List of power stations in Ethiopia

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.

Overview

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.[1] This results in a very dynamic situation with lots of 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).[2] In July 2017, the country had a total installed capacity of ~4.3 GWe and an annual electricity production of 12.5 TWh.[3] In 2017, hydropower has the lions share with 89.5% of the installed capacity and with 93,4% of the annual electricity production.

Guide to the lists

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.[4] 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.[3] 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[5].

Lists of ICS power plants

A complete list for all Ethiopian ICS power plants was published by the Ethiopian Electric Power (EEP) in September 2017.[3]

Renewable energies

Hydropower

ICS Power plant Coordinates Installed
capacity (MWe)		 Capacity factor
(2016/17)[6][7][8][9][3]		 Status operational
since		 River Drainage
Basin		 Total reservoir
size [km3]		 Dam height [m]
run-of-river		 Irrigation
area [km2]		 Remarks
Aba Samuel[10] 8°47′17″N 38°42′22″E / 8.788°N 38.706°E / 8.788; 38.706 (Aba Samuel Hydropower Plant) 6.6 0.25 operational 1932 Akaki Afar Triangle 0.035 22[11] no Rehabilitation
1970 to 2016
Koka (Awash I) 8°28′05″N 39°09′22″E / 8.468°N 39.156°E / 8.468; 39.156 (Koka (Awash I) Hydropower Plant) 43 0.23 operational 1960 Awash Afar Triangle 1.9 47 no
Awash II+III[12] 8°23′35″N 39°21′07″E / 8.393°N 39.352°E / 8.393; 39.352 (Awash II+III Hydropower Plants) 64 0.21 operational 1966
1971		 Awash Afar Triangle river run-of-river no
Fincha 9°33′40″N 37°24′47″E / 9.561°N 37.413°E / 9.561; 37.413 (Fincha Hydropower Plant) 134 0.63 operational 1973 Fincha Nile 0.65 20 no
Fincha Amerti Neshe (FAN)[13] 9°47′20″N 37°16′08″E / 9.789°N 37.269°E / 9.789; 37.269 (Fincha Amerti Neshe Hydropower Plant) 95 0.13 operational 2011 Amerti / Neshe Nile 0.19 38 127
Gilgel Gibe I[14] 7°49′52″N 37°19′19″E / 7.831°N 37.322°E / 7.831; 37.322 (Gilgel Gibe I Hydropower Plant) 184 0.43 operational 2004 Gilgel Gibe Turkana Basin 0.92 40 no cascade with Gilgel Gibe II
Gilgel Gibe II[15] 7°45′25″N 37°33′43″E / 7.757°N 37.562°E / 7.757; 37.562 (Gilgel Gibe II Hydropower Plant) 420 0.41 operational 2010 Gilgel Gibe / Omo Turkana Basin diversion
weir		 46.5 no cascade with Gilgel Gibe I
Gilgel Gibe III[16] 6°50′38″N 37°18′04″E / 6.844°N 37.301°E / 6.844; 37.301 (Gilgel Gibe III Hydropower Plant) 1,870 0.30 operational 2016 Omo Turkana Basin 14.7 243 no cascade with Koysha
Koysha 6°35′02″N 36°33′54″E / 6.584°N 36.565°E / 6.584; 36.565 (Koysha Hydropower Plant) (2,160)[17] (0.34) under
construction[18]		 Omo Turkana Basin 6 179 no cascade with Gilgel Gibe III
Melka Wakena[19] 7°13′30″N 39°27′43″E / 7.225°N 39.462°E / 7.225; 39.462 (Melka Wakena Hydropower Plant) 153 0.30 operational 1989 Shebelle Shebelle 0.75 42 no
Tana Beles 11°49′N 36°55′E / 11.82°N 36.92°E / 11.82; 36.92 (Tana Beles Hydropower Plant) 460 0.61 operational 2010 Beles Nile 9.1 floodgates 1,400
Tekeze 13°20′53″N 38°44′31″E / 13.348°N 38.742°E / 13.348; 38.742 (Tekezé Hydropower Plant) 300 0.26 operational 2010 Tekeze Nile 9.3 188 no
Tis Abay I+II 11°29′10″N 37°35′13″E / 11.486°N 37.587°E / 11.486; 37.587 (Tis Abay I+II Hydropower Plants) 84.4 0.015 operational 1953
2001		 Blue Nile Nile river run-of-river no
GERD 11°12′50″N 35°05′20″E / 11.214°N 35.089°E / 11.214; 35.089 (Grand Ethiopian Renaissance Hydropower Plant) (6,450) (0.28) under construction, 65% complete (4/2018)[20] Blue Nile Nile 74 155 no de facto
cascade with Roseires Dam
Genale Dawa III[21][22] 5°30′36″N 39°43′05″E / 5.51°N 39.718°E / 5.51; 39.718 (Genale Dawa III Hydropower Plant) 254 0 operational, but out of use for social reasons[23] 2017 Ganale Jubba 2.6 110 no cascade with Genale Dawa VI
Genale Dawa VI[22] 5°41′N 40°56′E / 5.68°N 40.93°E / 5.68; 40.93 (Genale Dawa VI Hydropower Plant) (257) (0.67) project
implementation[24]		 Ganale Jubba 0.18 39 270 cascade with Genale Dawa III
Public-Private Partnership
Geba I+II 8°12′40″N 36°04′23″E / 8.211°N 36.073°E / 8.211; 36.073 (Geba I+II Hydropower Plants) (385) (0.52) project
implementation[6]		 Gebba Nile 1.4 46
70		 4,800
Total 13,320
Total operational 4,068

