(01). sierra leone, apendicies to the SoW.pdf

APPENDIX A Page 1

APPENDIX A : SIERRA LEONE IMPLEMENTING ENTITIES

− Ministry of Energy – The Ministry has the mandate of overseeing policy formulation, planning and coordination.

− Electricity Generation and Transmission Company (EGTC) – EGTC became operational in 2015 following the completion of the unbundling process and is in charge of generation and sale of power to the main distribution and supply entity in the sector. EGTC also manages the high voltage transmission network infrastructure.

− Electricity Distribution and Supply Authority (EDSA) – EDSA became operational in 2015 and is in charge of the low voltage distribution network, and retail sale of grid-based power in the country.

− Electricity and Water Regulatory Commission (EWRC) – The Commission is in charge of technical and economic regulation of the power utilities. The Commission gives licenses, sets electricity rates and ensures service quality for consumers is enhanced through performance standards and monitoring.

− Public-Private Partnership Unit (PPPU) – The PPP Unit was established in 2014 and has the mandate to promote and facilitate private sector transactions in infrastructure in the country.

− Ministry of Finance – The Ministry is a key actor and provides subsidies to both government-owned generation and distribution utilities. Sector deficit is financed by the Ministry through the main government budget. The Ministry also manages the interim collections accounts that seeks to create a platform for financial sustainability in the sector.

− Ministry of the Environment – The ministry provides direct technical and operational support and advice to its departments and agencies on general environmental and climate governance decisions, including for formulating policy, initiating environmental projects, and collating data on environmental performance. It oversees the work of the Environment Protection Agency (EPA), where the Climate Change Secretariat is housed. The Ministry also oversees climate-related functions performed by the Sierra Leone Meteorological Agency (SLMet) where the country’s UNFCCC Focal Point is based.

− Environmental Protection Agency – EPA issues permits and licenses in respect of environmental assessments conducted by public and private sector institutions looking to initiate new projects or improve or expand existing investments. The EPA Act (2008) provides a legal framework for managing the interaction between human environments and environmental resources.

APPENDIX B Page 1

APPENDIX B: INFORMATION ON EXISTING DISTRIBUTION

NETWORK

EXISTING DISTRIBUTION NETWORK IN SIERRA LEONE

The Electricity and Distribution Supply Authority (EDSA) is the single distributor of electricity in the country and manages several isolated distribution networks throughout the districts in all five provinces. It does not, however, operate in all the districts. Its operational areas by province and their access to electricity evaluations are shown respectively in the two tables below:

Table 1 EDSA’s operational areas by province1

1 GoSL-EDSA Due Diligence and Private Sector Participation Strategy Report, 2021.

Table 2 Districts in Sierra Leone with access to electricity1

The distribution network comprises of equipment with voltages ranging from 33 kV to 11 kV and

0.415 kV. The assets are mainly 11 kV overhead lines and underground cables, low voltage lines, transformers with transformation ratios of 33/0.415 kV and 11/0.415 kV.

APPENDIX B Page 2

The existing infrastructure in the distribution system operated by EDSA includes approximately:

— 9 primary switching substations with voltage capacities of between 161/33 kV and 33/11 kV;

— 101 km of 11 kV overhead lines; 176 km of 11 kV underground lines and 33 km of 33 kV lines;

— 297 11 kV transformer units;

— 420 km of 0.415 kV Low Voltage (LV) lines; and

— 930 km of secondary lines servicing customers across Freetown and its environs.

The following figure shows the full transmission and distribution network.

Figure 1 Transmission and distribution network map (existing and planned)

EDSA’s distribution network is classified mainly into primary substation and interconnector assets and distribution assets. The primary substations and interconnector assets include the primary substation transformers, 33 kV overhead lines, 33/11 kV switchgear equipment and transformers and 11 kV interconnectors (overhead lines and underground cables) (GoSL-EDSA DD and PSP Report).

APPENDIX B Page 3

The network is considered weak, inefficient and vulnerable to both climate risks and vandalism.

The main distribution network in Freetown in the Western Area province serves approximately 85,000 customers of EDSA with a peak demand constrained to approximately 74 MW (NRECA Preparation of the Electricity Network Investment Plan – Draft Final Design Report, 2016).

Over the years EDSA’s networks has been upgraded with funding from the World Bank to provide it a capacity of 85 MW however, its capacity remains constrained. Further investments are required to upgrade and densify the system which currently features limited primary substations and overloaded and inefficient equipment including the transformers, poles and ancillary plant. Consequently, the system experiences frequent system outages. The general unreliability of the network is compounded given EDSA lacks the resources and logistics to respond within a reasonable amount of time to the faults.

SYSTEM LOSSES AND NETWORK RELIABILITY IN SIERRA LEONE

The system losses experienced throughout the distribution network are among the key factors contributing to EDSA’s financial distress, with the company unable to independently finance its operational expenses and as such relies heavily on grants and government subsidies. Between the years of 2018 and 2020, EDSA had average system losses of 48.0% compared to an average of 11.7% across low-income Sub-Saharan African countries. EDSA also had average collection losses of about 12% during the same period contributing to total losses over the review period averaging to approximately 60%.

Currently, EDSA management has no system in operation to accurately measure the actual technical losses. Aggregate distribution losses in the past four years, for which data is available has averaged 41% as shown in Figure 1. Load flow analysis done by EDSA indicates that about 40% of all losses are technical losses whilst the remaining are due to poor commercial and billing practices. The key drivers of the technical losses in the distribution network include the congested and overloaded 11 kV transformers in the communities. Preventive maintenance is rarely conducted and there is also limited availability of meters at feeder and distribution transformer levels. The analysis of future losses data during the load flow study will be an important factor in the justification of the Compact.

