This page lists power stations in Ethiopia, both integrated with the national power grid but also isolated ones. Due to the quickly developing demand for electricity in Ethiopia, operational power plants are listed as well as those under construction and also proposed ones likely to be built within a number of years.
See main article: Energy in Ethiopia. Due to favorable conditions in Ethiopia (water power, wind power, photovoltaics, geothermal energy) for power generation, the country avoids exploiting and importing fossil fuels as much as possible. As Ethiopia is a quickly developing country, the demand for electricity grows by 30% each year. This results in a very dynamic situation with many power plants being planned simultaneously or being under construction.
In the year 2014 Ethiopia had – according to an estimation of the CIA – an annual electricity production of 9.5 TWh and was at position 101 worldwide. The total installed capacity was ~2,4 GWe (position 104). In July 2017, the country had a total installed capacity of ~4.3 GWe and an annual electricity production of 12.5 TWh. In 2017, hydropower has the largest share with 89.5% of the installed capacity and with 93,4% of the annual electricity production.
The lists provide all power plants within the Ethiopian national power grid (Ethiopian InterConnected System (ICS)). In addition, listed are all ICS power plants under construction, under rehabilitation or in stand-by-mode. And finally it lists all ICS power plants in planning stage which are foreseen (or are given chances) to be going into the construction stage until 2025. All ICS power plants are administered by Ethiopian Electric Power (EEP), the state-owned enterprise for electricity production. The lists are up-to-date as of September 2017.
Also, an incomplete selection of operational off-grid power plants (Self-Contained Systems (SCS)) is provided by additional lists. Some of the SCS power stations are private power stations, others are administered by regional or local administrations. The SCS power stations are either small hydropower or Diesel generators usually with an installed capacity <1 MW each. The total power generation is 6.2 MWe for small hydropower SCS, while SCS Diesel generators make up a total of 20.65 MWe. There are also around 40,000 small off-grid Solar Home Systems (including slightly larger Solar Institutional Systems) for remote rural areas of Ethiopia with a total installed capacity of another 4 MWe. All SCS power plants combined have an installed capacity of around 30 MWe.
Provided is most often the nameplate capacity but not the effective capacity of the power plants. Most lists also provide the annual capacity factor for the power plants, which are the actual numbers for the Ethiopian fiscal year 2016/2017 (ended in July 2017). For construction projects or planned power plants, the expected capacity factor is given in brackets. With the installed capacity known and the capacity factor given, one could do the math (not done on this page) and derive the actual (or planned) annual energy production (in GWh).
The lists arrived from a survey of newspapers, World Bank documents and reports, including the EEP itself. The main documents for the power plants in planning stage on this page came from the Ethiopian Power System Expansion Master Plan Study, EEP 2014 and from the Ethiopian Geothermal Power System Master Plan, JICA 2015.
A complete list for all Ethiopian ICS power plants was published by the Ethiopian Electric Power (EEP) in September 2017.
| ICS Power plant | Coordinates | River | Drainage Basin | Installed capacity (MWe) | Capacity factor (2016/17) | Total reservoir size [km<sup>3</sup>] | Dam height [m] run-of-river | Irrigation area [km<sup>2</sup>] | operational since | Status | Notes | |
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Aba Samuel | Akaki | Afar Triangle | 6.6 | 0.25 | 0.035 | 22 | no | 1932 | Rehabilitation 1970 to 2016 | |||
| Koka (Awash I) | 8.468°N 39.156°W | Awash | Afar Triangle | 43 | 0.23 | 1.9 | 47 | no | 1960 | |||
| Awash II+III | Awash | Afar Triangle | 64 | 0.21 | river | run-of-river | no | 1966 1971 | ||||
| Fincha | 9.561°N 37.413°W | Fincha | Abbay | 134 | 0.63 | 0.65 | 20 | no | 1973 | |||