The average capacity factor of all the shown Ethiopian hydropower plants was at 0.46 in the year 2014/15, an average value from the worldwide perspective.[6][7][8][9] In 2016/17, the average capacity factor was well below the 2014/2015 value. The reason is simple: the power grid got plenty of power generation reserves with the large Gilgel Gibe III power plant going into operation in 2016.[3]

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.

Wind farms

According to The Wind Power', the number of wind parks in operation (July 2017) is at three.[25] All these wind parks deliver power to the national grid, they are ICS power stations.

Wind farm Coordinates Installed
Capacity (MWe)		 Capacity factor
(2016/17)[7][9][3]		 Turbines Location operational
since		 Status Remarks
Adama I[25][26] 8°33′50″N 39°14′06″E / 8.564°N 39.235°E / 8.564; 39.235 (Adama I+II Wind Farms) 51 0.30 34 Adama 2012 operational
Adama II[25][26] 8°33′50″N 39°14′06″E / 8.564°N 39.235°E / 8.564; 39.235 (Adama I+II Wind Farms) 153 0.32 102 Adama 2015 operational
Ashegoda[25] 13°25′30″N 39°31′23″E / 13.425°N 39.523°E / 13.425; 39.523 (Ashegoda Wind Farm) 120 0.21 84 Hintalo Wajirat 2013 operational
Ayisha I[27][28] 10°45′14″N 42°35′06″E / 10.754°N 42.585°E / 10.754; 42.585 (Ayisha Wind Farm) (120) (0.34) 80 Ayisha under
construction
Ayisha II[29] 10°45′14″N 42°35′06″E / 10.754°N 42.585°E / 10.754; 42.585 (Ayisha Wind Farm) (120) (0.41) 48 Ayisha under
construction		 Ayisha III will follow
Total 564.18
Total operational 324,18

Ayisha I (120 MWe), Ayisha II (120 MWe) and Ayisha III (60 MWe) are bundled in one concession. This means, that all three will be under construction more or less simultaneously. The total installed capacity will be 300 MWe.

Geothermics

All geothermal power plants are designed to be ICS power plants. They are primarily considered to be baseload power plants.

ICS Power plant Coordinates Installed
capacity (MWe)		 Capacity factor
(2016/17)[7][3]		 Thermal
energy (MWth)		 Location Status Wells operational
since		 Remarks
Aluto I 7°47′20″N 38°47′38″E / 7.789°N 38.794°E / 7.789; 38.794 (Aluto Geothermal Plant) 7.3 0[30] 80 Aluto Langano mothballed[30] 4 1998 out-of-operation for most of the time[31]
Aluto II 7°47′20″N 38°47′38″E / 7.789°N 38.794°E / 7.789; 38.794 (Aluto Geothermal Field) (75)[30] (0.8) Aluto Langano committed, in
implementation[30][32]		 8
Tendaho I 11°45′N 41°05′E / 11.75°N 41.09°E / 11.75; 41.09 (Tendaho Geothermal Plant) (10)[33] (0.8) Dubti under
construction		 6
Corbetti I 7°11′N 38°26′E / 7.18°N 38.44°E / 7.18; 38.44 (Corbetti Caldera Geothermal Field) (10)[32][34] (0.8) Shashamane under construction
until 2020[35]		 3-5 One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW)[32][36][37]
Corbetti II 7°11′N 38°26′E / 7.18°N 38.44°E / 7.18; 38.44 (Corbetti Caldera Geothermal Field) (50)[35] (0.8) Shashamane committed, in implementation[35] 9-13 One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW)[32][36][37]
Tulu Moye I 8°09′32″N 39°08′13″E / 8.159°N 39.137°E / 8.159; 39.137 (Tulu Moye Geothermal Field) (50)[37] (0.90) Arsi Zone under construction
until 2021[37]		 One concession of Corbetti I-III with Tulu Moye I-IV (total ~1020 MW)[32][36][37]
Total 202.3
Total operational 0