Figure 2 EDSA Quarterly Distribution System Losses 2018 – 2021 (%)

APPENDIX B Page 4

The commercial losses, however, are caused mainly by illegal abstraction of power, large number of faulty pre-paid meters, shortage of meters, poor billing and collection practices for the 16,462 post-paid consumers, poor technical monitoring and enforcements and the growing number of unserved and unplanned communities that are impatient for the network to be extended for their areas and thus resort to illegal means of tapping power. Acts of theft put additional strain on an already overstretched network which further exacerbates its poor performance and reliability.

Given the unreliability and poor quality of the power supplied, customers or potential customers are either forced to augment or fully circumvent EDSA using costly alternatives, this is especially prevalent amongst commercial users. According to a World Bank report, 70% of firms report owning diesel generators as either a primary source of power or a back-up in the event of blackouts or outages, supplying nearly 50% of their power needs (World Bank, 2021).

In 2020, it was discovered that a significant amount of Le 5.4 billion has been lost by a practice whereby EDSA provides free power tokens to members of the Board of Directors and Management staff. With no system to track and account for how much power each customer had consumed over time (in kW/h and Leones) or the ability for billable customers to acquire the tokens, these had to all be accounted for as collection losses.

The trend of decreasing customers interruptions and average down time on the network is encouraging and will require continued efforts to improve the customers’ quality of service.

The latest EDSA report illustrates the SAIFI (System Average Interruption Frequency Index), SAIDI (System Average Interruption Duration Index) and CAIDI (Customer Average Interruption Duration Index) key performance indicators (KPI) recorded on the network, see Table 3 for details.

Table 3 EDSA outage occurrence and number of customers affected (2017 to June 2021)1

The means to improve the reliability of any electrical network must address 3 types of actions that affect the determining factors of reliability indicators:

— Reduce the frequency of interruptions;

— Reduce the number of clients affected by interruptions;

— Reduce the duration of interruptions.

APPENDIX B Page 5

ELECTRICITY ACCESS IN SIERRA LEONE

Currently, the electricity access rate in Sierra Leone is estimated to be around 23%, one of the lowest in Sub-Saharan Africa as well as among its per capita income peers around the globe.

Moreover, the absolute number of people without any form of grid and off-grid electricity as the population grows, has outpaced the number of connections. A deeper dive into the access rate reveals it is much lower in rural areas with only 4% connected to electricity compared to their counterparts in urban areas with an access rate of 48%. Even in instances in urban areas where there is grid coverage, households and firms face inadequate supply reliability and brownouts are prevalent because of an overloaded and outstretched network. Sierra Leone’s Electricity Sector Reform Roadmap targets universal access to electricity by 2030 in line with the Sustainable Development Goal 7. This would require almost 40,000 new connections a year commencing from 2018 (Sierra Leone’s Electricity Sector Reform Roadmap).

Recent figures as of 2021 reveal the majority of customers with an EDSA connection are located in Freetown or the surrounding communities in the Western Area province.

The following table illustrates EDSA connectivity rates throughout all districts in the country (SLCDU: Increasing Access to Reliable and Affordable Power in Sierra Leone, 2021).

Table 4 Rate of Energy Access in Districts with a Distribution Network1

LOCATION NUMBER OF

HOUSEHOLDS

NUMBER OF HOUSEHOLDS

CONNECTED TO THE GRID ACCESS RATE ESTIMATED

POVERTY RATE

Western Area 321,235 180,219 56% 23.6%

Makeni 105,902 17,306 16% 35.1% Bo 102,723 15,707 15% 41.7%

Kenema 111,734 10,812 10% 37.6% Kono 86,119 4,671 5% 49.3%

Port Loko 111,701 9,712 9% 46.2% Magburaka 86,840 1,962 2% 73.4%

1 Source: EDSA, Statistics Sierra Leone.

For a large percentage of the customers connected, they experience a supply that is intermittent and unreliable. This coupled with low household incomes subsequently contributes to the low average household consumption of electricity. Many households outside of Freetown look to self-generated power for productive activities especially in the agriculture and fisheries production centers.

Interventions are expected to increase the number of connections in the Western Area and other Provincial Districts in which there is an existing distribution network or mini-grid installations.

In the Western Area and Provincial headquarter towns with grid access, access rates vary, as seen in the table below. In addition to the high meter costs, high upfront last-mile connection costs for cables for internal wiring, poles, and other electrical equipment are barriers to connection for poor households. Furthermore, internal wiring has been identified as a major cost driver to access electricity.

APPENDIX B Page 6

Stakeholder consultations during the RCA phase in select communities revealed that low rates of electricity connection are an important contributor to female time poverty due to their social and cultural roles in the household. Given these social and gender dynamics, it is important that Compact interventions do not exacerbate these dynamics.

To this end, interventions will seek to promote connections for vulnerable populations by addressing key cost barriers as described above. Focus groups will be conducted with vulnerable groups (including women) to obtain their views on tariffs (particularly on affordability), and to receive assistance on installation of pre-paid meters, meter measurement, monthly reporting, etc. which will be essential to development of this activity. The challenge of illegal connections will also require further study to better understand this group’s decision-making and impacts to the system.

The cost of a single-phase meter is approximately Le1.35 million, which is more than twice the minimum monthly wage in the country of Le600,000. The cost of a three-phase meter is even more expensive at Le 2.6 million which would typically be used by small-scale household enterprises. Thus, beyond the tariff, high connection costs serve as an impediment to connection which also exacerbates the issue of illegal connections undermining the financial sustainability of EDSA.

