Last Updated: June 2006
 Energy Data, Statistics and Analysis - Oil, Gas, Electricity, Coal_files/Blank.gif){kind=spacer}
Regional leaders created the Economic Community of West African
States (ECOWAS) on May 28, 1975 in Lagos, Nigeria. ECOWAS is comprised of
15 countries, which include: Benin, Burkina Faso, Cape Verde, Cote
d’Ivoire, The Gambia, Ghana, Guinea, Guinea-Bissau, Liberia,
Mali, Niger, Nigeria,
Senegal, Sierra Leone, and Togo. The leaders established ECOWAS to promote
regional integration and economic growth in West Africa, as well as to
create a monetary union in the region. However, ECOWAS has encountered
problems in the process of regional integration including: political
instability and lack of good governance that has plagued many member
countries, the insufficient diversification of national economies, the
absence of reliable infrastructure, and the multiplicity of organizations
for regional integration with the same objectives.
 Energy Data, Statistics and Analysis - Oil, Gas, Electricity, Coal_files/ecowas.gif)
The Authority of Heads of
State and Government is the governing body of ECOWAS. The
Authority determines the general direction and development of the
Community, as well as the realization of the Community’s objectives. The
Authority elects an annual Chairman, with the 2006 Chairman being Niger's
President, Mamadou Tandja. Under the Authority is the Council of Ministers, which
is responsible for the proper functioning of the Community. In April 2002,
the Council approved a procedure for the ECOWAS Trade Liberalization
Scheme (TLS). The TLS entitles the manufacturers of approved products to
customs duty exemption within ECOWAS member states. The procedure uses
National Approval Committees, set up by member states, to handle the
approval of products to be granted exemption under TLS. The 2002 decision
by the Council abrogates a previous decision and grants the Council a
monopoly for approving applications for such exemptions.
In 1990, ECOWAS established the Economic Community Monitoring
Group (ECOMOG), a multilateral military peacekeeping force to
intervene in the civil war of Liberia. Since 1990, ECOMOG has been
deployed in civil conflicts in Sierra Leone, Guinea-Bissau and
Côte d’Ivoire. The Côte d’Ivoire disarmament and
peace mission included ECOMOG troops from Benin, Ghana, Niger, Nigeria,
Senegal and Togo. Overall, Nigeria has contributed the largest amount of
troops, materials and financial support to ECOMOG missions. ECOWAS is
seeking international support to enable it to train and equip the 15
battalions of troops pledged by member states. The training of the
composite units facilitates their effectiveness in peacekeeping,
humanitarian assistance and other missions for which they could be
deployed.
Economic OverviewIn 2005, the combined Gross Domestic Product (GDP) for ECOWAS was
estimated at $139 billion (see Table
1.). Economies within the
Community are at varying stages of development. Nigeria's economy is
larger than the combined GDP of all other ECOWAS countries, with a GDP of
$78 billion. In 2005, the Community's economies grew at a combined
weighted average rate of 5.0 percent. However, substantial external debt
within individual states remains one of ECOWAS’ greatest challenges. In
addition, internal strife has adversely affected economic performance in
several states.
Total regional exports, including intra-regional exports, were $68.4
billion in 2005 and ECOWAS had a $17.5 billion trade surplus. The region's
major export commodities were energy products (crude oil and refined
petroleum products), minerals (gold, diamonds, and bauxite) and
agricultural products (cocoa, coffee, groundnuts, and cotton). The primary
U.S. import from the region was Nigerian crude oil. As of January 1, 2006,
President Bush approved the designation of 37 sub-Saharan African
countries as eligible for tariff preferences under the African Growth and Opportunity Act
(AGOA). As required by the legislation, this annual
determination signifies which countries are making continued progress
toward a market-based economy, the rule of law, free trade, economic
policies that will reduce poverty, and protection of worker's rights.
Côte d’Ivoire, Liberia, and Togo were the only countries in
the region not approved for the AGOA.
In 1994, ECOWAS’ Francophone members Benin, Burkina Faso,
Côte d'Ivoire, Mali, Niger, Senegal and Togo, with Lusophone
Guinea Bissau, created the West African Monetary Union (UEMOA) in Senegal.
UEMOA is a regional economic and monetary union which shares a common
currency (the CFA Franc). Five ECOWAS Anglophone-members, The Gambia,
Ghana, Guinea, Nigeria and Sierra Leone, have proposed setting up a second
West African Monetary Zone (WAMZ) in December 2009 and launching a new
common currency, the Eco. All five states signed the 2000 Accra
Declaration for the creation of the second monetary zone, agreeing to
reform their economies to meet specific targets prior to the introduction
of the Eco. It is planned that the Eco would circulate simultaneously with
the CFA Franc, with the ultimate goal of creating a single monetary zone
for the entire Community. Both Liberia and Cape Verde have shown interest
in becoming members of the WAMZ.