The energy conversion efficiency of geothermal energies is low, at 10-15%, so that the released thermal energy is much larger than the obtained electrical energy. But thermal energy does not cost anything, so a low energy conversion efficiency does not hurt.

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.[35] 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.[37]

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.[32]

Solar parks

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.

ICS Solar park Coordinates Installed
capacity
(MWac)		 Capacity
factor		 park size
[km2]		 Location Status operational
since		 Remarks
Metehara[38] 8°57′50″N 39°54′40″E / 8.964°N 39.911°E / 8.964; 39.911 (Metehara Solar Park) (100) (0.32) (2.5) Metehara project
implementation		 1st solar park

No solar-thermal power plants are planned. The first large solar park is considered to be operational by 2019.[39][38] All solar parks will be operated by private owners equipped with a long-term power purchase agreement.

Thermal

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:

  1. Simple biomass thermal power plants, all electricity generated is exported to the power grid.
  2. Biomass thermal power plants that are cogeneration, meaning that they are captive power plants attached to a factory, typically a sugar factory, and the electricity produced is consumed mainly by that factory, with only surplus power being supplied to the national grid.
Simple Thermal

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.[40] 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).[41]

ICS Thermal Plant Coordinates Thermal
capacity (MWth)		 Installed
capacity (MWe)		 Max. net exports
(MWe)		 Capacity
factor		 Location Status combustion
input
Reppie waste-to-energy plant 8°58′34″N 38°42′36″E / 8.976°N 38.710°E / 8.976; 38.710 (Reppie Waste To Energy Plant) 110 50[40][41] 25 0.845 Addis Ababa operational[23] urban wastes,
biomass
Co-generation thermal

Cogeneration means that the electricity is generated by a captive power plants attached to a factory, typically a sugar factory, and the electricity produced is consumed mainly by that factory, with only surplus power being supplied to the national grid. In Ethiopia, all cogeneration power stations are biomass-based thermal ICS power plants attached to the national power grid.

The production of sugar and bioethanol from sugarcane leaves over biomass wastes: bagasse. The production of sugar and bioethanol requires thermal and electrical energy, both which is provided through the combustion of bagasse. The excess electrical power that is not needed for the production processes is then delivered to the national power grid. The Ethiopian sugar factories are state-owned and they are sometimes 'under construction' for many years and don't necessarily deliver sugar – or electricity. One example, the construction of Tendaho Sugar, started in 2005 and 12 years later its degree of completion stands at 27%.[42] At least the first three plants on the list (Wonji-Shoa Sugar, Metehara Sugar, Finchaa Sugar) are out of question, they are delivering electricity.[43]

