Table 7-10.10 Additional Lines by 2025 - North-West Ring
Source: JICA Study Team
Reinforcements of 132 kV lines overloaded under N-0 5.1 3.2 8.3
Reinforcements of 132 kV lines overloaded under N-1 86.1 17.6 103.7
Upgrading requirements of 330/132 kV 3-winding transformers overloaded under N-0 0.0 25.0 25.0
Upgrading requirements of 132/33 kV and 132/11 kV transformers overloaded under N-0 0.0 30.2 30.2
Upgrading requirements of 330/132 kV, 132/33 kV and 132/11 kV transformers overloaded
loaded over 85% under N-00 43.7 43.7
New Reactor and Capacitors 0 8.4 8.4
New Transmission Lines by 2020 297.5 147.5 445.0
Total Additional Investment Cost by 2020 664.3
Total Cost required by 2020
Transmission System ExpansionsTransmission
Line
Substation
(Million US$)
Total Cost
(Million US$)
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Kainji - Birnin Kebbi 330 kV DC Line 330 310 0.45 139.5
2 Birnin Kebbi - Sokoto 330 kV DC Line 330 130 0.45 58.5
3 Sokoto - Talata Mafara 330 kV DC Line 330 125 0.45 56.3
4 Talata Mafara - Gusau 330 kV DC Line 330 85 0.45 38.3
5 Gusau - Funtua 330 kV DC Line 330 70 0.45 31.5
6 Funtua - Zaria 330 kV DC Line 330 70 0.45 31.5
355.5
1 Kainji 2 0 0 0 0 3.8
2 Birnin Kebbi 7 1 1 1 1 17.9
3 Sokoto 7 9 1 2 1 32.2
4 Talata Mafara 7 9 1 2 1 32.2
5 Gusau 7 9 1 2 1 32.2
6 Funtua 7 9 1 2 1 32.2
7 Zaria 4 2 1 2 1 15.3
165.8
Cost Estimation of Additional Transmission Lines required by 2025 （330 kV North West Ring）
Subtotal I
Subtotal II
Transmission Line Substation
Overhead Lines
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
521.3
Substations
Grand Total
7-101
Table 7-10.11 Additional Lines by 2025 - North-East Ring
Source: JICA Study Team
Table 7-10.12 Additional Lines by 2025 - Mambilla Network Connection
Source: JICA Study Team
Table 7-10.13 Other Additional Lines by 2025 (1)
Source: JICA Study Team
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Jos - Gombe 330 kV DC Line 330 270 0.45 121.5
2 Gombe - Damaturu 330 kV DC Line 330 180 0.45 81.0
3 Damaturu - Maiduguri 330 kV DC Line 330 260 0.45 117.0
4 Gombe - Yola 330 kV DC Line 330 240 0.45 108.0
5 Yola - Jalingo 330 kV DC Line 330 160 0.45 72.0
499.5
1 Jos 2 0 0 0 0 3.8
2 Gombe 9 7 1 2 2 33.6
3 Damaturu 7 7 1 2 2 29.8
4 Maiduguri 5 5 1 2 2 22.8
5 Yola 7 7 1 2 2 29.8
6 Jailingo 7 9 1 2 1 32.2
152.0
Cost Estimation of Additional Transmission Lines required by 2025 （330 kV North East Ring）
60 MVA、
132/33 kV
Transformer
150 MVA、
330/132kV
Transformer
33 kV
Switchgear
132 kV
Feeder
330 kV
Feeder
Transmission Line Substation
Overhead Lines
Substations
No. Project
Subtotal I
Subtotal II
Grand Total 651.5
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Mambilla - Wukari 330 kV DC Line 330 159 0.45 71.6