Energy OverviewCommercial energy resources in ECOWAS, primarily petroleum and
natural gas, are concentrated in coastal and offshore regions. Electricity
in West Africa is generated through thermal (57.8 percent of installed
capacity) or hydroelectric (42.2 percent) resources. Natural gas could
take a more significant role in the Community's energy sector as fields in
Nigeria and Côte d'Ivoire are developed. Due to a relatively
small urban population in ECOWAS (approximately 33.9 percent) and lack of
infrastructure, access to commercial energy sources is limited. In 2005,
Nigeria had petroleum exports of 2.3 million barrels per day (bbl/d),
while Côte d’Ivoire, exported 39,000 bbl/d of petroleum. All
other ECOWAS countries are net energy importers.
In 2003, ECOWAS consumed (see Table
2.) 1.43 quadrillion
British thermal units (Btu) of commercial energy (0.4 percent of total
world consumption) and produced 5.82 quadrillion Btu (1.4 percent of total
world production). Also in 2003, the region generated 33.2 million metric
tons of carbon equivalent (0.5 percent of the world total). Nigeria
accounted for 66.7 percent (0.99 quadrillion Btu) of energy consumption in
ECOWAS, 96.3 percent (5.6 quadrillion Btu) of energy production, and 76.9
percent (33.16 million metric tons) of the Community's carbon emissions.
ECOWAS has plans to create a $50 billion fund that will be used to
boost energy services for the West African population and to curb energy
shortfalls that are seen as a hindrance to economic development and
regional integration. ECOWAS has set December 2007 as the target for the
creation of the fund. By 2015, with the help of additional energy, ECOWAS
would like to see a 50 percent reduction in poverty within the Community.
Nigeria, West Africa's only significant oil producer, had oil
production averaging 2.6 million barrels per day (bbl/d) in 2005 (see Table
3). According to the Oil and
Gas Journal (OGJ), Nigeria's estimated proven crude reserves are
35.9 billion barrels, and this constitutes 96 percent of the Community's
estimated proven crude reserves. Smaller reserve deposits are located in
the Gulf of Guinea (offshore Benin, Côte d'Ivoire and Ghana).
In 2005, petroleum consumption in West Africa averaged 487,000 bbl/d, with
Nigeria being the Community's largest oil consumer (63 percent of total
consumption).
Exploration and
ProductionNigeria
In recent months, Nigeria has experienced increased pipeline
vandalism. In October 2005, a pipeline fire in the south-western Delta
State of Nigeria resulted in the deaths of about 60 people. This was
followed by a December attack, in which armed men in speed boats dynamited
Shell’s pipeline in the Opobo Channel. In January 2006, a pipeline attack
from the Brass Creek fields to the Forcados terminal forced Shell to
announce a force majeure on Forcados commitments to
end-February. Additional attacks made on the pipeline and the Forcados
terminal in February made it necessary for Shell to extend the force
majeure beyond the end-February date. Shell estimates that more than
450,000 bbl/d of its oil production is currently shut-in because of the
attacks. A February 2006 attack on the Escravos pipeline, that supplies
oil to the Warri refinery, caused the refinery to shutdown. Officials are
unsure of how long it will take to repair the damage. Nigeria had
re-commissioned the Escravos-Warri pipeline in January 2005 after 18
months of repairing the damage caused by sabotage during the 2003 Niger
Delta Crisis. In addition to pipeline vandalism, Nigeria has seen an
increase in kidnappings of expatriate oil workers in the Niger Delta
region. In January 2006, four foreign employees of Royal Dutch Shell were
kidnapped and then held for 19 days before being released on “humanitarian
grounds”. In February 2006, nine additional oil workers were kidnapped in
the Niger Delta region. On March 3, 2006, six of the nine hostages were
released, with the remaining three being released on March 27, 2006. The
Movement for the Emancipation of the Niger Delta (MEND) is taking
responsibility for the kidnappings and for blowing up a crude oil pipeline
owned and operated by Royal Dutch Shell.
Despite recent attacks on Shell's oil facilities in the Niger Delta
region, the company’s deepwater Bonga field began producing oil at the end
2005. Bonga is estimated to hold recoverable reserves of 600 million
barrels of oil. At peak production, the field will produce around 225,000
bbl/d and 150 million cubic feet (MMcf) of natural gas. Oil from the field
will be stored in a floating production, storage and offloading (FPSO)
unit, with a storage capacity of 2.0 million barrels.
ExxonMobil produces around 750,000 bbl/d of oil in Nigeria. The
company plans to invest $11 billion in the country's oil sector through
2011, with the hope of increasing production to 1.2 million bbl/d. The
majority of the increase will occur at the Erha field, which is located on
Block OPL 209. ExxonMobil began producing oil from Erha in April 2006.