ICS Thermal Plant Coordinates Installed
capacity (MWe)		 Own use
(MWe)		 Max. net exports
(MWe)[44]		 Capacity
factor		 Location Status combustion
input
Wonji-Shoa Sugar 8°27′14″N 39°13′48″E / 8.454°N 39.230°E / 8.454; 39.230 (Wonji-Shoa Sugar Plant) 30 9 21 Adama operational bagasse
Metehara Sugar 8°50′02″N 39°55′19″E / 8.834°N 39.922°E / 8.834; 39.922 (Metehara Sugar Plant) 9 9 0 Metehara operational bagasse
Finchaa Sugar 9°47′31″N 37°25′16″E / 9.792°N 37.421°E / 9.792; 37.421 (Finchaa Sugar Plant) 30 18 12 Fincha operational bagasse
Kessem Sugar 9°09′11″N 39°57′14″E / 9.153°N 39.954°E / 9.153; 39.954 (Kessem Sugar Plant) 26 10 16 Amibara operational bagasse
Tendaho Sugar 11°33′00″N 41°23′20″E / 11.550°N 41.389°E / 11.550; 41.389 (Tendaho Sugar Plant) (60) (22) (38) Asaita partially
operational		 bagasse
Omo Kuraz I Sugar 6°17′24″N 35°03′11″E / 6.290°N 35.053°E / 6.290; 35.053 (Omo Kuraz I Sugar Plant) (45) (16) (29) Kuraz under
construction		 bagasse
Omo Kuraz II Sugar 6°07′34″N 35°59′56″E / 6.126°N 35.999°E / 6.126; 35.999 (Omo Kuraz II Sugar Plant) 60 20 40 Kuraz operational bagasse
Omo Kuraz III Sugar 6°07′34″N 35°59′56″E / 6.126°N 35.999°E / 6.126; 35.999 (Omo Kuraz III Sugar Plant) (60) (20) (40) Kuraz under
construction		 bagasse
Omo Kuraz V Sugar 6°07′34″N 35°59′56″E / 6.126°N 35.999°E / 6.126; 35.999 (Omo Kuraz V Sugar Plant) (120) (40) (80) Kuraz under
construction		 bagasse
Total 282
Total operational 89

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. It would be tempting to make the cogeneration sugar factories pure electricity-generating biomass power plants during this time which would allow Ethiopia to operate additional and carbon-neutral power plants at no additional cost. A promising candidate is 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.

Non-renewable energies

Diesel

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 Coordinates Installed Capacity (MWe) Capacity factor
(2016/17)[7][3]		 Location operational
since		 Status
Dire Dawa (mu) 9°37′37″N 41°48′11″E / 9.627°N 41.803°E / 9.627; 41.803 (Dire Dawa Oil Power Plant) 3.6 0.002 Dire Dawa 1965 operational
Dire Dawa 9°37′37″N 41°48′11″E / 9.627°N 41.803°E / 9.627; 41.803 (Dire Dawa Oil Power Plant) 40 0.00 Dire Dawa 2004 operational
Adwa 14°09′07″N 38°52′23″E / 14.152°N 38.873°E / 14.152; 38.873 (Adwa Oil Power Plant) 3.0 0.00 Adwa 1998 operational
Axum 14°07′19″N 38°42′32″E / 14.122°N 38.709°E / 14.122; 38.709 (Axum Oil Power Plant) 3.2 0.00 Axum 1975 operational
Awash 7 Kilo 9°00′07″N 40°10′37″E / 9.002°N 40.177°E / 9.002; 40.177 (Awash 7Kilo Oil Power Plant) 35 0.00 Awash 2003 operational
Kaliti 8°53′10″N 38°45′22″E / 8.886°N 38.756°E / 8.886; 38.756 (Kaliti Oil Power Plant) 14 0.00 Addis Ababa 2003 operational
Total operational 98.8

Diesel power generation costs up to 10 times more than hydropower and is only used in times of emergency or when no other option is available. In 2016/2017, the capacity factor was ~0.00, indicating that the power grid had enough reserves and did not require power generation from expensive diesel. Essentially, all diesel power plants were in stand-by mode only.

Others

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.[9] 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.[45]

Lists of SCS power plants

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.

Renewable energies

Hydropower

The list is certainly not complete.

SCS Power plant Location Installed
capacity (kWe)		 Capacity factor
(2016/17)		 Status operational
since		 River Drainage
Basin		 Diversion weir
or run-of-river		 Remarks
Sor 8°23′53″N 35°26′24″E / 8.398°N 35.44°E / 8.398; 35.44 (Sor Hydropower Plant) 5,000 0.49 operational 1990 Sor River Nile run-of-river largest SCS
Dembi south of Tepi village 800 unknown 1991 Gilo River Nile run-of-river rehabilitation after 2010
Yadot Delo Menna woreda 350 operational 1990 Yadot River Jubba run-of-river
Hagara Sodicha Aleto Wendo woreda 55 operational 2011 Lalta River Rift Valley weir
Gobecho I + II Bona woreda 41 operational 2010/11 Gange River Rift Valley weir
Ererte Bona woreda 33 operational 2010 Ererte River Rift Valley weir
Leku Shebe Senbo woreda 20 operational 2016 Boru River Nile weir
Total operational 6,299

The listed SCS power plants have a total capacity of 6.3 MEe. An extension of the "Sor" power plant, the "Sor 2" power plant with another 5 MEe might be under construction, but the status of that project is not known.