2 Mambilla - Jailingo 330 95 0.45 42.8
3 Wukari - Makurdi 330 159 0.45 71.6
4 Wukari - Lafia 330 95 0.45 42.8
228.6
1 Mambilla 2 0 0 0 0 3.8
2 Wukari 5 5 0 2 2 22.1
3 Makurdi 2 0 0 0 0 3.8
4 Lafia 2 0 0 0 0 3.8
5 Jalingo 2 0 0 0 0 3.8
37.3
Cost Estimation of Additional Transmission Lines required by 2025 （330 kV Mambilla Network Con-nections）Transmission Line Substation
Overhead Lines
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Subtotal I
Substations
265.9
Subtotal II
Grand Total
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Arigbajo - Ayede Loop-in at Ayede 330 1 0.22 0.2
2 Katsina - Daura 330 40 0.45 18.0
3 Daura - Kazaure 330 25 0.45 11.3
4 Shiroro - Kaduna 330 96 0.45 43.2
5 Gwangwalada - Shiroro 132 145 0.26 37.7
6 Benin North - Omotosho 330 110 0.45 49.5
7 Zungeru - Kainji 330 200 0.45 90.0
8 Zungeru - Shiroro 330 25 0.45 11.3
261.1
1 Ayede 2 0 0 0 0 3.8
2 Katsina 2 0 0 0 0 3.8
3 Daura 4 0 0 0 0 7.6
4 Kazaure 2 0 0 0 0 3.8
5 Shiroro 6 0 0 0 0 11.4
6 Kaduna 2 0 0 0 0 3.8
7 Gwangwalada 2 0 0 0 0 3.8
8 Benin North 2 0 0 0 0 3.8
9 Omotosho 2 0 0 0 0 3.8
10 Zungeru 4 0 0 0 0 7.6
11 Kainji 2 0 0 0 0 3.8
57.0
Cost Estimation of Transmission Lines required by 2025 (Others 1)
Subtotal I
Subtotal II
318.1
Substations
Transmission Line Substation
Overhead Lines
Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
No.
Grand Total
7-102
Table 7-10.14 Other Additional Lines by 2025 (2)
Source: JICA Study Team
Table 7-10.15 First transmission lines of the Supergrid by 2025
Source: JICA Study Team
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Shiroro - Tegina 132 65 0.26 16.9
2 Tegina - Kontagora 132 90 0.26 23.4
3 Kontagora - Yelwa-Yauri 132 88 0.26 22.9
4 Ganmo - Ilorin 132 10.5 0.26 2.7
5 Obajana - Egbe 132 97 0.26 25.2
6 Omotosho - Ondo 132 98 0.26 25.5
7 Benin - Irrua 132 88 0.26 22.9
8 Irrua - Ukpilla 132 43 0.26 11.2
9 Ukpilla - Okene 132 33 0.26 8.6
10 Shamagu - Ijebu Ode 132 41 0.26 10.7
11 Dakata - Gagarawa 132 89 0.26 23.1
12 Gagarawa - Hadejia 132 60 0.26 15.6
13 Dakata - Kumbotso 132 30 0.26 7.8
14 Obajana - Okene 132 97 0.26 25.2
15 Kainji - Iseyin 132 200 0.26 52.0
293.7
1 Shiroro 0 2 0 0 0 3.2
2 Tegina 0 2 0 0 0 3.2
3 Kontagora 0 2 0 0 0 3.2
4 Yelwa-Yauri 0 2 0 0 0 3.2
5 Ganmo 0 2 0 0 0 3.2
6 Ilorin 0 2 0 0 0 3.2
7 Obajana 0 2 0 0 0 3.2
8 Egbe 0 2 0 0 0 3.2
9 Omotosho 0 2 0 0 0 3.2
10 Ondo 0 2 0 0 0 3.2
11 Benin 0 2 0 0 0 3.2
12 Ukpilla 0 2 0 0 0 3.2
13 Shamagu 0 2 0 0 0 3.2
14 Ijebu Ode 0 2 0 0 0 3.2
15 Dakata 0 2 0 0 0 3.2
16 Gagarawa 0 2 0 0 0 3.2
17 Hadejia 0 2 0 0 0 3.2
18 Dakata 0 2 0 0 0 3.2
19 Kumbotso 0 2 0 0 0 3.2
20 Birmin Kebbi 0 2 0 0 0 3.2
21 Dosso 0 2 0 0 0 3.2
67.2
Cost Estimation of Transmission Lines required by 2025 (Others 2)