| Fincha Amerti Neshe (FAN) | 9.789°N 37.269°W | Amerti / Neshe | Abbay | 95 | 0.13 | 0.19 | 38 | 127 | 2011 | |||
| Gilgel Gibe I | 7.831°N 37.322°W | Gilgel Gibe | Turkana Basin | 184 | 0.43 | 0.92 | 40 | no | 2004 | cascade with Gilgel Gibe II | ||
| Gilgel Gibe II | 7.927°N 37.389°W | Gilgel Gibe / Omo | Turkana Basin | 420 | 0.41 | diversion weir | 46.5 | no | 2010 | cascade with Gilgel Gibe I | ||
| Gilgel Gibe III | 6.844°N 37.301°W | Omo | Turkana Basin | 1,870 | 0.30 | 14.7 | 243 | no | 2016 | cascade with Koysha | ||
| Koysha Dam | 6.584°N 36.565°W | Omo | Turkana Basin | 2,160[1] | (0.34) | 6 | 179 | no | 2021[2] | cascade with Gilgel Gibe III | ||
| Melka Wakena | 7.225°N 39.462°W | Shebelle | Shebelle | 153 | 0.30 | 0.75 | 42 | no | 1989 | |||
| Tana Beles | 11.82°N 36.92°W | Beles | Nile | 460 | 0.61 | 9.1 | floodgates | 1,400 | 2010 | |||
| Tekeze | 13.348°N 38.742°W | Tekeze | Nile | 300 | 0.26 | 9.3 | 188 | no | 2010 | |||
| Tis Abay I+II | 11.486°N 37.587°W | Blue Nile | Nile | 84.4 | 0.015 | river | run-of-river | no | 1953 2001 | |||
| GERD Hidase | 11.214°N 35.089°W | Abbay | Abbay | 750 (5,100) | (0.28) | 74 | 155 | no | 2022- | under construction, 90% complete (04/2023) | de facto cascade with Roseires Dam | |
| Genale Dawa III | 5.51°N 39.718°W | Ganale | Jubba | 254 | 0 < | --planned: 0.54 --> | 2.6 | 110 | no | 2017 | operational | cascade with Genale Dawa VI |
| Genale Dawa VI | 5.68°N 40.93°W | Ganale | Jubba | (257) | (0.67) | 0.18 | 39 | 270 | project implementation | cascade with Genale Dawa III Public-Private Partnership | ||
| Geba I+II | 8.211°N 36.073°W | Gebba | Abbay | (385) | (0.52) | 1.4 | 46 70 | 4,800 | project implementation | |||
| Total | 11,970 | |||||||||||
| Total operational | 6,978 |
Run-of-river schemes (without reservoir) totally depend on the flow of the river, which might be low in times of drought. Sometimes a run-of-river hydropower plant sits behind another hydropower plant in a cascade, so that their operation does not depend on the river but on the upstream size of the reservoir feeding the upstream hydropower plant. Such a scheme exists in the several cases (see Remarks). This makes more efficient use of the existing water supply.
Given by the table is the total volume of the reservoir for several hydropower plants but not the live volume, the usable part of the volume for hydropower generation. The live volume is not always known, therefore it is not shown in the lists, but a few examples can be given. The Tekezé-reservoir has a live volume of 5.3 km3, that is less than 58% of the total volume of 9.3 km3. For Genale Dawa III on the other hand, a live volume of 2.3 km3 is present, that is almost 90% of the total volume of the reservoir. For the larger reservoir of the Gilgel Gibe III power plant, the live volume amounts to 11.75 km3, 80% of the total size of the reservoir. The Koysha reservoir, although equipped with more turbine generators than Gilgel Gibe III is considered to get a live volume of only 5.2 km3. Koysha will depend on the cascade with Gibe III and is considered to be operated partially in run-of-river mode. And finally, the Grand Ethiopian Renaissance Dam, the live volume is about 59.2 km3, also 80% of the total size of the reservoir.
According to The Wind Power, the number of wind parks in operation (July 2017) is at three. All these wind parks deliver power to the national grid, they are ICS power stations.
| Wind farm | Location | Coordinates | Installed Capacity (MWe) | Capacity factor (2016/17) | Turbines | Operational since | Notes | |
|---|---|---|---|---|---|---|---|---|
| Adama I | Adama | 8.564°N 39.235°W | 51 | 0.30 | 34 | 2012 | ||
| Adama II | Adama | 8.564°N 39.235°W | 153 | 0.32 | 102 | 2015 | ||
| Ashegoda | Hintalo Wajirat | 13.425°N 39.523°W | 120 | 0.21 | 84 | 2013 | ||
| Ayisha I | Ayisha | 10.754°N 42.585°W | (120) | (0.34) | 80 | under construction | ||
| Ayisha II | Ayisha | 10.754°N 42.585°W | (120) | (0.41) | 48 | under construction; Ayisha III will follow | ||
| Total | 564.18 | |||||||
| Total operational | 324,18 |
All geothermal power plants are designed to be ICS power plants. They are primarily considered to be baseload power plants.