Wind

There are private initiatives to provide small-scale wind power as SCS systems, off-grid. The 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.[46][47]

Location Turbines Installed
Capacity (kWe)
[per turbine]		 Installed
Capacity (kWe)
[per grid]		 Installed
Capacity (kWe)
[total]		 operational
since		 Status Remarks
Menz Gera Midir[46] 6 1.6 1.6 9.6 2016 operational Ethiopia's first SCS wind units[47]

Solar

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.[39][4] 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.[48]

Non-renewable energies

Diesel

There are lots of small operational and active off-grid SCS Diesel systems with a sum of 20.65 MW of installed capacity throughout Ethiopia (Aug. 2017).

Planned power plants until 2025

Energy mix foreseen

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.[1] 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.[49] 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).[50]

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 a large number of power plants being constructed in parallel, 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:

[5] 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

The list above does show the expected installed capacity (in MWe) for the LCOE ranges given for the year 2025. In general, Ethiopia targets LCOE of around 0.08 $/kWh and below to stay competitive in the future. A few exceptions are about to happen in particular in eastern Ethiopia (no hydropower, no geothermal energy, substantial losses through long distance power transmission), where CCGT and wind power remains competitive. This explains in part the planned energy mix shown.

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 from 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% ???

Candidate power plants

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.[5] 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[5]		    Coordinates    Capacity
(MWe)		 Capacity
factor		 LCOE
($/kWh)		 Type Location Drainage
Basin		 Specifics
Melka Sedi 9°14′13″N 40°08′06″E / 9.237°N 40.135°E / 9.237; 40.135 (Melka Sedi Thermal Power Plant) 137 0.9 biomass Amibara Input: Mesquite + Bagasse
Bameza 11°13′19″N 35°04′55″E / 11.222°N 35.082°E / 11.222; 35.082 (Bameza Thermal Power Plant) 120 0.25 0.114 biomass Guba, near GERD input: wood
Wabi 8°14′10″N 37°43′37″E / 8.236°N 37.727°E / 8.236; 37.727 (Wabi Hydropower Plant) 100-150 hydro Wabe River Turkana Basin feasibility study in 2018[51]
Beko Abo 10°21′54″N 36°34′16″E / 10.365°N 36.571°E / 10.365; 36.571 (Beko Abo Hydropower Plant) 935 0.81 0.026 hydro Blue Nile River Nile live storage: 1.2 km3
Genji 8°09′25″N 35°08′56″E / 8.157°N 35.149°E / 8.157; 35.149 (Genji Hydropower Plant) 216 0.49 0.029 hydro Baro River Nile diversion weir
Upper Mendaya 10°00′40″N 35°50′20″E / 10.011°N 35.839°E / 10.011; 35.839 (Upper Mendaya Hydropower Plant) 1,700 0.57 0.038 hydro Blue Nile River Nile live storage: 10.3 km3
Karadobi 9°53′38″N 37°50′20″E / 9.894°N 37.839°E / 9.894; 37.839 (Karadobi Hydropower Plant) 1,600 0.56 0.044 hydro Blue Nile River Nile live storage: 18.7 km3
Geba I+II 8°12′40″N 36°04′23″E / 8.211°N 36.073°E / 8.211; 36.073 (Geba I+II Hydropower Plants) 385 0.55 0.045 hydro Geba River Nile live storage: 1.7 km3