Output from the field is expected to reach 150,000 bbl/d by the third
quarter of 2006, and rise to 190,000 bbl/d by the end of the year. Oil
from Erha is stored in an FPSO, with a storage capacity of 2.2 million
barrels oil. ExxonMobil uses Very Large Crude Carriers (VLCC), capable of
holding up to 300,000 deadweight tons to export the oil from the terminal.
The company also operates the Yoho field, with current full-field output
of around 150,000 bbl/d. Yoho contains around 400 million barrels of oil
reserves. ExxonMobil is continuing to expand Yoho field and estimates the
expansion project will increase production to 170,000 bbl/d by the third
quarter of 2006. The $1.2 billion field is located in the shallow waters
of Block OML 104. ExxonMobil's Bosi, and Eti/Asasa fields with capacities
of 120,000 bbl/d, and 25,000 bbl/d, respectively, are scheduled to come
online between 2006 and 2007.
Nigeria shares a Joint
Development Zone (JDZ) with neighboring São
Tomé and Príncipe (STP), which contains
23 exploration blocks. Nigeria and Sao Tome have agreed to split revenues
from the blocks on a 60:40 basis, respectively. Block One is currently the
only block in the JDZ undergoing development. The block is controlled by
Chevron (51 percent), with partners ExxonMobil (40 percent) and Equity
Energy Resources (9 percent). Preliminary studies have indicated that the
block could contain sizable amounts of oil (up to 1 billion barrels). If
recoverable oil is located, Chevron plans to bring it onstream by 2010.
Blocks Two through Six were also awarded, of which, three have been
approved for PSAs, while the remaining two have yet to be signed.
Meanwhile, several independent U.S. based companies that were awarded
shares in the blocks have relinquished their awards. Pioneer Natural
Resources stated a failure to agree to specific terms of operation on
Block Two as the reason for its withdrawal from the project. Pioneer’s
withdrawal has opened the door for China’s oil and gas company, Sinopec,
to invest in the JDZ. For more information on the oil sector in Nigeria,
please see the Nigerian
Country Analysis Brief.
Côte d’Ivoire In August 2005, Canadian Natural Resources (CNR) brought their Baobab
oil field onstream, with initial production averaging 48,000 bbl/d. The
field is located offshore in Block CI-40 and production on the field is
expected to reach capacity of 65,000 bbl/d in 2006. Block CI-40 is
estimated to contain 200 million barrels of recoverable oil
reserves. CNR is operator of the block with a 57.6 percent interest
and is joined with partners Svenska Petroleum Exploration (27.4 percent),
Petroci Overseas (10 percent), and Petroci Holding (5 percent). CNR is
also operator of Block CI-26 and holds an interest in Block CI-400. The
Espoir field, which is located in Block CI-26, had first oil come onstream
in 2002. Espoir's recoverable reserves are estimated at 93 million barrels
of oil and 180 billion cubic feet (Bcf) of natural gas. Production at the
field, which has a life expectancy of 20 to 25 years, is expected to peak
at 35,000 bbl/d of oil. Espoir's oil production is exported by shuttle
tanker, while the natural gas is piped to shore where it is used to
generate electricity. CNR announced that development of the West Espoir
field began in mid-2005, with production expected to start in mid-2006.
CNR holds 58.7 percent interest in Block CI-26 and is joined with partners
Tullow Oil (21.3 percent) and Petrosi (20 percent). In 2003, Tullow Oil
discovered oil in the Acajou prospect, also located on Block CI-26.
Devon Energy Corporation operates the Lion oil field on Block CI-11,
with production averaging 20,000 bbl/d of oil. Recoverable oil reserves on
the block are estimated to be 210 million barrels. Devon's partners on
Block CI-11 include Petroci, Pluspetrol of Argentina, and the
International Finance Corporation. In addition to Block CI-11, Devon holds
interests (ranging from 35 percent to 80 percent) in several other blocks
in Côte d'Ivoire including offshore Block CI-01, which contains the Kudu, Eland and Ibex fields; Block CI-02, which contains the
Gazelle field and Block CI-105.
Vanco Energy Company has estimated that 2.7 billion
barrels of oil is located in the San Pedro ridge and other deposits in
Block CI-112 off the western coast of Côte d'Ivoire.
India's Oil and Natural Gas Corporation (ONGC) (21.2
percent), Oil India (10.4 percent) and China's Sinopec
(27 percent) signed on to the CI-112 project in December 2004, reducing
Vanco's stake to 27 percent. This is the first African
deepwater exploration venture for all three state-owned firms. In March
2005, Vanco drilled the San Pedro 1 well on Block CI-112, but
later plugged the well due to a lack of hydrocarbons. In October 2005,
Vanco signed two production sharing agreements
(PSAs) with Côte d’Ivoire for
Blocks CI-401 and CI-101. For more information on the oil sector in
Côte d’Ivoire, please see the Côte
d’Ivoire Country Analysis Brief.