| ICS Power plant | Location | Coordinates | Installed capacity (MWe) | Capacity factor (2016/17) | Thermal energy (MWth) | Wells | Operational since | Status | Notes | |
|---|---|---|---|---|---|---|---|---|---|---|
| Aluto I | Aluto Langano | 7.789°N 38.794°W | 7.3 | 0 | 80 | 4 | 1998 | mothballed | out-of-operation for most of the time | |
| Aluto II | Aluto Langano | 7.789°N 38.794°W | (75) | (0.8) | 8 | committed, in implementation | ||||
| Tendaho I | Dubti | 11.75°N 41.09°W | (10) | (0.8) | 6 | under construction | ||||
| Corbetti I | Shashamane | 7.18°N 38.44°W | (10) | (0.8) | 3-5 | under construction until 2020 | One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW) | |||
| Corbetti II | Shashamane | 7.18°N 38.44°W | (50) | (0.8) | 9-13 | committed, in implementation | One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW) | |||
| Tulu Moye I | Arsi Zone | 8.159°N 39.137°W | (50) | (0.90) | under construction until 2021 | One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW) | ||||
| Total | 202.3 | |||||||||
| Total operational | 0 |
A total of ~520 MW is planned at the Corbetti site, with 10 MW under construction in the years 2018-2019 (Corbetti I) financed by equity. Almost simultaneously, Corbetti II with 50-60 MW will be developed, based on debt financing. After these two first phases, a simple GO decision by the stakeholders is required to start the construction works of Corbetti III to add another 440-60 MW until 2025. In parallel to the construction works at the Corbetti site, it is foreseen to start working at the Tulu Moye geothermal sites with ~520 MW in four phases, Tulu Moye I with 50 MW until 2021 and after a GO decision, Tulu Moye II-IV with 470 MW (see planned geothermal projects below) until 2027.
The total concession package agreed on between the Ethiopian government and the project stakeholders allows for the development of 1020 MW of geothermal energy at the respective sites.
Energy generation from solar energy in Ethiopia is limited to photovoltaic systems, only solar parks operating with flat panel solar cells will be built and operated. Ethiopia is specifying its solar parks with the ac-converted nominal power output MWac instead of the standard dc-based MWp. Ethiopia so avoids some confusion about the nominal power output.
No solar-thermal power plants are planned. The first large solar park is considered to be operational by 2019. All solar parks will be operated by private owners equipped with a long-term power purchase agreement.Renewable sources for thermal power plants include agricultural wastes, wood, urban wastes. In short: biomass. Two types of these thermal power plants exist in Ethiopia:
There is only one biomass-based thermal power plant in Ethiopia which is not attached to some large factory (therefore it is "simple" and not "cogenerational"). Located at the site of the main landfill (Koshe) of the capital Addis Ababa is the first waste-to-energy power plant of Ethiopia, Reppie waste-to-energy plant. It will be an ICS power plant. The power plant operates with a 110 MWth boiler that is designed to deliver sufficient steam to one single 25 MWe generating unit. Therefore and irrespective the existence of a second 25 MWe turbine-generator, the power plant cannot generate more than 25 MWe without special measures (like a future plant expansion).
Cogeneration means that the electricity is generated by a captive power plant attached to a factory, typically a sugar factory in Ethiopia, and the electricity produced is consumed mainly by that factory, with only surplus power being supplied to the national grid. The largest of these power plants, however, is under construction and is considered to deliver both heat and electricity for the own use in an industrial park near Adi Gudem with up to 11 heavy industry factories. It is fully private (IPP), the electrical power will be delivered to the national grid through a power purchasing agreement (PPA).