Sor II 8°23′53″N 35°26′24″E / 8.398°N 35.44°E / 8.398; 35.44 (Sor Hydropower Plant) 5 0.92 0.058 hydro Sor River Nile live storage: 0.3 km3
Upper Dabus I+II 9°56′02″N 34°53′42″E / 9.934°N 34.895°E / 9.934; 34.895 (Upper Dabus Hydropower Plant) 424 0.51 0.058 hydro Dabus River Nile live storage: 2.6 km3
Tendaho II-IV 11°45′N 41°05′E / 11.75°N 41.09°E / 11.75; 41.09 (Tendaho Geothermal Field) 555 0.90 0.059 geothermal Dubti T >240°C steam
Aluto III+IV 7°47′20″N 38°47′38″E / 7.789°N 38.794°E / 7.789; 38.794 (Aluto Geothermal Plant) 160 0.90 0.059 geothermal Aluto T >240°C steam
Birbir 8°32′35″N 35°11′42″E / 8.543°N 35.195°E / 8.543; 35.195 (Birbir Hydropower Plant) 467 0.70 0.059 hydro Birbir River Nile ive storage: 2.5 km3
Corbetti II-III 7°11′N 38°26′E / 7.18°N 38.44°E / 7.18; 38.44 (Corbetti Caldera Geothermal Field) 500 0.90 0.059 geothermal Shashamane T >210°C steam
Halele Werabesa 8°22′52″N 37°23′28″E / 8.381°N 37.391°E / 8.381; 37.391 (Halele Werabesa Hydropower Plant) 436 0.54 0.061 hydro River Gibe Turkana Basin live storage: 5.7 km3
Yeda I+II 10°17′10″N 37°43′37″E / 10.286°N 37.727°E / 10.286; 37.727 (Yeda Hydropower Plant) 280 0.45 0.067 hydro Debre Markos Nile live storage: 0.5 km3
Genale Dawa V 5°23′42″N 40°26′17″E / 5.395°N 40.438°E / 5.395; 40.438 (Genale Dawa V Hydropower Plant) 100 0.66 0.067 hydro River Genale Jubba live storage: 0.1 km3
Abaya 6°49′16″N 38°04′19″E / 6.821°N 38.072°E / 6.821; 38.072 (Abaya Geothermal Field) 790 0.90 0.071 geothermal Middle Bilate River T >210°C steam
Boseti 8°46′48″N 39°49′44″E / 8.780°N 39.829°E / 8.780; 39.829 (Boseti Geothermal Field) 265 0.90 0.072 geothermal near Kone T >210°C steam
TAMS 8°12′32″N 34°55′55″E / 8.209°N 34.932°E / 8.209; 34.932 (TAMS Hydropower Plant) 1,700 0.39 0.073 hydro Baro River Nile live storage: 4.8 km3
Meteka 9°52′01″N 40°31′01″E / 9.867°N 40.517°E / 9.867; 40.517 (Meteka Geothermal Field) 130 0.90 0.073 geothermal Meteka T >210°C steam
Dofan 9°21′N 40°08′E / 9.35°N 40.13°E / 9.35; 40.13 (Dofan Geothermal Field) 86 0.90 0.078 geothermal Dulecha T >210°C steam
Baro I+II 8°07′52″N 35°13′16″E / 8.131°N 35.221°E / 8.131; 35.221 (Baro Hydropower Plant) 645 0.46 0.083 hydro Baro River Nile live storage: 1.0 km3
Lower Didessa 9°28′44″N 35°58′12″E / 9.479°N 35.970°E / 9.479; 35.970 (Lower Didessa Hydropower Plant) 550 0.20 0.083 hydro Didessa River Nile live storage: 3.5 km3
Tekeze II 13°52′01″N 37°54′29″E / 13.867°N 37.908°E / 13.867; 37.908 (Baro Hydropower Plant) 450 0.69 0.084 hydro Tekeze River Nile live storage: 6.6 km3
Ayisha III-IV 10°45′14″N 42°35′06″E / 10.754°N 42.585°E / 10.754; 42.585 (Ayisha Wind Farm) 300 0.34 0.09 wind Ayisha
Iteya 8°14′28″N 39°07′34″E / 8.241°N 39.126°E / 8.241; 39.126 (Iteya Wind Farm) 600 0.32 0.09 wind Iteya overlap with Assela and Tulu Moye areas
Mega Maji 4°13′48″N 37°59′42″E / 4.230°N 37.995°E / 4.230; 37.995 (Mega Maji Wind Farm) 100 0.34 0.095 wind Mega
Debre Berhan 9°53′53″N 37°43′19″E / 9.898°N 37.722°E / 9.898; 37.722 (Debre Berhan Wind Farm) 200 0.3 0.095 wind Debre Berhan
Sululta 9°14′28″N 38°50′42″E / 9.241°N 38.845°E / 9.241; 38.845 (Sululta Wind Farm) 100 0.26 0.095 wind Sululta
Dila 5°51′14″N 38°15′54″E / 5.854°N 38.265°E / 5.854; 38.265 (Dila Wind Farm) 100 0.3 0.1 wind Dila