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Transmission Line Substation
No. Project330 kV
Feeder
Subtotal II
Grand Total 360.9
Subtotal I
Overhead Lines
Substations
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Ikot-Ekpene - Makurdi 330 320 0.45 144.0
2 Makurdi - Gwangwalada 330 180 0.45 81.0
3 Ajaokuta - Gwangwalada 330 150 0.45 67.5
4 Osogbo - Gwangwalada 330 250 0.45 112.5
5 Gwangwalada - Funtua 330 250 0.45 112.5
517.5
1 Ikot-Ekpene 2 2 0 2 0 10.0
2 Markurdi 2 2 0 2 0 10.0
3 Ajaokuta 2 2 0 2 0 10.0
4 Gwangwalada 8 2 0 2 0 21.4
5 Osogbo 2 2 0 2 0 10.0
6 Funtua 2 2 0 2 0 10.0
71.4
Cost Estimation of Transmission Lines for Supergrid required by 2025
Subtotal I
Subtotal II
Grand Total
Transmission Line Substation
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
588.9
Substations
Overhead Lines
7-103
Table 7-10.16 Reconductoring of 132 kV lines by 2025
Source: JICA Study Team
Table 7-10.17 Upgrading requirements of 330/132kV transformers
Source: JICA Study Team
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Egbin - Ikorodu 132 20 0.08 1.6
2 Ogijo - Shagamu 132 16 0.08 1.3
3 Ayede - Idaban North 132 12 0.04 0.5
4 Ayede - Jericho 132 6 0.08 0.5
5 Alaoji - Aba 132 10 0.08 0.8
6 Eket - Ibom IPP 132 45 0.08 3.6
7 PHCT Main - PHCT Town 132 6 0.04 0.2
8.5
0.0
Cost Estimation of Reconductoring of 132 kV Transmission Lines required by 2025
Subtotal I
Subtotal II
Grand Total 8.5
Substations
Transmission Line Substation
Overhead Lines
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Adiagbo 2 2 0 2 0 10.0
2 Aja 2 2 0 2 0 10.0
3 Ajaokuta 2 2 0 2 0 10.0
4 Akangba 2 2 0 2 0 10.0
5 Akoka 2 2 0 2 0 10.0
6 Akure 2 2 0 2 0 10.0
7 Apapa 2 2 0 2 0 10.0
8 Ayede 2 2 0 2 0 10.0
9 Delta 2 2 0 2 0 10.0
10 Ganmo 2 2 0 2 0 10.0
11 Ihala 2 2 0 2 0 10.0
12 Ikeja West 2 2 0 2 0 10.0
13 Isolo 2 2 0 2 0 10.0
14 Jericho 2 2 0 2 0 10.0
15 Kano 2 2 0 2 0 10.0
16 Kumbotoso 2 2 0 2 0 10.0
17 Nnewi 2 2 0 2 0 10.0
18 Omotosho 2 2 0 2 0 10.0
19 Onitsha 2 2 0 2 0 10.0
20 Osogbo 2 2 0 2 0 10.0
21 Oweri 2 2 0 2 0 10.0
22 West Main 2 2 0 2 0 10.0
210.0
Cost Estimation of Upgrading of 330/132 kV 3-winding Transformers required by 2025
Subtotal I
Subtotal II
Transmission Line Substation
Overhead Lines
Substations
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
210.0Grand Total
7-104
Table 7-10.18 Upgrading requirements of 132/33(11) kV transformers
Source: JICA Study Team
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Aba 0 2 2 0 0 2 0 6.2
2 Abakaliki 0 2 2 0 0 2 0 6.2
3 Afam 1-2-3 0 2 0 2 0 0 2 5.4
4 Ahoada 0 2 2 0 0 2 0 6.2
5 Ajaokuta 0 2 2 0 0 2 0 6.2
6 Akangba 0 2 2 0 0 2 0 6.2
7 Akoka 0 2 2 0 0 2 0 6.2
8 Akure 0 2 2 0 0 2 0 6.2
9 Alagbon 0 2 2 0 0 2 0 6.2
10 Alimosho 0 2 2 0 0 2 0 6.2