| ICS Thermal Plant | Location | Coordinates | Fuel | Installed capacity (MWe) | Own use (MWe) | Max. net exports (MWe) | Capacity factor | Status | Notes | |
|---|---|---|---|---|---|---|---|---|---|---|
| Adi Gudem Industrial | Adi Gudem | 13.241°N 39.558°W | gas (CCGT) | (500) | (135) | (365) | construction start in March 2019 | IPP with PPA | ||
| Wonji-Shoa Sugar | Adama | 8.454°N 39.23°W | bagasse | 30 | 9 | 21 | ||||
| Metehara Sugar | Metehara | 8.834°N 39.922°W | bagasse | 9 | 9 | 0 | ||||
| Finchaa Sugar | Fincha | 9.792°N 37.421°W | bagasse | 30 | 18 | 12 | ||||
| Kessem Sugar | Amibara | 9.153°N 39.954°W | bagasse | 26 | 10 | 16 | ||||
| Tendaho Sugar | Asaita | 11.55°N 41.389°W | bagasse | 60 | 22 | 38 | ||||
| Omo Kuraz I Sugar | Kuraz | 6.29°N 35.053°W | bagasse | (45) | (16) | (29) | under construction | |||
| Omo Kuraz II Sugar | Kuraz | 6.126°N 35.999°W | bagasse | 60 | 20 | 40 | ||||
| Omo Kuraz III Sugar | Kuraz | 6.126°N 35.999°W | bagasse | 60 | 20 | 40 | ||||
| Omo Kuraz V Sugar | Kuraz | 6.126°N 35.999°W | bagasse | (120) | (40) | (80) | under construction | |||
| Total | 647 | |||||||||
| Total operational | 167 |
Bagasse is only available from October to May during and after the harvesting of sugarcane. Therefore the operation of the plants (and their cogeneration facilities) is limited to these months. Given such conditions, the capacity factor of the plants has low chances to be above 0.5.
Under investigation is the use of biomass other than bagasse for electricity production in the campaign gap from May to October. A promising candidate is also the use of Devil's Tree for the Kessem sugar factory, an invasive species in the Amibara woreda of Afar region of Ethiopia. In addition, other thermal biomass power plants are planned to be constructed in Amibara woreda (close to the Kessem sugar factory) to make use of the Devil's Tree.
The list contains ICS power plants, with a sum of 98.8 MWe of installed capacity. They are all powered by diesel fuel:
| ICS Power plant | Location | Coordinates | Capacity (MWe) | Capacity factor (2016/17) | operational since | |
|---|---|---|---|---|---|---|
| Dire Dawa (mu) | Dire Dawa | 9.627°N 41.803°W | 3.6 | 0.002 | 1965 | |
| Dire Dawa | Dire Dawa | 9.627°N 41.803°W | 40 | 0.00 | 2004 | |
| Adwa | Adwa | 14.152°N 38.873°W | 3.0 | 0.00 | 1998 | |
| Axum | Axum | 14.122°N 38.709°W | 3.2 | 0.00 | 1975 | |
| Awash 7 Kilo | Awash | 9.002°N 40.177°W | 35 | 0.00 | 2003 | |
| Kaliti | Addis Ababa | 8.886°N 38.756°W | 14 | 0.00 | 2003 | |
| Total operational | 98.8 |
There are no other power plants working with non-renewable fuels or fossil fuels.
Ethiopia has confirmed gaseous, liquid and solid hydrocarbon reserves (fossil fuels): natural gas of around eight trillion cubic feet, oil by 253 million tonnes of oil shales and more than 300 million tonnes of coal. Most countries on earth use such resources to generate electricity, but in Ethiopia, there are no plans to exploit them for energy generation. An 800 km pipeline from a gas field to Djibouti is being laid by a Chinese company in order to export Ethiopia's gas resources cheaply to China, but there are no plans to use these resource for the benefit of Ethiopia itself yet. In the case of coal, plans were made in 2006 to build a 100 MW coal power plant (the Yayu coal power plant) which would use coal and lignite from a nearby coal mine. The capacity of 100 MW is extremely small by international standards (2000–4000 MW being the norm), but still, an active environment lobby managed to sabotage the plans, with the backing of international NGOs. All plans had to be abandoned and the project was cancelled in September 2006. The expected environmental destruction was considered to be way too severe.
SCS power plants are dealt with within the Ethiopian regions or by private institutions and not the federal government anymore (last federal data were from 2015), which makes it somewhat challenging to list them. SCS power plants often make sense only in areas with no access to the national grid, because of the often higher total cost of electricity if compared to ICS power plants.
This is especially true for the smallest hydropower power plants, while hydropower power plants with an installed capacity beyond 1 MWe might still be competitive. If the national grid is to enter the area of an SCS plant, the plant will possibly or even likely be shut down, closed and decommissioned. That can happen after just a few years of operation given the fast development in Ethiopia. The lifetime of small hydropower plants then amounts to years rather than decades. For the reason given, any listing of small hydropower SCS plants is something like a snapshot for the moment, here 2017.