APPENDIX C Page 1

APPENDIX C: EXISTING TECHNICAL FINANCIAL PARTNER FUNDED

DISTRIBUTION PROJECTS

The World Bank under the Energy Supply and Utility Reform Project (ESURP) is planning to make investments in the majority of the 77 unserved areas in the Western Area that serve communities with a population of 629,587 (approximately 108,589 households). This compact will therefore support expanding the network to the communities in the Western Area that will not be covered by World Bank investments.

The ESURP project will serve the following villages and communities in the Western Area through the installation of the distribution network infrastructure:

Communities on Aberdeen Substation

Fannah Factory Thomas Street

Aberdeen Village Grassfield Tombo

Aberdeen Guma Pump Health Center Upper Sima Town

Communities on Jui Substation

Joe Town 1 Waterloo 55 Market

Charlotte Joe Town 2 Waterloo 55 no.2 lorry park

Hastings Wharf Joe Town Old Road Waterloo Benguima RD 2

Looking Town/KINGSTON John Thorpe, Rokel White Mosque

Madina Community Kabba Street White Stone

Mamboreh Kanneh Street Communities on Pennisular Road (EXISTING LINE)

Mamboreh, Allen Town Kissi Town Airfield Banga Farm, Goderich

Mongegba Kissy town Baw Baw Village Sussex

Mothaim Kondoloh Guma and environs

New York Garage Limba Lakka

Rogbangba Liverpool Steet Mambo

Wantic Mammy Eku Street 2 Mambo Upper

Communities on Waterloo Substation

Mano Corner Number 2

4 Milie Maroute Pogodon

BANGA FARM NASSIT Road Sussex

Banga Farm 1 Newton Upper Sussex

Banga Farm 2 Police Station Communities on Regent Existing Line

Bangura Junction PSS School Bathurst

Binta Town REC school Gloucester 1

Cole Street Lumpa 3 Samakar Drive-joe town africel Gloucester 2

Cole Town Samuel Town Junction Regent Village

Devil Hole Soja Town

APPENDIX C Page 2

The scope of works in the Western Area contains the following network upgrades.

Construction of new 161/33 kV and 33/11 kV Substations:

— Freetown 161/33 kV, 35/40 MVA Substation including all electrical plant.

— 33/11 kV, 20/26 MVA Substations including all electrical plant.

— Aberdeen, Cline Town and Falconbridge AIS Single Busbar Substations;

— Jui and Waterloo AIS Double Busbar Substations.

Construction of 33 kV lines:

— New 33 kV line from Freetown 161 S/S to 33/11 kV Aberdeen S/S:

— The line shall be in general constructed as single circuit 265 mm² AAC Conductor and 32 fiber OPGW on Poles. Partially where site conditions dictate line will be constructed with 300 mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 7 km.

— New 33kV line from Freetown 161 S/S to 33/11 kV Falcon Bridge S/S:

— The line shall be in general constructed as double circuit 265 mm² AAC Conductor and 32 fiber OPGW on double circuit Poles. Partially where site conditions dictate line will be constructed with 300mm² 33kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 2.5 km

— New 33 kV line from 33/11 kV Falcon Bridge S/S to 33/11 kV Cline Town S/S:

— The line shall be in general constructed as double circuit 265 mm² AAC Conductor and 32 fiber OPGW on Poles. Partially where site conditions dictate line will be constructed with 300 mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 3 km

— New 33 kV line from 33/11 kV Cline Town S/S to 33/11 kV Blackhall Road S/S:

— The line shall be in general constructed as double circuit 265 mm² AAC Conductor and 32 fiber OPGW on Poles. Partially where site conditions dictate line will be constructed with 300 mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 1.2 km

— New 33 kV line from 33/11 kV Jui S/S to 33/11 kV Regent S/S:

— The line shall be in general constructed as single circuit 265 mm² AAC Conductor and 32 fiber OPGW on double circuit Poles. Partially where site conditions dictate line will be constructed with 300 mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 13.5 km

— New 33 kV line from 33/11 kV Wellington S/S to 33/11 kV Jui S/S:

— The line shall be in general constructed as double circuit 265 mm² AAC Conductor and 32 fiber OPGW on steel lattice towers. Partially where site conditions dictate line will be constructed with 30 0mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 6.5 km

APPENDIX C Page 3

— New 33 kV line from 33/11 kV Jui S/S to 33/11 kV Waterloo S/S:

— The line shall be in general constructed as double circuit 265 mm² AAC Conductor and 32 fiber OPGW on steal lattice towers. Partially where site conditions dictate line will be constructed with 300 mm² 33 kV, Sigle core XLPE/SWA/PVC Cu underground cable and 32 fiber optic cable. The approximate route length is 16.5 km

— Second Circuit of 33 kV line from 33/11k V Blackhall Road S/S to 33/11 kV Wellington S/S:

— Stringing of second circuit of 33 kV line with 265 mm² AAC Conductor and 32 fiber OPGW on existing slim steel lattice towers. The approximate route length is 8.5 km.

— Upgrade of existing 33 kV lines between Freetown 161, Blackhall Road and Wilberforce Substations:

— The works involve the upgrade of existing network of double circuit 2x (3(1x150 mm² ACSR)) Lattice tower lines to Double Circuit 2x (3(1x265 mm² AAC)). The contractor shall be required to do an analysis/assessment of the strength of the existing towers to carry the double circuit 265AAC. If it is determined that the strength in inadequate, then a re-design of the tower would have to be carried out by Contractor to determine which and how new members would be introduced to reinforce towers. If it is determined that existing foundations can withstand increase load the Contractor shall be required to reinforce the existing towers to ensure their capability to carry the heavier conductors.

However, if it is determined that existing foundations cannot withstand increased load, then it wouldn’t be possible to upgrade existing 33 kV lines.