GhanaIn 2005, Saltpond Offshore Producing Ltd (SOPL), which is owned by
the U.S.-registered Lushann-Eternit (60 percent) and the state-owned
Ghanaian National Petroleum Company (GNPC) (40 percent), signed a $5
million redevelopment project that will restart six wells on the Saltpond
oil and natural gas field. SOPL hopes the additional wells will increase
production from the current 500 bbl/d to 1,500 bbl/d. The former operator
of Saltpond field, Agripetco, had shut the field down in 1985 due to
decreasing output.
Scottish-based Dana Petroleum is currently analyzing exploration
targets in the deepwater section of its West Tano Block. The company
previously drilled two successful test wells, WT-1X and WT-2X on Tano
field, and made estimates that the field contained oil reserves of 200
million barrels. However, Dana Petroleum indicated that only a small
amount of the oil would be recoverable due to geological reasons. Dana
Petroleum operates the block with 90 percent interest and is joined with
GNPC (10 percent).
In 2002, Oklahoma-based Devon Energy and Canadian independent EnCana
entered into an agreement with the GNPC to explore for hydrocarbons
offshore of southeastern Ghana in the Keta Basin. The companies are
currently analyzing seismic data on the Keta Block. Devon has been active
in Ghana since 1997 when it acquired the Keta concession. Houston-based
Vanco Energy also signed an exploration agreement with the Ghanaian
government in August 2002. In May 2005, Vanco Energy completed 3D seismic
research on its Cape Three Points Deepwater Block, and the company plans
to drill its first exploration well on the block in 2006. Finally,
Dallas-based, Kosmos Energy signed a seven-year oil exploration agreement
with Ghana. Kosmos will search for oil in the Tano Basin, adjacent to
Vanco Energy’s Cape Three Points Deepwater Block. Kosmos is operator of
the West Cape Three Points license with 86.5 percent interest and is
joined with GNPC (10 percent) and E.O. Group (3.5 percent).
SenegalIn 2006, Hunt Oil plans to conduct seismic research on the
Sangomar-Rufisque license offshore Senegal. Analysts estimate that the
license area could contain upwards of 1 billion barrels of recoverable
oil. Hunt Oil is the operator of the license with a 60 percent interest,
and is joined with partners First Australian Resources (30 percent) and
state-owned Societe des petroles du Senegal (Petrosen) (10 percent).
In March 2005, Malaysian-based, Markmore Energy acquired a 55 percent
stake in the Dome Flore Block. The block is located in a joint maritime
exploration zone, which is controlled by Senegal and Guinea-Bissua and
administered by the Agence de Gestion et de Cooperation (AGC). The Dome
Flore Block contains an estimated 800 million barrels of heavy oil.
Thirteen wells have been drilled on the block, and several have penetrated
10 - 13 API heavy oil deposits. Additionally, two wells have found much
smaller deposits of 30 - 35 API light oil. Markmore Energy is joined with
partners Sterling Oil (UK) (30 percent) and AGC (15 percent).
Eni, as operator of the AGC-administered Cheval Marin Block, has a 48
percent interest and is joined with ExxonMobil (37 percent), Sterling Oil
(10 percent) and AGC (15 percent). Seismic surveys were completed on the
Cheval Marin Block in April 2002, and additional seismic surveys are being
planned.
Guinea-BissauIn March 2002, U.K.-independent Premier Oil announced the results of
its first exploratory well on the Sinapa prospect (Block 2) offshore
Guinea-Bissau. The Sinapa-1 exploratory well has been designated plugged
and abandoned with oil shows. Despite the disappointing results, Premier
Oil plans to retain its acreage in Guinea-Bissau, and is in the process of
reviewing seismic data on its holdings. In addition, Premier Oil plans to
drill exploration wells, Eirozes and Espinafre, towards the end of 2006.
The national oil company of Guinea-Bissau, Petroguin, is planning to offer
the country's new deep-water acreage to prospective investors. Exploration
activity in the region has sparked interest in the remaining 11 offshore
blocks.
The GambiaIn July 2005, The Gambia awarded Philippine National Oil Company
(PNOC) one of The Gambia’s six oil exploration blocks. The Gambia gave the
award to PNOC without tender, or a technical review of the company’s
capabilities. Amerada Hess (80 percent interest) and Sterling Energy (20
percent) hold the rights to The Gambia's Deepwater PPL Block. The license
has been issued for six years and the companies are currently finalizing
interpretation studies and evaluating options for a 3D seismic data
acquisition.