On the other side, small SCS wind generators can be moved at any time to a new location, if the national grid approaches an area with small micro-grid wind farms. Such low-cost wind turbines can have a prolonged lifetime and can even be competitive with large-scale ICS power plants considering the total cost of electricity. Installation costs are low and they don't need costly infrastructure elements like water canals or diversion weirs.
The list is certainly not complete.
| SCS Power plant | Location | River | Drainage Basin | Type | Installed capacity (kWe) | Capacity factor (2016/17) | Operational since | Notes |
|---|---|---|---|---|---|---|---|---|
| Sor | 8.398°N 35.44°W | Sor River | Nile | run-of-river | 5,000 | 0.49 | 1990 | largest SCS |
| Dembi | south of Tepi village | Gilo River | Nile | run-of-river | 800 | 1991 | rehabilitation after 2010 | |
| Yadot | Delo Menna woreda | Yadot River | Jubba | run-of-river | 350 | 1990 | ||
| Hagara Sodicha | Aleto Wendo woreda | Lalta River | Rift Valley | weir | 55 | 2011 | ||
| Gobecho I + II | Bona woreda | Gange River | Rift Valley | weir | 41 | 2010/11 | ||
| Ererte | Bona woreda | Ererte River | Rift Valley | weir | 33 | 2010 | ||
| Leku | Shebe Senbo woreda | Boru River | Nile | weir | 20 | 2016 | ||
| Total operational | ! | 6,299 | ||||||
first six wind turbines / generators (with battery buffer) were initiated, built and provided in 2016 by the Ethio Resource Group, a privately owned company, that made a power purchasing agreement with the Ethiopian government. Each turbine services another village and its own micro-grid, there are no connections between the micro-grids and between the turbines.
There are around 40,000 small off-grid Solar Home Stations mainly for households delivering between 25–100 W each. For 2020 it is planned to have 400,000 of them. In addition, a large amount of solar lanterns are in operation, up to 3,600,000 are planned for 2020 for providing lighting in places in need for it. A double-digit number of private initiatives in Ethiopia is funded with US$100,000 each through the Power Africa and The Off-Grid Energy Challenge of the U.S. African Development Foundation. The single largest one is a 12 kW solar installation.
Remarkable is a hybrid photovoltaics system buffered by a battery which allows to deliver 160 kW. This system is built for Wolisso Hospital, one of the largest hospitals in Ethiopia to have an always reliable source of electrical power at a rated voltage due to its high-level medicine infrastructure and sensitive instruments and other equipment.
There are many small operational and active off-grid SCS Diesel systems with a sum of 20.65 MW of installed capacity throughout Ethiopia (Aug. 2017).
See also: Levelized cost of electricity. Ethiopia is now aiming as much as possible at geothermal energy, in contrast to the years before 2015, when the country focused almost exclusively on hydropower. Power plants with geothermal energy usually have a high and constant power output with high capacity factors which makes this kind of energy highly competitive in the long term. Also, geothermal energy can be used for baseload power plants. Geothermal energy is unlimited and always available, which is not always the case for hydropower (in times of drought, for example). Hydropower is still much cheaper and has the largest share in Ethiopian plans.
Ethiopia with its quickly increasing electricity demand of over 30% requires new power plants, immediately.But at the same time, the construction of new power plants is incredibly slow, in 2015 only 3.9% of the energy target (energy from new power plants) had been achieved for the timeframe from 2010–2015 due to lack of public financing. Ethiopia learned its lesson and is now seeking financing from private investors. These investors should build and also operate power plants for 25 years as Independent Power Producers (IPP), each equipped with a Power Purchasing Agreement (PPA).
Therefore, Ethiopia is now experimenting with Public-private partnerships with IPP's for the construction of most if not all powervplants. This happens in the hope to have many power plants being constructed simultaneously, something, Ethiopia cannot do due to its own limited financial resources. This also means that the original Ethiopian plans dealing with a priority order of power plants to be constructed until 2025 or 2037 is dead, as the free market has its own priority order.
Regarding suitable sites for generating electricity, Ethiopia did a lot of exploration in recent years, including determining the expected levelized cost of electricity (LCOE) for each site, electricity source and power plant including the construction of necessary power transmission lines, auxiliary infrastructures like access roads, etc. The LCOE values also depend on a multitude of boarder conditions like the capacity factor, the assumed lifetime of a power plant and other boarder conditions often being country-specific (which are not provided here). In some cases, the costs for power transmission lines make up to 0.02 $/kWh of the provided LCOE. Power transmission losses account for up to 0.007 $/kWh. The LCOE given in all tables below therefore cannot be directly compared to that of other countries in Africa and of the World in general.