The ESURP project also supports network expansion in other areas of the country to provide new and improved electricity services to nine major towns and surrounding communities by capitalizing on the transmission lines under construction and the availability of electricity through imports over the CLSG interconnection. More specifically, the project will include:

— Construction of a single circuit 33 kV distribution line of about 35 km, including a 15 MVA 33/11 kV transformer, connecting the distribution network in Kabala with the 225/33 kV Fadugu substation of the CLSG line.

— Construction of a single circuit 66 kV sub-transmission line of about 100 km, including a 66/33/11 kV transformer of 20 MVA, connecting the distribution network in Kailahun with the 225/66 kV Kenema substation of the CLSG line.

— Design and construction of a 33 kV line of about 25 km connecting the distribution network in Pujehun with the CLSG line.

— Feasibility study and preliminary design of the single circuit 33 kV distribution line of about 55 km, including a 15 MVA 33/11 kV transformer, connecting the distribution network in Kambia with the 225/33 kV Port Loko substation of the double circuit 225 kV Fadugu- Freetown line.

JAPANESE INTERNATIONAL CORPORATION AGENCY (JICA) PROJECT

The Japanese International Corporation Agency (JICA) funded project along the Freetown Penninsular aims to rehabilitate the distribution lines between key substations. The scope of the work under the project is illustrated in Figure 1.

APPENDIX C Page 4

1. 33 kV Distribution Line between Goderich substation and New Tombo substation:

New York and Tombo substations will be energized by constructing new 33 kV distribution line using conductor AAC-265 mm2 overhead line. The overhead line length is approx.

44.9 km. Support structure of the 33 kV overhead distribution line shall be steel pole types, refer to the drawing DL-2.

2. 1 1kV Distribution Line from York substation:

12 Secondary substations will be energized by constructing new 11 kV distribution line using conductor AAC-150mm2 overhead line, refer to attached drawing DL-1. The overhead line length is approx. 35.5km. Support structure of the 11 kV overhead distribution line shall be steel pole types, refer to the drawing DL-2.

3. 11 kV Distribution Line from Tombo substation:

16 Secondary substations will be energized by constructing new 11 kV distribution line using conductor AAC-150 mm2 overhead line, refer to attached drawing DL-1. The overhead line length is approx. 12.6 km. Support structure of the 11 kV overhead distribution line shall be steel pole types, refer to the drawing DL-2.

Figure 1 JICA funded Projects

APPENDIX C Page 5

BO-KENEMA PROVINCIAL - CLSG PROJECT

The Bo-Kenema Rehabilitation and Extension Project/ CLSG Interconnection Project funded in part by the AfDB will install new electrical infrastructure that links the Southern and Eastern Provinces. There are four lots by individual contractors containing differing scope of works.

1. LOT 1 (T&D Power & Capital Electech & T&D Technology JV) will undertake the Design, Supply, Installation and commissioning of two new primary substations and rehabilitation of two (2) city centers 33/11 kV substations and 33/11 kV substations between Bo and Kenema.

— 2 x 66/33/11 kV substations to be constructed;

— 2 x 33/11 kV Substations to be constructed;

— 2 x 33/11 kV Substations to be rehabilitated;

— 2 x 33/11 kV transformer stations to be installed.

2. LOT 2 (SINOTEC & GTSCC JV) will undertake the Design, Supply, Installation and Commissioning of one double circuit 66 kV overhead transmission line between Bo and Kenema and rehabilitation of 11 kV and 0.4 kV distribution networks.

— Length of distribution lines to be constructed (km):

— 66 kV double circuit = 70.6;

— 33 kV double circuit = 20.3;

— 33 kV Single circuit = 58.6;

— 11 kV Single Circuit = 212.0;

— 0.4 kV (Low Voltage) = 816.0.

— Transformers to be installed:

— 33/0.4 kV = 25 Nos;

— 11/0.4 kV = 176 Nos.

3. LOT 3 (Shenzhen Clou Electronics Company Limited) will undertake the Supply, Installation and Commissioning of Split Prepaid Meters.

— Number of Single Phase Split Prepaid Energy Meters to be installed = 50,000 pcs;

— Number of Three Phase Split Prepaid Energy Meters to be installed = 500 pcs.

4. Design, Supply, Installation, and Commissioning of 39 towns and villages under the CLSG 225/33 kV line using the shield wire (T&D Power Solution Limited & Shirdi Sai Electricals Limited JV).

— Design, Supply, Installation and Commissioning of Medium and Low Voltage Power Lines and Service Connections including Prepayment Meters and Street Light in 39 Villages in Sierra Leone.

APPENDIX D Page 1

APPENDIX D: INFORMATION ON EXISTING GENERATION

Sierra Leone's installed energy capacity is primarily based on hydropower with the recent addition of Heavy Fuel and Gas generation. Bumbuna I (50 MW) provides half of the total energy consumption of the country while the other hydro power plants Goma (6 MW), Charlotte and Makalie represent a combined (3 MW) capacity of 10 MW. A total of 50 MW of HFO (Heavy fuel oil) or diesel is installed for peak power demand. Importation of power (CLSG WAPP CLSG Interconnector) and Natural Gas Power plant such as recent installation of Karpowership will provide energy during the transition for the installation of renewable energy. Sierra Leone’s energy system includes about 6 MW of mini grid systems.

While installed capacity is informative, the ongoing operations and maintenance of these power plants is not optimal. Table 1 below highlights the contrast between installed and available capacity. Rehabilitation and upgrades are necessary for many of the existing assets to perform as originally rated.