11 Amukpe 0 2 2 0 0 2 0 6.2
12 Arigbajo 0 2 2 0 0 2 0 6.2
13 Ayede 0 2 2 0 0 2 0 6.2
14 Benin 0 2 2 0 0 2 0 6.2
15 Dan Agundi 0 2 2 0 0 2 0 6.2
16 Egbin 0 2 2 0 0 2 0 6.2
17 Ejigbo 0 2 2 0 0 2 0 6.2
18 Eket 0 2 2 0 0 2 0 6.2
19 Elelenwo 0 2 2 0 0 2 0 6.2
20 Ganmo 0 2 2 0 0 2 0 6.2
21 Gashuwa 0 2 2 0 0 2 0 6.2
22 Gusau 0 2 2 0 0 2 0 6.2
23 Idaban North 0 2 2 0 0 2 0 6.2
24 Ijebu Ode 0 2 2 0 0 2 0 6.2
25 Ijora 0 2 2 0 0 2 0 6.2
26 Ikordu 0 2 2 0 0 2 0 6.2
27 Ikot Abasi 0 2 2 0 0 2 0 6.2
28 Ilesha 0 2 2 0 0 2 0 6.2
29 Illupeju 0 2 0 2 0 0 2 5.4
30 Irrua 0 2 2 0 0 2 0 6.2
31 Iseyin 0 2 2 0 0 2 0 6.2
32 Isolo 0 2 2 0 0 2 0 6.2
33 Itire 0 2 0 2 0 0 2 5.4
34 Iwo 0 2 2 0 0 2 0 6.2
35 Jalingo 0 2 2 0 0 2 0 6.2
36 Jos 0 2 2 0 0 2 0 6.2
37 Kaduna Town 0 2 2 0 0 2 0 6.2
38 Kafanchan 0 2 2 0 0 2 0 6.2
39 Kano 0 2 2 0 0 2 0 6.2
40 Katsina 0 2 2 0 0 2 0 6.2
41 Kazaure 0 2 2 0 0 2 0 6.2
42 Makeri 0 2 2 0 0 2 0 6.2
43 New Haven 0 2 2 0 0 2 0 6.2
44 Nkalagu 0 2 2 0 0 2 0 6.2
45 Odogunyan 0 2 2 0 0 2 0 6.2
46 Ogba 0 2 0 2 0 0 2 5.4
47 Ojo 0 2 2 0 0 2 0 6.2
48 Ondo2 0 2 2 0 0 2 0 6.2
49 Onitsha 0 2 2 0 0 2 0 6.2
50 Osogbo 0 2 2 0 0 2 0 6.2
51 Otta 0 2 2 0 0 2 0 6.2
52 Oweri 0 2 2 0 0 2 0 6.2
53 Oworosoki 0 2 2 0 0 2 0 6.2
54 Paras 0 2 2 0 0 2 0 6.2
55 PHCT Town 0 2 0 2 0 0 2 5.4
56 Rumusoi 0 2 2 0 0 2 0 6.2
57 Savannah 0 2 2 0 0 2 0 6.2
58 Shagamu 0 2 2 0 0 2 0 6.2
59 Shagamu Cement 0 2 0 2 0 0 2 5.4
60 Shiroro 0 2 2 0 0 2 0 6.2
61 Suleja 0 2 2 0 0 2 0 6.2
62 Tegina 0 2 2 0 0 2 0 6.2
63 Ughelli 0 2 2 0 0 2 0 6.2
64 Umuahia 0 2 2 0 0 2 0 6.2
65 Uyo 0 2 2 0 0 2 0 6.2
398.2
Grand Total
30 MVA、
132/11 kV
Transformer
Cost Estimation of Upgrading of 132/33, 132/11 kV Transformers required by 2025
Subtotal I
Subtotal II
132 kV
Feeder
33 kV
Switchgear
11kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
398.2
Transmission Line Substation
Substations
Overhead Lines
No. Project330 kV
Feeder
7-105
Table 7-10.19 New reactors and capacitors by 2025
Source: JICA Study Team
7-10-3-2 Summary of Additional Investments between 2021 and 2025
Table 7-10.20 shows a summary of all additional investments in transmission lines and substations between 2021 and 2025.
Table 7-10.20 Summary of additional investments in transmission lines and
substations between 2021 and 2025
Source: JICA Study Team
7-10-4 Transmission Reinforcements Required by 2030
A further extension of the 330 kV Supergrid will be required by 2030. Furthermore, there will be a need to install capacitor banks at various substations to maintain voltages within permissible limits.
7-10-4-1 Cost Estimation of Each Project
The cost estimate for the additional transmission lines, transformers and capacitor banks is shown in Table 7-10.21 and 7-10.22.