The LCOE and LCOE ranges provided below are given in US$ values as of 2012 and were determined in 2013–2015. They reflect the state-of-the-art of 2012 and do not account for technology breakthroughs in the meantime:
| Hydropower | Geothermal energy | Wind farms | Solar parks | Co-generation with biomass | Combined cycle gas turbines (CCGT) | Gas turbines | Diesel | Waste-to-energy | |
|---|---|---|---|---|---|---|---|---|---|
| Projected additional Capacity [MW] | 9,893 | 3,412 | 1,500 | 700 | 420 | 420 | 0 | 0 | 0 |
| LCOE [$/kWh] | 0.02–0.11 | 0.05–0.11 | 0.08–0.11 | 0.12 | 0.11–0.12 | 0.11 | 0.135 | 0.21 | 0.245 |
| Capacity factor | 0.2–0.92 | 0.9 | 0.26–0.34 | 0.2–0.3 | 0.2–0.3 | 0.88 | 0.9 | 0.84 | 0.85 |
As IPP's should take over starting with 2017, surprises can happen. For example, high LCOE sites for geothermal power generation might become low LCOE sites in the near future, as there is an innovation cycle resulting in reduced costs. This is not reflected by the table above. Accordingly, the installed capacity in 2025 might be higher for geothermal energy than expected. A similar trend is observable for wind power and photovoltaics, so there might be a number of wind power sites in 2025 with an LCOE below 0.09 $/kWh. In the USA and in the timeframe of 2010–2017, the LCOE for solar photovoltaics was reduced by 81%, wind power saw a reduction of 63% and CCGT a reduction of 31%.
The following distribution among public and private investors is planned, with IPP constructing and operating the power plants for 20–25 years through PPA:
| Hydropower | Geothermal energy | Wind farms | Solar parks | Co-generation with biomass | Combined cycle gas turbines (CCGT) | |
|---|---|---|---|---|---|---|
| private (IPP) | 50% | 100% | 70% | 100% | 70% | ??? |
| public (EEP) | 50% | 0 | 30% | 0 | 30% | ??? |
The table below shows candidate power plants for construction, ordered for their LCOE (based on 2012 values). The general terms outlined in the chapter above for LCOE values apply for this listing as well. Power plants under construction or in project implementation phase are not shown, only the planned ones.
Most entries came from the Ethiopian Power System Expansion Master Plan Study, EEP 2014 and from the Ethiopian Geothermal Power System Master Plan, JICA 2015. A low number of refinements arrived from published tenders (as for the Upper Dabus power plant) and from feasibility studies that arrived after 2014 (as for the TAMS hydropower plant). For the Solar power plants, also documents from the Scaling Solar initiative of the World Bank have been used.
| Candidate Power plant | Location | Coordinates | Type | Drainage Basin | Capacity (MWe) | Capacity factor | LCOE ($/kWh) | Specifics | ||
|---|---|---|---|---|---|---|---|---|---|---|
| Melka Sedi | Amibara | 9.237°N 40.135°W | biomass | 137 | 0.9 | Input: Mesquite + Bagasse | ||||
| Bameza | Guba, near GERD | 11.222°N 35.082°W | biomass | 120 | 0.25 | 0.114 | input: wood | |||
| Wabi | Wabe River | 8.236°N 37.727°W | hydro | Turkana Basin | 100–150 | data-sort-value="0" | feasibility study in 2018[3] | |||
| Beko Abo | Blue Nile River | 10.365°N 36.571°W | hydro | Nile | 935 | 0.81 | 0.026 | data-sort-value="1.2" | live storage: 1.2 km3 | |
| Genji | Baro River | 8.157°N 35.149°W | hydro | Nile | 216 | 0.49 | 0.029 | data-sort-value="0.01" | diversion weir | |