Electricity generation by source, source Final IRP 2021

Figure 1 Electricity capacity by source, source Threshold Final IRP 2021

Figure 2 Power plants in operation (extract from P.Habay SL IRP, 2020)

Biomass

Bumbuna

SHPP

HFO

Imports

SPP

ENERGY PRODUCTION

Biomass

HFO

Karpowerhip Diesel

SHPP

Bumbuna

WPPSPP

POWER CAPACITY

INSTALLED

APPENDIX D Page 2

Table 1 Installed capacity of Sierra Leone

Station Unit

Installed Capacity

(MW)

Available Capacity

(MW) Conditions/Remarks Bumbuna Hydro 1A 25 25 Good

1B 25 25 Good Goma Hydro Unit 1 1,5 1,5 Good

Unit 2 1,5 1,5 Good Unit 3 1,5 0 Out of service Unit 4 1,5 0 Out of service

Makalie Hydro 0,5 0,5 Good Bankasoka Hydro 2,5 2,5 Good Port Loko Diesel Perkins 0,44 0,44 to be confirmed Charlotte Hydro 2,2 2,2 Good Solar Park Freetown 6,0 0,0 Yet to be commisssioned Kingtom HFO Nigata 7 5,0 0 Major maintenance required - Reserve

Nigata 8 5,0 0 Major maintenance required - Reserve Blackhall Road HFO Wartisla 1 8,2 0 Major maintenance required - Reserve

Wartisla 2 8,2 0 Major maintenance required - Reserve Bo-Diesel Cat 1 1,28 0 Out of service

MTU 1 1,6 0 Broken down due to Turbocharger MTU 2 3,0 1,2 Fair MTU 3 3,0 1,2 Fair GH Cat 1,6 1,4 Fair Cat 3 1 0 Cannibalized

Makeni Diesel Cat 1 1,28 0,0 Major maintenance required Perkins 1 1,6 0,0 Out of service Perkins 2 1,6 0,0 Out of service Perkins GH 1,2 1,0 Fair Cat GH 1,6 1,3 Fair

Lungi Diesel Man 1 2,0 1,8 Fair Man 2 2,0 0 Out of service, major maintenance required Man 3 2,0 0 Out of service, major maintenance required MTU 1 0,64 0 Out of service, major maintenance required MTU 2 0,64 0,5 Fair MTU 3 0,64 0,5 Fair

Lunsar Diesel Perkins 1 1,06 0,0 Out of service, major maintenance required Perkins 2 0,45 0,4

Magburaka Diesel Perkins 1 0,5 0,4 Fair Perkins 2 0,5 0,4 Fair

Kono Diesel Man 1 3,00 0 Yet to be commissioned Man 2 3,00 2,7 MTU 1 2,00 0,0 Out of service, major maintenance required

MTU 2 2,00 2,0

TOTAL 133,2 73,4

APPENDIX D Page 3

As far as the Compact is concerned, MCC has decided to focus on investments on generation power that will ensure security and cost effectiveness of electricity supply and can be implemented within a 5-year timeframe of funding. Given this time constraint, MCC will primarily focus on rehabilitation and upgrade projects for hydro power plants. Moreover, the analysis of the best energy mix to manage solar intermittency and hydro seasonality will be considered.

GOMA HYDRO PLANT HISTORY

Goma Hydroelectric power plant is situated in the sub-catchment of Dodo in the Eastern province. The dam is located on a tributary of Sewa River. A MCC consultant conducted an initial site assessment in March, 2022 and returned with these findings.

The plant was initially built in 1986 with 4 units of 1 MW.

In 2006 the plant was flooded as a result of a test on the electrical line, during which there was a flashover and a short circuit, followed by an overspeed on one machine. As a result, the pressure valve failed. Three machines could not continue to operate.

In 2007, it was decided to upgrade the plant with 4 Horizontal Francis machines of 1.5 MW each (supplier HUNNING China). After only two years of operation, unit 4 developed excessive bearing vibration, and it was curtailed to 1 MW output.

In 2013 a contract was signed with the manufacturer to dismantle the machine, realign the shaft, and modify the foundation, but the problem of unit 4 was not solved and operation continued at 500 kW output due to the level of vibration.

In 2014, unit 2 was lost. Two units tripped at the same time and the staff did not use automatic control, they operated manually. As a result, the operator was able to stop only one unit and there were major damages to the rotor of Unit 2.

In 2015, a Chinese manufacturer representative came for the maintenance and repair of unit 1, 2 and 4. They tried without success to improve the quality of the foundation of unit 4 and could not repair unit 2. They only succeeded to get unit 1 back online.

In 2018, there was an exciter fault on unit 3, it was replaced by a new exciter and unit 3 could resume operation up to 0.71 MW.

As of today, only unit 1 can be operated up to 1.5 MW, and unit 3 to 0.71 MW. Operators have not noticed any problem during the partial load operation of the Francis Turbine of unit 3, but partial load operation is generally not recommended.

In Sierra Leone, water resources are highly seasonal: the dry season starts in February and finishes in June with a minimum flow in March and April. This seasonality affects the operation as the there is limited water in the Goma reservoir during the dry season to generate power.

APPENDIX D Page 4

Goma power plant is owned and operated by EGTC. There are 28 workers for maintenance and operation of the station. Most of them live in the workers’ dwellings close to the power station.

The dwellings are in poor condition and need to be rebuilt including the right level of sanitary condition.

The length of the upstream river is 33.6 km. It seems that there is artisanal mining activity and as a consequence, deforestation of river banks and silt sediment build-up in the river. This plant was initially constructed in 1986 as four units rated at 1 MW. An upgrade was funded in 2007 to bring the plant to 4 units x 1.5 MW for a total maximum capacity of 6 MW. Unfortunately, through a series of events, the site now operates only with Unit 1 at 1.5 MW and Unit 3 at

0.71 MW. The other 2 turbines are offline.

APPENDIX D Page 5

Main Characteristics (according to the document transmitted by the responsible person on site):

— Gravity dam:

— Elevation of the overflow dam crest at 102 m (for manual level reading, 101.78 is considered as the overflow level);

— Elevation of the earth dam crest 107 m;

— Concrete dam length 45.5 m including 12.5 m for the sluice gate and the intake.