Assela 7°56′31″N 39°14′31″E / 7.942°N 39.242°E / 7.942; 39.242 (Assela Wind Farm) 100 0.28 0.1 wind Assela overlap with Iteya and Tulu Moye areas
Tulu Moye II-IV 8°09′32″N 39°08′13″E / 8.159°N 39.137°E / 8.159; 39.137 (Tulu Moye Geothermal Field) 470 0.90 0.104 geothermal Arsi Zone T ≥170°C steam
Teo 11°05′20″N 40°47′31″E / 11.089°N 40.792°E / 11.089; 40.792 (Teo Geothermal Field) 9 0.90 0.104 geothermal Afar Zone 3 T >210°C steam
Fantale 8°58′01″N 39°54′00″E / 8.967°N 39.9°E / 8.967; 39.9 (Fantale Geothermal Field) 120 0.90 0.105 geothermal Mount Fentale T ≥170°C steam
Dallol 14°14′31″N 40°18′00″E / 14.242°N 40.3°E / 14.242; 40.3 (Dallol Geothermal Field) 44 0.90 0.108 geothermal Dallol volcano T >210°C steam
Dama Ali 11°16′59″N 41°37′59″E / 11.283°N 41.633°E / 11.283; 41.633 (Dama Ali Geothermal Field) 230 0.90 0.108 geothermal Mount Dama Ali T ≥170°C steam
Calub 6°12′36″N 44°38′42″E / 6.210°N 44.645°E / 6.210; 44.645 (Calub Combined Cycle Gas Plant) 420 0.88 0.109 CCGT Calub gas field domestic natural gas
Nazareth 8°30′11″N 39°19′23″E / 8.503°N 39.323°E / 8.503; 39.323 (Nazareth Geothermal Field) 33 0.90 0.109 geothermal Adama T ≥170°C steam
Boina 13°00′N 40°09′E / 13.0°N 40.15°E / 13.0; 40.15 (Boina Geothermal Field) 100 0.90 0.111 geothermal Alamata T ≥170°C steam
Mek'ele 13°29′53″N 39°30′14″E / 13.498°N 39.504°E / 13.498; 39.504 (Mek'ele Solar Park) 100 0.2 0.12 solar Mek'ele
Humera 14°17′02″N 36°37′12″E / 14.284°N 36.620°E / 14.284; 36.620 (Humera Solar Park) 100 0.2 0.12 solar Humera
Dire Dawa 9°36′14″N 41°48′18″E / 9.604°N 41.805°E / 9.604; 41.805 (Dire Dawa Solar Park) 125 0.2 0.12 solar Dire Dawa Scaling Solar Phase I
Dicheto 11°48′29″N 41°43′16″E / 11.808°N 41.721°E / 11.808; 41.721 (Dicheto Solar Park) 125 0.2 0.12 solar NW of Galafi Scaling Solar Phase I
Gojeb 7°14′13″N 36°51′14″E / 7.237°N 36.854°E / 7.237; 36.854 (Gojeb Hydropower Plant) 150 0.48 0.127 hydro Gojeb River Turkana Basin live storage: 1.0 km3
Aleltu East 9°45′43″N 38°58′16″E / 9.762°N 38.971°E / 9.762; 38.971 (Aleltu East Hydropower Plant) 189 0.53 0.128 hydro Aleltu River Nile live storage: 0.6 km3
Aleltu West 9°45′22″N 38°57′14″E / 9.756°N 38.954°E / 9.756; 38.954 (Aleltu West Hydropower Plant) 265 0.46 0.149 hydro Aleltu River Nile live storage: 0.6 km3
Wabi Shebele 7°29′10″N 42°06′04″E / 7.486°N 42.101°E / 7.486; 42.101 (Wabi Shebele Hydropower Plant) 88 0.91 0.161 hydro Shebelle River Shebelle live storage: 3.3 km3
Lower Dabus 9°59′06″N 34°53′20″E / 9.985°N 34.889°E / 9.985; 34.889 (Lower Dabus Hydropower Plant) 250 0.29 0.177 hydro Dabus River Nile live storage: 1.4 km3
Total planned 17,550
Total ≤0.11 $/kWh 15,201
Total ≤0.08 $/kWh 10,740

Some candidate hydropower plants on the list have a much higher LCOE than CCGT power plants, wind farms or solar farms. Usually this means that the affected candidate power plants are out of play. Nevertheless, they might still be considered for immediate construction as the LCOE does not account for any multipurpose use beyond electricity generation.

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.

Cross border transfer of electricity

Ethiopia is a member of the East Africa Power Pool. The other members are Sudan, Burundi, DRC, Egypt, Kenya, Libya, Rwanda, Tanzania, and Uganda.

See also

References

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