| Upper Mendaya | Blue Nile River | 10.011°N 35.839°W | hydro | Nile | 1,700 | 0.57 | 0.038 | data-sort-value="10.3" | live storage: 10.3 km3 | |
| Karadobi | Blue Nile River | 9.894°N 37.839°W | hydro | Nile | 1,600 | 0.56 | 0.044 | data-sort-value="18.7" | live storage: 18.7 km3 | |
| Geba I+II | Geba River | 8.211°N 36.073°W | hydro | Nile | 385 | 0.55 | 0.045 | data-sort-value="1.7" | live storage: 1.7 km3 | |
| Sor II | Sor River | 8.398°N 35.44°W | hydro | Nile | 5 | 0.92 | 0.058 | data-sort-value="0.3" | live storage: 0.3 km3 | |
| Upper Dabus I+II | Dabus River | 9.934°N 34.895°W | hydro | Nile | 798 | 0.51 | 0.058 | data-sort-value="2.6" | live storage: 2.6 km3 | |
| Tendaho II-IV | Dubti | 11.75°N 41.09°W | geothermal | 555 | 0.90 | 0.059 | data-sort-value="240" | T >240 °C steam | ||
| Aluto III+IV | Aluto | 7.789°N 38.794°W | geothermal | 160 | 0.90 | 0.059 | data-sort-value="240" | T >240 °C steam | ||
| Birbir I+II | Birbir River | 8.543°N 35.195°W | hydro | Nile | 564 | 0.70 | 0.059 | data-sort-value="2.5" | ive storage: 2.5 km3 | |
| Corbetti II-III | Shashamane | 7.18°N 38.44°W | geothermal | 500 | 0.90 | 0.059 | data-sort-value="210" | T >210 °C steam | ||
| Halele Werabesa | River Gibe | 8.381°N 37.391°W | hydro | Turkana Basin | 424 | 0.54 | 0.061 | data-sort-value="5.7" | live storage: 5.7 km3 | |
| Chemoga Yeda I+II | Debre Markos | 10.286°N 37.727°W | hydro | Nile | 280 | 0.45 | 0.067 | data-sort-value="0.5" | live storage: 0.5 km3 | |
| Genale Dawa V | River Genale | 5.395°N 40.438°W | hydro | Jubba | 146 | 0.66 | 0.067 | data-sort-value="0.1" | live storage: 0.1 km3 | |
| Abaya | Middle Bilate River | 6.821°N 38.072°W | geothermal | 790 | 0.90 | 0.071 | data-sort-value="210" | T >210 °C steam | ||
| Boseti | near Kone | 8.78°N 39.829°W | geothermal | 265 | 0.90 | 0.072 | data-sort-value="210" | T >210 °C steam | ||
| TAMS | Baro River | 8.209°N 34.932°W | hydro | Nile | 1,700 | 0.39 | 0.073 | data-sort-value="4.8" | live storage: 4.8 km3 | |
| Meteka | Meteka | 9.867°N 40.517°W | geothermal | 130 | 0.90 | 0.073 | data-sort-value="210" | T >210 °C steam | ||
| Dofan | Dulecha | 9.35°N 40.13°W | geothermal | 86 | 0.90 | 0.078 | data-sort-value="210" | T >210 °C steam | ||
| Baro I+II | Baro River | 8.131°N 35.221°W | hydro | Nile | 645 | 0.46 | 0.083 | data-sort-value="1" | live storage: 1.0 km3 | |
| Lower Didessa | Didessa River | 9.479°N 35.97°W | hydro | Nile | 550 | 0.20 | 0.083 | data-sort-value="3.5" | live storage: 3.5 km3 | |
| Tekeze II | Tekeze River | 13.867°N 37.908°W | hydro | Nile | 450 | 0.69 | 0.084 | data-sort-value="6.6" | live storage: 6.6 km3 | |
| Ayisha III-IV | Ayisha | 10.754°N 42.585°W | wind | 300 | 0.34 | 0.09 | data-sort-value="0" | |||
| Iteya | Iteya | 8.241°N 39.126°W | wind | 600 | 0.32 | 0.09 | data-sort-value="0" | overlap with Assela and Tulu Moye areas | ||
| Mega Maji | Mega | 4.23°N 37.995°W | wind | 100 | 0.34 | 0.095 | data-sort-value="0" | |||
| Debre Berhan | Debre Berhan | 9.898°N 37.722°W | wind | 200 | 0.3 | 0.095 | data-sort-value="0" | |||
| Sululta | Sululta | 9.241°N 38.845°W | wind | 100 | 0.26 | 0.095 | data-sort-value="0" | |||
| Dila | Dila | 5.854°N 38.265°W | wind | 100 | 0.3 | 0.1 | data-sort-value="0" | |||