— Reservoir:

— Total capacity 1 900 000 m3;

— Effective capacity 1320 000 m3;

— Mean annual discharge flow 10.5 m3/s;

APPENDIX D Page 6

— Discharge during 2% of the time during flash flood: 420 m3/s;

— Normal water level: 102 m.

— Gates:

— Radial gate: out of order since 2009;

— Intake gate: operated manually and use only for maintenance.

— Penstock:

— Open air (above ground) penstock, several areas of leakage;

— Length: 754.08 m;

— Diameter: 1.71 m;

— Surge tank location 23.7 m from the power station with internal diameter of 4 m, height

25.6 m above the ground surface.

— Power plant:

— 4 Horizontal Francis Turbine 1596 kW, design head 66.4 m @ 2.82 m3/s, speed

1000 rpm;

— Main valve: 0.8 m diameter;

— Generator: 1765 kVA, 6.3 kV; 161.7 A, frequency 50 Hz, power factor 0.85;

— Excitation voltage 54 V, current 268 A.

— Transmission system:

— Main generator step-up transformers: 2x2500 KVA (Tian Jin transformer; Co)

— Line 33.3 kV with structural galvanised steel towers;

— 58 km going to Kenema substation and 69.8 km line from Kenema to Bo.

APPENDIX D Page 7

BUMBUNA HYDRO PLANT (EXISTING AND PROPOSED PROJECTS)

OBSERVATIONS:

1. Existing Generation Station (GS), Proposed Bumbuna II Project and Bumbuna 1 expansion and upgrade:

Bumbuna I GS exists and includes:

— A reservoir of 445 Mm3 Bumbuna;

— A power station with 2 x 25 MW Francis turbine (Head of 47-80 m);

— Substation with step-up transformer and 161 kV transmission line to Freetown.

Project Bumbuna II will comprise:

— A new reservoir: Yiben (1.5 Bm3, to be confirmed);

— A power station: Yiben with 2 x 27.4 MW Francis turbine, at the bottom of the Yiben Dam;

— A new powerhouse at Bumbuna I Expansion with 2 x 42.15 MW Francis turbine (net Head

112 m) located downstream from the existing Bumbuna I powerhouse; the intake will be located at the existing Bumbuna dam with a new tunnel and penstock;

— An ecological flow power station with 3.6 MW at Bumbuna dam.

For this project, a PPA has already been signed by the government with Joule Bumbuna Limited.

Proposed project Bumbuna 1 upgrade includes:

— One or two additional T/G machines in the existing powerhouse of Bumbuna I for a total power of 50 MW.

There is provision with an existing tunnel and an intake for these additional machines. The detail of the work to perform is defined in annex 1.

APPENDIX D Page 8

2. Available water flow condition:

River yearly average flow ranges between 100 and 140 m3/s.

Based on data for monthly mean flow, the wet season flow can go up to 450 m3/s while it is nearly zero for one or two months during the dry season.

The two following graphs were extracted from the Threshold Final IRP Sierra Leone. It provides an indication of the variability of annual mean flow from 1920 to 1980 with a median value of 120 m3/s while the second graph shows variability on a monthly basis with the maximum of 450 m3/s in September-October and a minimum in March-April.

Figure 3 Bumbuna annual mean flow (Threshold Final IRP Sierra Leone)

APPENDIX D Page 9

Figure 4 Bumbuna monthly mean flow (Threshold Final IRP Sierra Leone)

The rainfall measurement performed from 2008 to 2021 (presented with the graph below) confirms the large seasonal dependency, and some variability between the years There is none or nearly no rain falls from December to March, and significant rain from July to October.

Figure 5 Bumbuna rain fall (Bumbuna O&M Report oct2021)

3. Current Bumbuna operation:

MANAGEMENT OF RESERVOIR LEVEL AND WATER FLOW

Bumbuna 1 GS operation depends on the high seasonal variation of the river flow. The Figure 6 shows the typical variation along the year of water flow and level of the reservoir. In January the reservoir inflow reduces substantially and the reservoir empties. The flow reaches a minimum between February and April while, in June, reservoir fills up and the maximum level is reached

APPENDIX D Page 10 at the end of July. It can be observed that, from July to December, most of the surplus water is spilled while water flow going through the turbines is almost constant.

Figure 6 Bumbuna rain year 2015 - Variation of the reservoir level, the inflow and outflow and the turbine discharge

GENERATING STATION OPERATION

There are 3 modes of operation:

— Dry season, from February to May: The river flow is low or nearly zero and only one machine is operating. The level of the reservoir is decreasing down to 210 m asl (above sea level); and consequently, the head is decreasing i.e. power output is reduced. The discharge is around 25 m3/s. When the level of the reservoir is lower than 210 m, the machines are stopped; only the ecological flow of 6 m3/s is spilled in the river. The capacity factor (% of maximum plant power used on average during the period) for the year 2014 to 2016 was between 20% to 35% of generator rated power. This is illustrated by graphs of Figure 7 and Figure 8.

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2015 FLOW AND WATER LEVEL

Qoutflow (m3/s) Qinflow (m3/s) m

Reservoir level mFlow m3/s

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Figure 7 Bumbuna rain year 2015 - Variation of the inflow and outflow during the dry season

— Intermediate season, January, June and July. In January, river flow and reservoir level starts decreasing. Starting in June, the flow resumes, and the reservoir is filled up to the level of 238 m. Two machines are operating and the flow is approximatively 50 m3/s. During this period, the energy produced is not at the maximum.