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Iseyin 0 0 0 0 0 0 2 0 0.50
2 Irrua 0 0 0 0 0 0 1 0 0.25
3 Keffi 0 1 0 0 1 0 0 0 1.90
4 Omuaran 0 2 0 0 2 0 0 0 3.80
5 Hadejia 0 2 0 0 2 0 0 0 3.80
6 Apo 0 2 0 0 2 0 0 0 3.80
7 Sulejia 0 2 0 0 2 0 0 0 3.80
8 Uyo 0 4 0 0 4 0 0 0 7.60
9 Ondo 0 1 0 0 1 0 0 0 1.90
27.35
Cost Estimation of New Reactors and Capacitors required by 2025
Subtotal I
Subtotal II
11 kV
Switchgear132 kV
Capacitor
132 kV
Reactor
33 kV
Capacitor
33 kV
Reactor
Transmission Line Substation
Substations
Overhead Lines
27.35Grand Total
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
Project 1: 330 kV North West Ring by 2025 355.5 165.8 521.3
Project 2: 330 kV North East Ring by 2025 499.5 152.0 651.5
Project 3: 330 kV Mambilla Network Connections by 2025 228.6 37.3 265.9
Additional Transmission Lines by 2025 - Part 1 261.1 57.0 318.1
Additional Transmission Lines by 2025 - Part 2 293.7 67.2 360.9
First Transmission Lines of the Supergrid by 2025 517.5 71.4 588.9
Reconductoring of 132 kV Lines 8.5 0.0 8.5
Additional 330/132 kV Transformers by 2025 0.0 210.0 210.0
Additional 132/33 and 132/11 kV Transformers 0.0 398.2 398.2
New Reactive Power Compensation 0.0 27.4 27.4
Costs for converting 330 kV DC lines to quad conductors 10.0 0.0 10.0
Total Additional Investment Cost by 2025 3,360.7
Total Cost required from 2021 to 2025
Transmission System ExpansionsTransmission Line
(Million US$)
Substation
(Million US$)
Total Cost
(Million US$)
7-106
Table 7-10.21 Additional investments in 330 kV Supergrid transmission lines and substations by 2030
Source: JICA Study Team
Table 7-10.22 Additional Capacitor Banks to be installed by 2030
Source: JICA Study Team
7-10-5 Transmission Reinforcements Required by 2035
Table 7-10.23 Additional investments in transmission lines and substations by 2035
Source: JICA Study Team
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Ikot Ekpene - Benin 330 300 0.45 135.0
2 Benin - Egbin 330 230 0.45 103.5
3 Egbin - New Agbara 330 50 0.45 22.5
4 Benin - Osogbo 330 200 0.45 90.0
5 Osogbo - Kainji 330 200 0.45 90.0
6 Benin - Ajeokuta 330 150 0.45 67.5
7 Gangwalada - Kainji 330 250 0.45 112.5
8 Kainji - Bernin Kebbi 330 300 0.45 135.0
9 New Agbara - Osogbo 330 150 0.45 67.5
823.5
1 Ikot Ekpene 2 0 0 0 0 3.8
2 Benin 6 5 0 0 0 19.4
3 Egbin 4 0 0 0 0 7.6
4 New Agbara 4 0 0 0 0 7.6
5 Osogbo 6 0 0 0 0 11.4
6 Ajaokuta 2 0 0 0 0 3.8
7 Gangwalada 2 0 0 0 0 3.8
8 Kainji 4 0 0 0 0 7.6
9 Bernin Kebbi 2 0 0 0 0 3.8
68.8
Subtotal I
Subtotal II
Grand Total
Cost Estimation of Additional 330 kV Supergrid Transmission Lines and Substations required by 2030
892.3
Transmission Line Substation
Overhead Lines
Substations
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Gombe 0 4 0 0 4 0 0 0 7.6
2 Bernin Kebbi 0 3 0 0 6 0 0 0 6.6
3 Gashuwa 0 1 0 0 1 0 0 0 1.9
4 Apo 0 2 0 0 2 0 0 0 3.8
5 Keffi 0 1 0 0 1 0 0 0 1.9
6 Uba 0 2 0 0 2 0 0 0 3.8
25.6
Cost Estimation of New Reactors and Capacitors required by 2030
Subtotal I
Transmission Line Substation
Overhead Lines
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