Benin and Togo In Benin, U.S.-based independent Kerr-McGee has exploration plans for
Block 4, which include 3D seismic research and an anticipated drilling in
late 2006. Kerr-McGee (operator) holds a 40 percent interest in the block
and is joined with partners Kosmos Energy (40 percent) and Malaysia's
Petronas (20 percent). In neighboring Togo, Petronas and Hunt Oil are
exploring for oil. Hunt Oil signed a PSC with Togo in late July 2002 for
the country's first deepwater well. In addition, Togo awarded Hunt Oil the
exclusive rights to the country’s entire offshore area. The contract area,
previously divided into 15 blocks, covers 1,570 square miles.
Other ECOWAS Members Although the Mano River States (Liberia, Guinea and Sierra Leone)
currently produce no hydrocarbons, sporadic exploration activity is taking
place. In 2005, Liberia held its first licensing round since the cessation
of its civil war in 2003. Liberia awarded exploration concessions to
UK-based Regal Petroleum, Repsol, Woodside, Broadway Consolidated and
Oranto Petroleum. In addition, Canadian-based Ona Exploration signed a
Memorandum of Understanding (MoU) with the Liberian government for oil and
natural gas drilling rights in two offshore concessions. In Guinea,
Houston's HyperDynamics has been meeting with government officials to
discuss hydrocarbon development plans in the country. The company has
exploration and data marketing rights for the entire continental margin of
Guinea, which covers 210 miles of coastline and up to 150 miles offshore.
In October 2005, Sierra Leone signed an agreement with Nigerian’s oil and
natural gas company, Frazimex, allowing the company to explore for oil in
Block 3 for seven years. Several test wells drilled in the 1970's on
Sierra Leone's continental shelf produced "shows" of oil.
To date, no proven hydrocarbon reserves have been found in
Mali. However, many oil companies are currently exploring for oil, with
focused exploration on the Taoudeni basin and the Graben de Gao in the
northwest of the country. In Niger, the China National Petroleum
Corporation (CNPC) is choosing three sites to drill exploration wells in
its Tenere Block. CNPC’s contract states that the drilling must be
completed by 2008. In Petronas’ and ExxonMobil’s Agadem Block, the
companies discovered an estimated 350 million barrels of oil equivalent.
Oil exploration has been carried out for more than 20 years in Niger's
Djado region on the border with Libya, but no commercial finds have been
discovered.
West Africa's petroleum refining capacity is concentrated in Nigeria.
Nigeria's refining capacity is currently insufficient to meet domestic
demand, forcing the country to import petroleum products. Nigeria's
state-held refineries (Port Harcourt I and II, Warri, and Kaduna) have a
combined nameplate capacity of 438,750 bbl/d, but problems including
sabotage, fire, poor management and a lack of regular maintenance
contribute to the current operating capacity of around 214,000 bbl/d. The
Nigerian government is granting permits to build several
independently-owned refineries in Nigeria. Sapele Petroleum Limited is
waiting for final approval to construct a $105-million, 120,000 bbl/d oil
refinery in Delta State. The refinery is one of the more probable to be
built and could save Nigeria as much as $2 billion in costs for refined
petroleum imports. Other ECOWAS refineries are located in Côte
d’Ivoire(Abidjan, 65,200 bbl/d); Ghana (Tema, 45,000
bbl/d); Liberia (Monrovia, 15,000 bbl/d); Senegal (Dakar, 27,000 bbl/d)
and Sierra Leone (Freetown, 10,000 bbl/d).
Côte d'Ivoire's refining facilities consist of the 65,200-bbl/d SIR
refinery and an adjacent 10,000-bbl/d asphalt plant (Société
Multinationale de Bitumes-SMB) in Abidjan. An oil pipeline connects the
SIR refinery to the Lion and Panther fields. The refinery also receives
crude oil from Nigeria. The state currently owns 47.27 percent of SIR, and
expects to retain a 10 percent interest after privatization. Burkina Faso
owns a 5.39 percent stake in SIR, and Total, Shell, ExxonMobil and
ChevronTexaco own the remainder.
The government of Ghana plans to partially privatize its Tema Oil
Refinery (TOR) in 2006 in order to raise money for infrastructure
developments in the country. In addition, plans are being made to increase
TOR’s capacity to 100,000 bbl/d. Currently, TOR’s 45,000 bbl/d capacity
meets about 80 - 85 percent of Ghana’s demand for petroleum products.
Ghana hopes to raise $6 million from the sale of TOR and other state-run
businesses.