— During the rainy season, from August to December, the reservoir is full and level is between 238 m and 241.25 m. The two machines operate continuously at around 50 m3/s or more.

Figure 9 shows the monthly production; in 2021, the production is nearly at the maximum possible from August to December. If level of the dam become higher than 241.25 m, the machines are stopped.

Figure 8 Bumbuna: year 2015; turbine discharge

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PRODUCTION:

Figure 9 Bumbuna monthly average production

4. Operating scenario of Bumbuna I Upgrade without Bumbuna II project:

The upgrade involves adding two machines to the existing powerhouse.

During the dry season, from January 15th to June 15th (in case of year 2015), only one machine is normally in operation in the power plant for an average power of 20 MW. There will be no possible additional power due to lack of water and operating condition, Bumbuna upgrade Turbine/Generator (T/G) will not produce power during this period.

There can be of interest not valued today if the power plant is used for peak load: production of 80 MW for 6 hours a day instead of an average of 20 MW continuously throughout the day. This operation mode would not require more water flow but special T/G design features to accommodate for peaking.

During the wet season (August to December), there would be enough water flow to operate the additional 50 MW but it would still be necessary to spill water.

During the intermediate season, in January when the level of reservoir is decreasing, there would be no additional production, while in July most probably 4 machines could operate to provide additional power before the complete filling of the reservoir.

The additional energy available thanks to the upgrade would be 180 000 MWh (5 months at 50 MW), which represents a yearly increase of +75% over the energy produced in 2021. It would also be recommended to specify T/G machine with a lower operating range in term of head in order to increase the global efficiency, as Bumbuna upgrade T/G would be used only during the wet season when the reservoir is full.

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The Capex should be relatively low considering the provision made to the dam and the tunnel as well as the construction timeframe.

Figure 10 Bumbuna simulation of monthly average production with and without

Bumbuna upgrade

5. Operating scenario of Bumbuna I with Upgrade and Expansion projects:

As part of the Bumbuna II project, a new power station called Bumbuna I Expansion is contemplated. The intake would be from the Bumbuna I reservoir. The powerhouse would be located at a lower level than the existing powerhouse of Bumbuna I such that, with a higher net head of 112 m, the flow required would be 41 m3/s per unit for a power output of 84 MW for two units.

Operating conditions between Bumbuna extension, existing Bumbuna and Bumbuna upgrade will be linked.

The average value of the flow available in Bumbuna is between 100 to 140 m3/s on yearly basis.

— The rated flow for Bumbuna expansion would be 82 m3/s. An average value of 65 m3/s seems reasonable on a yearly basis.

— The current operation of Bumbuna 1 requires 50 m3/s for two machines up to 65 m3/s for the total power out available of 50 MW.

— The operation of Bumbuna 1 upgrade T/G would be the same as for the existing machines.

Therefore, it would not be possible to use during the whole year the 6 machines installed in Bumbuna 1 (combining existing upgrade and expansion).

Bumbuna 2 project scope of works includes the Yiben reservoir with a capacity of storage of 1500 billions m3. The dead part of this reservoir is not available and consideration should be given to the level variation that dictates the power output of the T/G machines.

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APPENDIX D Page 14

A draft simulation based on:

— An available Yiben reservoir capacity of 1100 billions m3 (75% of the total reservoir capacity);

— A constant maximum level of the existing Bumbuna reservoir;

— Priority for dispatch given for the operation of Bumbuna Expansion based on an average of 80% of 84 MW on yearly basis;

— The second priority of dispatch given to existing Bumbuna 1 T/G and the third to Bumbuna upgrade T/G.

Shows:

— The global energy production available for Bumbuna 1 (expansion, existing and upgrade) overall would be approximately 900 000 MWh per year (as opposed to the 235 000 MWh produced in 2021 in Existing Bumbuna);

— On a yearly basis, the global energy production for the existing Bumbuna 1 powerhouse would not change;

— The production of Bumbuna upgrade will decrease from 180 000 MWh/year without Bumbuna expansion to approximately 120 000 MWh /year.

Previous analysis is based on the objective to provide maximum continuous power to the grid.

But power flexibility can also be an advantage for the grid.

The graph 8 extract from the Threshold shows the typical hourly tendency of the electricity demand, typically from 35 MW to 55 MW, the peak starts at 6 pm and represents an increase of 50%. This effect will be amplified if Sierra Leone implement solar power as the availability of solar power declines at 6 pm while demand peak appear. The global overcapacity of Bumbuna 1 may play an important role in this grid regulation, some machines could operate during the peak to stabilize the grid.

Figure 11 Hourly load profile (Threshold Final IRP Sierra Leone)

APPENDIX D Page 15

6. Interaction and priorities to be considered:

— Operating mode of Bumbuna I existing, upgrade and expansion are dependent on the available water in Bumbuna I reservoir resulting from the operation of Yiben power plant and Yiben reservoir management.

— Operation of the three powerhouses is linked.

— The management of Bumbuna 1 reservoir will have to be defined taking into consideration the operation of the six machines.

— The production of the powerhouse upgrade and extension will be completely linked.

CONCLUSION AND RECOMMENDATIONS

— Even though Bumbuna 1 upgrade represents over capacity at the time Bumbuna II project will be commissioned considering the additional powerhouse (Bumbuna expansion) that will be built, the upgrade needs to be explored and supported by economic analysis:

— It can provide 180 000 MWh /year mainly during the wet season in a relatively short timeframe (3 to 5 years);

— The Capex will be cost competitive as it is an extension with provision for upgrade;

— It will provide an additional 100 000 to 140 000 MWh after the commissioning of

Bumbuna II.