11 kV
Switchgear132 kV
Capacitor
132 kV
Reactor
33 kV
Capacitor
33 kV
Reactor
25.6
Subtotal II
Grand Total
Substations
Rated
VoltageLength Cost of Alternative 1 Cost of Alternative 2 Cost
(kV) (km)Reinforce
ment
Unit Cost
(Million US$/km)
Reinforce
ment
Unit Cost
(Million US$/km)(Million US$) (Million US$) (Million US$)
1 Wukari - Lafia 330 95 DC 0.45 DC 0.45 42.8 42.8
2 Zuma - Lokoja 330 25 RE 0.15 DC 0.45 3.8 11.3
3 Aja - Lekki 330 7 RE 0.15 DC 0.45 1.1 3.2
4 Benin North - Akure 330 130 RE 0.08 DC 0.45 10.4 58.5
5 Kwaya Kusar - Biu 132 42 SC 0.17 DC 0.26 7.1 10.9
6 Biu - Damboa 132 140 SC 0.17 DC 0.26 23.8 36.4
7 Damboa - Maiduguri 132 64 SC 0.17 DC 0.26 10.9 16.6
99.8 179.6
1 Wukari 2 0 0 0 0 3.8
2 Lafia 2 0 0 0 0 3.8
3 Zuma 0 0 0 0 0 0.0
4 Lokoja 0 0 0 0 0 0.0
5 Aja 0 0 0 0 0 0.0
6 Lekki 0 0 0 0 0 0.0
7 Benin North 0 0 0 0 0 0.0
8 Akure 0 0 0 0 0 0.0
9 Kwaya Kusar 0 1 0 0 0 1.6
10 Biu 0 2 0 0 0 3.2
11 Damboa 0 2 0 0 0 3.2
12 Maiduguri 0 1 0 0 0 1.6
17.2
117.0
60 MVA、
132/33 kV
Transformer
Cost Estimation of New Transmission Line required by 2035
Subtotal I
Subtotal II
Transmission Line Substation
Overhead Lines
Substations
Alternative 1 Alternative 2No. Project
330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
150 MVA、
330/132kV
Transformer
Grand Total - Alternative 1
7-107
Table 7-10.24 Additional Capacitor Banks to be installed by 2035
Source: JICA Study Team
7-10-6 Transmission Reinforcements Required by 2040
Table 7-10.25 Additional investments in transmission lines and substations by 2035
Source: JICA Study Team
Table 7-10.26 Additional Capacitor Banks to be installed by 2040
Source: JICA Study Team
7-10-7 Summary of Cost Comparison for Three Voltage Levels
This Section compares the cost of a super grid based on 330 kV (presently the highest voltage) with the costs of a super grid based on 500 and 750 kV nominal voltages (respectively 550- and 800 kV-rated voltages).
In the case of a 330-kV super grid, it is assumed that the transmission line will be Double-Circuit lines with Quad Bison conductors.
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Gombe 3 0 0 0 1 3 0 0 0 7.6
2 Bernin Kebbi 7 0 0 0 1 7 0 0 0 16.4
3 Ikeja West 0 12 0 0 1 12 0 0 0 23.8
47.8
Cost Estimation of New Reactors and Capacitors required by 2035
Subtotal I
Subtotal II
Grand Total
132 kV
Capacitor
132 kV
Reactor
33 kV
Capacitor
33 kV
Reactor
Transmission Line Substation
Overhead Lines
Substations
No. Project330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
11 kV
Switchgear
330 kV
Capacitor
47.8
Rated
VoltageLength
Cost of
Alternative 1
Cost of
Alternative 2Cost
(kV) (km) ReinforcementUnit Cost
(Million US$/km)
Reinforce
ment
Unit Cost
(Million US$/km)(Million US$) (Million US$) (Million US$)
1 Aladja - Delta IV 330 32 SC 0.22 DC 0.45 7.0 14.4
2 Osogbo - Ganmo 330 50 SC 0.22 DC 0.45 11.0 22.5
3 Yola - Little Gombe 330 100 DC 0.45 DC 0.45 45.0 45.0
4 Little Gombi - Biu 330 80 DC 0.45 DC 0.45 36.0 36.0
5 Biu - Daimaturu 330 130 DC 0.45 DC 0.45 58.5 58.5
6 Daimaturu - Potiscum 330 100 DC 0.45 DC 0.45 45.0 45.0