West Africa contains approximately 32 percent of Africa’s total
natural gas reserves. Nigeria holds the Community’s largest proven
reserves with 185 trillion cubic feet (Tcf) (see Table
4). However, proven reserves are also located in
Côte d’Ivoire (1.0 Tcf), Ghana (840 billion cubic feet; Bcf),
and Benin (40 Bcf). Although natural gas is still in early stages of use
in the region, several projects are under way that should increase the
future use of the resource.
NigeriaAccording to 2006 estimates by the Oil and Gas Journal (OGJ), Nigeria is the seventh largest
natural gas reserve holder in the world and the largest in Africa. In
October 2004, Nigeria announced that its natural gas reserves could be as
high as 660 Tcf. The government plans to raise earnings from natural gas
exports to 50 percent of oil revenues by 2010. However, the Nigerian
National Petroleum Company (NNPC) estimates that $15 billion in private
sector investments is necessary to meet its natural gas development goals
by 2010.
The vast majority of natural gas found in Nigeria is associated,
meaning that it occurs in crude oil reserves as free gas. Because many of
the fields lack the infrastructure to produce the associated natural gas,
it is flared. Nigeria flares more natural gas than any other country in
the world, with 43 percent of its total annual natural gas production
being flared. NNPC estimates that Nigerian flared natural gas accounts for
approximately 20 percent of the world total. Nigeria is working to end
natural gas flaring by 2008. However, Shell announced in its 2004 People
and Environment Annual Report that it would not be able to meet the 2008
goal of eliminating natural gas flaring.
A significant portion of Nigeria’s natural gas is processed into
liquefied natural gas (LNG). Nigeria's most ambitious natural gas project,
the $3.8 billion liquefaction facility on Bonny Island, was completed in
September 1999. In January 2006, NLNG sent its first shipment of LNG
exports to the United States from its newly-commissioned fourth train. The
company’s fifth train began operating in January 2006 as well. The
additional two trains have increased annual production capacity to 17
million tons per year of LNG. Plans have been approved for a sixth train
(to come online in 2007), which is expected to bring total capacity to 22
million tons per year. The facility is currently supplied from dedicated
(non-associated) natural gas fields, but it is anticipated that within a
few years half of the input natural gas will consist of associated
(currently flared) natural gas from existing oil fields. In January 2005,
ExxonMobil signed an MOU with NNPC to study the possibility of
constructing a second LNG plant on Bonny Island to come online in 2010.
The plant would produce around 4.8 million tons per year of LNG.
Côte
d’IvoireAccording to 2006 estimates by the OGJ, Côte d'Ivoire has 1.0 Tcf of proven
natural gas reserves. Although exploration teams first discovered natural
gas in Côte d'Ivoire in the 1980's, it wasn’t until the mid-1990’s that
companies began to develop the resource. In 2003, Côte d'Ivoire produced
50 Bcf of natural gas, while consuming 46 Bcf. The Ivoirian government
estimates that natural gas consumption will grow by 50 percent over the
next three years.
Côte d'Ivoire’s largest producing natural gas field is the Foxtrot
field in Block CI-27. Foxtrot contains estimated recoverable natural gas
reserves of 650 Bcf, and the field produces around 80 MMcf/d. The Manta
field is also located in Block CI-27 and in December 2005, the Mahi-1 well
began producing natural gas at 32 MMcf/d. The Block is operated by
Foxtrot, with a 24 percent interest and partners include Petroci (40
percent), SECI; a member of the Bouygues group of
France (24 percent), and Energie de
Côted'Ivoire (Enerci); a joint
venture of Gaz de France and EdF Group (12 percent).
SenegalSenegal's natural gas reserves are primarily located onshore. In
October 2002, U.S.-independent Fortesa International began natural gas
production from the onshore Gadiaga Development Area, with current
production at two MMcf/d of natural gas. Fortesa holds a 70 percent stake
in Gadiaga, with the remaining 30 percent held by Petrosen, the Senegalese
national oil company. In December 2005, Fortesa’s Sadjiratou-1 natural gas
well tested positive and the company has plans to drill another test well
in 2006. Petrosen anticipates that Tullow Energy, Hunt Oil and Edison will
drill additional test wells in 2007.
West African Gas
PipelineThe most significant natural gas development project is the West African Gas
Pipeline (WAGP) project. The WAGP will traverse 620 miles both
on and offshore from Nigeria's Niger Delta region to the Volta River
Authority’s power plant at Takoradi, Ghana. The $600 million WAGP will
initially transport 120 MMcf/d of gas to Ghana, Benin and Togo. In
September 2005, WAGP began laying the 353-mile main offshore segment of
the pipeline offshore Ghana. The pipeline is being laid approximately 12
miles offshore at a rate of up to two miles per day. Tie-in points will
take natural gas to metering and custody transfer stations at Lome in Togo
and Cotonou in Benin. Completion of the pipeline installation is projected
for December 2006. Natural gas deliveries are expected to be at 400 MMcf/d
when the pipeline is functioning at its capacity (approximately 15 years
after construction).