— There are three options for the selection of upgraded machines characteristics:

— Same as existing (main advantage will be the delivery time);

— One machine of 50 MW (advantage in term of cost but less operation flexibility);

— Machines design for a lower head variation to optimise efficiency;

— Two new machines, designed to accommodate flexible operation for an efficient and secure coupling with intermittent renewable power.

— An agreement on the future operating mode of Bumbuna II project powerhouses will be needed (valley control)

— Specific National SCADA/EMS dispatch and setpoint rules will be defined to optimise the seasonal nature of the operation with the network demand.

— The possibility to integrate solar panel (floating on the reservoir or not) could be investigated to increase power available using hydro storage capability for regulation.

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ANNEX 1

Bumbuna existing: Space are prepared for additional 50 MW

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APPENDIX E Page 1

APPENDIX E: TRAFFICKING IN PERONS (TIP) – BACKGROUND

INFORMATION

According to US Department of State’s Trafficking in Persons Report 2021, Sierra Leone is ranked as a Tier 2 country. Countries in Tier 2 ranking are those whose governments do not fully meet the Trafficking Victims Protection Act (TVPA) 2000 minimum standards for the elimination of Trafficking in Persons but are making significant efforts to bring themselves into compliance with those standards. According to the referenced report the Government of Sierra Leone (GoSL) demonstrated overall increased effort compared to the previous reporting period.

Some of the GoSL efforts include significantly increasing investigations and prosecutions, allocating funds to an NGO for protective services, and adopting a new anti-trafficking national action plan. Areas where the Government did not meet the minimum standards include, but are not limited to, shelter and services for male victims that remain inadequate and limited to Freetown, lack of investigation of past corruption reports and officials remaining complicit in trafficking crimes, etc.

These findings shed light on the TIP profile in Sierra Leone. The report stated that traffickers exploit and transport victims, mainly from rural provinces to urban and mining centers for sex trafficking and exploitation for forced labor in domestic services, artisanal diamond and granite mining. In addition, traffickers exploit victims in fishing and agriculture, and sex trafficking or forced labor through customary practices, such as forced marriage. Child sex trafficking is a serious problem. The report also stated that traffickers move women, men, youth and children across borders in West Africa as well as to the Middle East. MCC has a zero-tolerance policy on TIP and full compliance with its Counter Trafficking in Persons Policy (2021) MCC’s C-TIP Policy (Oct. 2021) is a requirement for all parties involved in MCC funded projects.

Furthermore, in 2012, MCC formally adopted the International Finance Corporation’s (IFC) Performance Standards (PS) on Environmental and Social Sustainability as part of the MCC Environmental Guidelines. IFC PS -2 incorporates the United Nations (UN) Guiding Principles on Business and Human Rights and other International Labor Organization (ILO) Conventions and recognizes that “the pursuit of economic growth through employment creation and income generation should be accompanied by protection of the fundamental rights of workers.” There are substantial synergies between IFC PS 2 and the scope MCC Counter Trafficking in Persons Policy, especially in terms of labor exploitation. The objectives of PS -2 include:

— Promotion of compliance with national employment and labor laws;

— Protection of workers, including vulnerable categories of workers such as children, migrant workers, workers engaged by third parties, and workers in the client’s supply chain; and

— Avoidance of the use of forced labor.

Other components of the IFC Performance Standards that are relevant to MCC’s approach to TIP include IFC PS 1: Assessment and Management of Environmental and Social Risks and Impacts, IFC PS 4: Community Health, Safety and Security, and IFC PS 5: Land Acquisition and Involuntary Resettlement. When host country laws and regulations differ from the levels and measures presented in the MCC Environmental Guidelines, projects are expected to achieve whichever levels and measures are more stringent. MCC’s Gender Policy is also relevant to https://www.mcc.gov/resources/doc-pdf/policy-counter-trafficking-in-persons https://www.mcc.gov/resources/doc-pdf/policy-counter-trafficking-in-persons

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MCC’s approach to countering trafficking in persons. It requires that activities funded by MCC specifically address social and gender inequalities, both to ensure opportunities for the participation and benefit of women and vulnerable groups and to avoid causing negative social and gender impacts. While trafficking impacts men, women, boys, and girls, women and children are particularly vulnerable.

MCC’s Counter Trafficking in Persons Policy (C-TIP Policy)

MCC’s uses the TIP definition from the TVPA:

Severe forms of trafficking in persons:

— Sex trafficking in which a commercial sex act is induced by force, fraud, or coercion, or in which the person induced to perform such act has not attained 18 years of age; or

— The recruitment, harboring, transportation, provision, or obtaining of a person for labor of services, through the use of force, fraud, or coercion for the purpose of subjection to involuntary servitude, peonage, debt bondage, or slavery.”

Additional supporting terms from the U.S Department of State Office to Monitor and Compact TIP includes, bonded labor or debt bondage, child sex trafficking, domestic servitude, forced labor and sex trafficking.

APPENDIX F Page 1

APPENDIX F: GEOGRAPHICAL SUBMISSION REQUIREMENTS

GEOGRAPHIC DATA DEFINITION

The Contractor may be required to submit geographic data obtained or generated under this contract. The Contractor may also need to perform field surveys or record observations from field visits to the project location. Please reference the (A) Geographic Data File Requirements section for more information on appropriate data formats and methods for submitting geographic data files to the [MCC or MCA]. Additional guidelines for (B) GIS data visualization, compatibility with MCC’s existing due diligence (C) geospatial web-platforms, and (D) field data collection are also outlined below.

(A) Geographic Data File Requirements

Geographic data files may include, but are not limited to:

1. Satellite/aerial/drone imagery;

2.…