7 Potiscum - Azare 330 100 DC 0.45 DC 0.45 45.0 45.0
8 Azare - Dutse 330 90 DC 0.45 DC 0.45 40.5 40.5
9 Dutse - Jogana 330 76 DC 0.45 DC 0.45 34.2 34.2
322.2 341.1
1 Aladja 2 0 0 0 0 3.8
2 Osogbo 2 0 0 0 0 3.8
3 Ganmo 2 0 0 0 0 3.8
4 Little Gombi 4 0 0 0 0 7.6
5 Biu 4 0 0 0 0 7.6
6 Daimaturu 4 0 0 0 0 7.6
7 Potiscum 4 0 0 0 0 7.6
8 Azare 4 0 0 0 0 7.6
9 Dutse 4 1 0 0 0 9.2
10 Jogana 2 2 0 0 0 7.0
65.6
Grand Total - Alternative 1
Cost Estimation of New Transmission Lines required by 2040
150 MVA、
330/132kV
Transformer
60 MVA、
132/33 kV
Transformer
Subtotal I
Subtotal II
387.8
Transmission Line Substation
Overhead Lines
Substations
Alternative 1 Alternative 2No. Project
330 kV
Feeder
132 kV
Feeder
33 kV
Switchgear
Rated
VoltageLength Unit Cost Cost Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
0.0
1 Abuja 15 0 0 0 15 0 0 0 0 43.5
2 Kano 6 0 0 0 6 0 0 0 0 17.4
3 Bernin Kebbi 4 0 0 0 4 0 0 0 0 11.6
4 Ikeja West 2 0 0 0 2 0 0 0 0 5.8
78.3
Cost Estimation of New Reactors and Capacitors required by 2040
Subtotal I
Subtotal II
Grand Total
132 kV
Capacitor
330 kV
Capacitor
11 kV
Switchgear
33 kV
Switchgear
132 kV
Feeder
78.3
Transmission Line Substation
Overhead Lines
Substations
No. Project33 kV
Reactor
33 kV
Capacitor
132 kV
Reactor
330 kV
Feeder
7-108
In the case of a 500-kV super grid, it is assumed that the transmission lines will be Single-Circuit lines with Quad Bison conductors.
In the case of a 750-kV super grid, it is assumed that the transmission lines will be Single-Circuit lines with five-bundle Bison conductors.
Regarding substations, it is assumed that for a 330-kV double busbar system with an auxiliary busbar, a bus coupler will be installed whereas for 500 and 750 kV units, one-and-half circuit-breaker schemes will be installed.
Table 7-10.27, Table 7-10.28 and Table 7-10.29 show the cost estimation for the three voltage levels.
Table 7-10.27 Cost estimation for the 330-kV super grid
Source: JICA Study Team
RatedVoltage
Length Cost per km Total Cost Total Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Ikot Ekpene - Benin 330 300 0.45 135
2 Ikot Ekpene - Makurdi 330 300 0.45 135
3 Benin - New Agbara 330 250 0.45 113
4 Benin - Osogbo 330 160 0.45 72
5 Benin - Ajaokuta 330 300 0.45 135
6 New Agbara - Osogbo 330 160 0.45 72
7 Osogbo - Gwagwalad 330 260 0.45 117
8 Makurdi - Gwagwalad 330 200 0.45 90
9 Makurdi - Ajaokuta 330 200 0.45 90
10 Ajaokuta - Gwagwalad 330 200 0.45 90
11 Gwagwalad - Funtua 330 250 0.45 113
Subtotal I 1,161
1 Ikot Ekpene 9 2 2 25
2 Benin 11 2 2 29
3 Makurdi 11 2 2 29
4 Osogbo 11 2 2 29
5 New Agbara 9 2 2 25
6 Ajaokuta 11 2 2 29
7 Gwagwalad 13 2 2 33
8 Funtua 7 2 2 21
Subtotal II 220
Grand Total
No. Project330 kV
Line
Feeder
330 kV
Transformer
Feeder
330 kV Shunt Reactor
1,381
Cost Estimation of 330 kV Super GridTransmission Lines 変電所
Overhead Lines
Substations
7-109
Table 7-10.28 Cost estimation for the 500-kV super grid
Source: JICA Study Team
Table 7-10.29 Cost estimation for the 750-kV super grid
Source: JICA Study Team
The cost comparison is summarized in Table 7-10.30.