In February 2003, the four nations involved in the WAGP signed an
agreement on the projects implementation. The treaty, which is for a
20-year period, provides for a comprehensive legal, fiscal and regulatory
framework, as well as a single authority for the implementation of the
project. The WAGP partners are ChevronTexaco with 36.7 percent, NNPC with
25 percent, Shell with 18 percent, Ghana's Takoradi Power Company with
16.3 percent and Societe Beninoise de Gas and Societe Togolaise de Gas
each with a 2 percent interest.
Only about one in three ECOWAS citizens currently has access to
electricity and analysts predict that electricity demand in the Community
will increase by five percent annually over the next 20 years. West
Africa's total installed electric generating capacity was 9.8 gigawatts
(GW) at the beginning of 2003, the majority of which is thermal (see Table
5). Total electricity generation for the region in 2003 was
31.0 billion kilowatthours (Bkwh), with Nigeria (15.7 Bkwh), Ghana (8.8
Bkwh) and Cote d'Ivoire (5.1 Bkwh) being the largest generators. In 2003,
total regional electricity consumption was 28.4 Bkwh, led by Nigeria (14.5
Bkwh, 50.1 percent). Ghana (5.1 Bkwh, 17.8 percent), Cote d'Ivoire (3.4
Bkwh, 12.0 percent) and Senegal (1.2 Bkwh, 4.3 percent) were the next
largest electricity consumers.
NigeriaThe Nigerian power sector operates well below its estimated capacity,
with power outages being a frequent occurrence. According to Power Holding
Company of Nigeria (PHCN), the country’s peak electric demand in February
2006 was 7,600 megawatts (MW), but actual generation capability was 3,600
MW. The discrepancy between electricity demand and actual generation is
mostly due to low water levels and inadequate plant maintenance. During
2005, electricity generation capacity fluctuated between 2,600 MW and
3,600 MW. The hydropower stations Kainji, Jebba, and Shiroro have seen
generation affected by insufficient water, and the Lagos Egbin, Delta, and
Port Harcourt Afam plants are also operating at below capacity due to poor
maintenance.
Only 40 percent of Nigerians have access to electricity, the majority
of whom are concentrated in urban areas. Despite endemic blackouts,
customers are billed for services rendered, partially explaining Nigeria's
widespread vandalism, power theft and PHCN's problems with payment
collection. Nigeria’s Bureau of Public Enterprises (BPE) hopes to see
increased stability in Nigeria’s electricity sector once the definite
privatization of PHCN takes place.
GhanaHydroelectricity is the primary source of Ghana's power. Ghana's
current hydroelectric capacity of 1.2 GW is located at Akosombo (912 MW)
and Kpong (160 MW). In 2005, the turbines of the Akosombo generation
station underwent retrofitting to increase its installed capacity by about
108 MW. The Ghanaian government is considering additional hydroelectric
projects to be built on a Build Operate Transfer (BOT) financing scheme.
One of these proposed projects is the $700-million, Bui hydroelectric
project, which would be located on the Black Volta and have a generation
capacity of 400 MW. In addition to increasing the domestic electricity
supply, power generated from Bui could be exported to Burkina Faso, Mali
and Côte d'Ivoire. An investment decision on the Bui
hydroelectric project is to be made by the end of 2006, and a maximum of
five years would be needed to complete the project. Additional
hydroelectric projects include the Hemang and Juale hydroelectric power
dams (operational by 2015) and the Pwalugu hydroelectric power dam
(operational by 2020). The generation capacity of Hemang, Juale and
Pwalugu would be developed to 93 MW, 87 MW, and 48 MW respectively.
In addition to increasing hydroelectric output, Ghana plans to
increase and expand thermal generating capacity. Current thermal
facilities are located at Tema and Takoradi. Additional capacity is
planned at Tano (gas-fired barges) and at Tema. Volta River Authority
(VRA) and GNPC have constructed transmission lines and substations at
Essiama and Elubo in the Western Region to feed the power generated at
Tano into the national grid.
The WAGP, which will transport natural gas from Nigeria to the
Takoradi power plant in Ghana, is expected to deliver the first natural
gas in December 2006. The transmission pipeline will provide Ghana (in
addition to Benin and Togo) with a reliable energy infrastructure and
competitively priced natural gas. In March 2006, the minister for energy
of Ghana announced that the International Finance Corporation (IFC) of the
World Bank Group had given approval for negotiations on financing the
expansion of the Aboadze thermal power plant at Takoradi. The cost of the
expansion project is estimated at $215 million. The upgrade would convert
the plant from burning crude oil to natural gas, which it would receive
from Nigeria through the WAGP. CMS Energy, a US-based company, has a 90
percent stake in the Takoradi facility, and the VRA holds the remaining 10
percent.