| Assela | Assela | 7.942°N 39.242°W | wind | 100 | 0.28 | 0.1 | data-sort-value="0" | overlap with Iteya and Tulu Moye areas | ||
| Tulu Moye II-IV | Arsi Zone | 8.159°N 39.137°W | geothermal | 470 | 0.90 | 0.104 | data-sort-value="170" | T ≥170 °C steam | ||
| Teo | Afar Zone 3 | 11.089°N 40.792°W | geothermal | 9 | 0.90 | 0.104 | data-sort-value="210" | T >210 °C steam | ||
| Fantale | Mount Fentale | 8.967°N 39.9°W | geothermal | 120 | 0.90 | 0.105 | data-sort-value="170" | T ≥170 °C steam | ||
| Dallol | Dallol volcano | 14.242°N 40.3°W | geothermal | 44 | 0.90 | 0.108 | data-sort-value="210" | T >210 °C steam | ||
| Dama Ali | Mount Dama Ali | 11.283°N 41.633°W | geothermal | 230 | 0.90 | 0.108 | data-sort-value="170" | T ≥170 °C steam | ||
| Calub | Calub gas field | 6.21°N 44.645°W | CCGT | 420 | 0.88 | 0.109 | data-sort-value="0" | domestic natural gas | ||
| Nazareth | Adama | 8.503°N 39.323°W | geothermal | 33 | 0.90 | 0.109 | data-sort-value="170" | T ≥170 °C steam | ||
| Boina | Alamata | 13°N 40.15°W | geothermal | 100 | 0.90 | 0.111 | data-sort-value="170" | T ≥170 °C steam | ||
| Mek'ele | Mek'ele | 13.498°N 39.504°W | solar | 100 | 0.2 | 0.12 | data-sort-value="0" | |||
| Humera | Humera | 14.284°N 36.62°W | solar | 100 | 0.2 | 0.12 | data-sort-value="0" | |||
| Gad | Gad | 9.96°N 41.93°W | solar | 125 | 0.2 | 0.12 | data-sort-value="0" | Scaling Solar Phase I | ||
| Hurso | Hurso | 9.612°N 41.536°W | solar | 125 | 0.2 | 0.12 | data-sort-value="0" | Scaling Solar Phase II (proposed) | ||
| Dicheto | NW of Galafi | 11.808°N 41.721°W | solar | 125 | 0.2 | 0.12 | data-sort-value="0" | Scaling Solar Phase I | ||
| Metema | Metemma | 12.952°N 36.173°W | solar | 125 | 0.2 | 0.12 | data-sort-value="0" | Scaling Solar Phase II (proposed) | ||
| Weranso | Weranso | 11.302°N 40.528°W | solar | 150 | 0.2 | 0.12 | data-sort-value="0" | |||
| Welenchiti | Welenchiti | 8.639°N 39.445°W | solar | 150 | 0.2 | 0.12 | data-sort-value="0" | |||
| Gojeb | Gojeb River | 7.237°N 36.854°W | hydro | Turkana Basin | 150 | 0.48 | 0.127 | data-sort-value="1" | live storage: 1.0 km3 | |
| Aleltu East | Aleltu River | 9.762°N 38.971°W | hydro | Nile | 189 | 0.53 | 0.128 | data-sort-value="0.6" | live storage: 0.6 km3 | |
| Aleltu West | Aleltu River | 9.756°N 38.954°W | hydro | Nile | 265 | 0.46 | 0.149 | data-sort-value="0.6" | live storage: 0.6 km3 | |
| Wabi Shebele | Shebelle River | 7.486°N 42.101°W | hydro | Shebelle | 88 | 0.91 | 0.161 | data-sort-value="3.3" | live storage: 3.3 km3 | |
| Lower Dabus | Dabus River | 9.985°N 34.889°W | hydro | Nile | 250 | 0.29 | 0.177 | data-sort-value="1.4" | live storage: 1.4 km3 | |
| Total planned | 18,617 | |||||||||
| Total ≤0.11 $/kWh | 15,201 | |||||||||
| Total ≤0.08 $/kWh | 11,257 | |||||||||
Some hydropower plants with high LCOE values are definitely multipurpose plants. Some of these high LCOE hydropower plants provide flood control, others allow advanced irrigation schemes for better agriculture (up to several thousands of km2) or they keep perennial and intermittent rivers navigable all year round.
Ethiopia is a member of the East Africa Power Pool. The other members are Sudan, Burundi, DRC, Egypt, Kenya, Libya, Rwanda, Tanzania, and Uganda.The Sodo–Moyale–Suswa High Voltage Power Line is being built between Sodo, Ethiopia and Suswa, Kenya.