RatedVoltage
Length Cost per km Total Cost Total Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Ikot Ekpene - Benin 500 300 0.28 84
2 Ikot Ekpene - Makurdi 500 300 0.28 84
3 Benin - New Agbara 500 250 0.28 70
4 Benin - Osogbo 500 160 0.28 45
5 Benin - Ajaokuta 500 300 0.28 84
6 New Agbara - Osogbo 500 160 0.28 45
7 Osogbo - Gwagwalad 500 260 0.28 73
8 Makurdi - Gwagwalad 500 200 0.28 56
9 Makurdi - Ajaokuta 500 200 0.28 56
10 Ajaokuta - Gwagwalad 500 200 0.28 56
11 Gwagwalad - Funtua 500 250 0.28 70
Subtotal I 722
1 Ikot Ekpene 6 2 2 2 64
2 Benin 8 2 2 2 72
3 Makurdi 7 2 2 2 68
4 Osogbo 7 2 2 2 68
5 New Agbara 6 2 2 2 64
6 Ajaokuta 7 2 2 2 68
7 Gwagwalad 8 2 2 2 72
8 Funtua 5 2 2 2 60
Subtotal II 533
Grand Total
Cost Estimation of 500 kV Super Grid
Overhead Lines
Substations
No. Project
1,256
Transmission Lines Substations
500kV feeder 330kV feeder
500MVA
500/330 kV
Transformer
500kV
Shunt Reactor
RatedVoltage
Length Cost per km Total Cost Total Cost
(kV) (km) (Million US$/km) (Million US$) (Million US$)
1 Ikot Ekpene - Benin 750 300 0.35 105
2 Ikot Ekpene - Makurdi 750 300 0.35 105
3 Benin - New Agbara 750 250 0.35 88
4 Benin - Osogbo 750 160 0.35 56
5 Benin - Ajaokuta 750 300 0.35 105
6 New Agbara - Osogbo 750 160 0.35 56
7 Osogbo - Gwagwalad 750 260 0.35 91
8 Makurdi - Gwagwalad 750 200 0.35 70
9 Makurdi - Ajaokuta 750 200 0.35 70
10 Ajaokuta - Gwagwalad 750 200 0.35 70
11 Gwagwalad - Funtua 750 250 0.35 88
Subtotal I 903
1 Ikot Ekpene 6 2 2 2 82
2 Benin 8 2 2 2 92
3 Makurdi 7 2 2 2 87
4 Osogbo 7 2 2 2 87
5 New Agbara 6 2 2 2 82
6 Ajaokuta 7 2 2 2 87
7 Gwagwalad 8 2 2 2 92
8 Funtua 5 2 2 2 77
Subtotal II 686
Grand Total
Cost Estimation of 750 kV Super Grid
No. Project
1,589
Transmission Lines Substations
750kV
feeder
330kV
feeder
500MVA
750/330 kV
Transformer
750kV
Shunt Reactor
Overhead Lines
Substations
7-110
Table 7-10.30 Summary of cost comparison
Voltage Level Transmission Lines
(Million US$) Substations
(Million US$) Total
(Million US$)
330 kV 1,161 220 1,381
500 kV 722 533 1,256
750 kV 903 686 1,589
Source: JICA Study Team
A rough cost comparison indicates that the 500-kV super grid will require less investment. However, the cost difference to 330 kV is relatively small. Considering that in terms of technical performance (MVA transmission capacity, losses, impact on under/overvoltages and overloads as well as static security issues) the 330-kV system appears more advantageous, its 10% higher investment cost could be justified.
In view of the above, it is apparent that more detailed studies must confirm the conclusions of this study. It is therefore recommended to have these detailed studies carried out in due course and as soon as possible, before a final decision can be made on the selection of the voltage level (330 or 500 kV) for a future super grid.
The cost for 750 kV is far higher compared to 330 and 500 kV. The transmission capacity of a 330-kV Double-Circuit line and a 500-kV Single-Circuit line are 3,100 and 2,350 MVA respectively, compared to 4,400 MW for a 750-kV Single-Circuit line. The network calculations (Chapter 8), however, have indicated that the transmission capacity of the 330 and 500 kV supergrid systems suffices.
There is no justification for adopting and/or further considering any higher (750 kV) option for the EHV grid, particularly when the implications in cost differences are taken into account, as detailed in Section 8. The higher transmission capacity (4,400 MVA) is not required at this stage and the marginal differences in losses cannot offset the high investment cost required in the planning horizon of this Master Plan.