The Electric Company of Ghana (ECG) is responsible for electricity
distribution to the Ashanti, Western, Central, Eastern, Greater Accra and
Volta regions. VRA is responsible for generation and for the distribution
of electricity in the Brong Ahafo, Northern, Upper East and Upper West
regions. When the WAGP is completed, VRA plans to convert oil-fired
facilities at Takoradi and Tema to natural gas.
Côte
d’IvoireCôte d'Ivoire’s natural gas-powered stations generate more than half
of the country's annual production. In 1995, Côte d'Ivoire built their
first natural gas-fired plant, Vridi II, near Abidjan. In 1999, the 288-MW
Azito power station came online. Azito produces more than a third of the
country's power. The phased construction of a third turbine in Azito has
been delayed pending a satisfactory rise in domestic and regional demand
for electricity, through the West African Power Pool (WAPP). In May 2005,
Alstom signed a 10-year service contract for the Azito plant. In addition
to natural gas-powered stations, Côte d'Ivoire also uses hydroelectric
plants to generate electricity. Although they no longer run at full
capacity, hydroelectric plants (Ayame I and II, Kossou, Taabo, Buyo and
Grah) continue to generate about 17 percent of the country's electricity.
Ivoirians also use individual fuel-powered generators throughout much of
the country.
SenegalDue to the fuel shortages, massive blackouts have recently affected
Senegal’s capital, Dakar. In April 2006, Morocco’s Samir oil refinery
agreed to ship fuel to Senegal’s power company, the Societe Nationale
d'Electricite (SENELEC) in order to return electricity generation to
normal in the country. Samir has also agreed to help construct fuel
storage facilities and to examine the possibility of building a new oil
terminal in Senegal.
In June 2005, the African Development Bank (ADB) approved a $10
million loan to finance the development of the Kounoune thermal power
project. The project consists of three components: construction and
operation of a 67.5 MW heavy diesel-fuel plant based on a
Build-Own-Operate contrac, the construction of a fuel supply pipeline
(heavy fuel) connecting the plant to the fuel source, and a substation
linking the plant to the SENELEC power grid. Senegal and the ADB hope the
project will help meet the county’s growing demand for electricity.
Other ECOWAS MembersLiberia plans to rebuild electricity generation and distribution
infrastructure that was damaged or destroyed during the civil war. The
first electrification goal is at the minimum to bring electricity to
central Monrovia by July 26, 2006. President Johnson-Sirleaf also has
long-term plans to privatize the Liberia Electricity Corporation (LEC) to
facilitate in making it more functional and serviceable for Liberians.
In June 2005, the government of Sierra Leone, with the support of the
World Bank, ADB and Italy decided to undertake the completion of the
Bumbuna hydroelectric project. The project had been nearly complete (85
percent) when civil war disrupted the construction in 1997. The Bumbuna
project includes construction of a dam, water intake structures,
spillways, and two 25 MW turbo-generators. To date, only the power house
has yet to be constructed, and completion of the project is expected in
2008. The total project cost is estimated to be $53.8 million.
Guinea is the source of several major West African rivers (including
the Gambia and Niger Rivers) and has a hydroelectric potential
(technically feasible) estimated at 19,400 Gigawatthours per year
(Gwh/yr). Only about 1 percent of Guinea's technically feasible potential
has so far been developed. The 75-MW Garafiri hydroelectric facility, on
the Konkoure River, was commissioned in 1999; and an 80-MW project is
planned 60 miles downstream at Kaleta. A 975 MW dam in Souapiti Kaleta has
also been proposed, but the displacement of 50,000 inhabitants in the area
has deterred international organizations from financing the project.
In Niger, the Islamic Development Bank (IDB) has taken the lead for
funding the construction of the Kandadji hydroelectric project. To date,
80 percent of the funding is available. In 2005, Moroccan engineering and
design firm Conseil, Ingenierie et Developpement won the $550,000
technical studies contract for the Kandadji dam. Kandadji, first conceived
in the mid-1970's, will be located on the Niger River approximately 120
miles upstream of Niamey. The 165-MW facility (originally proposed to be
230 MW) is expected to cost $270 million.
Regional ProjectsWest African Power Pool (WAPP)
In an effort to improve power reliability and encourage private
sector investment, ECOWAS has been working to establish the West African
Power Pool (WAPP). In October 2000, 14 ECOWAS members signed an agreement
to launch a project to boost power supply in the region. The WAPP
agreement reaffirmed the decision to develop energy production facilities
and interconnect their respective electricity grids. In December 2003,
ECOWAS Heads of State signed the ECOWAS Energy Protocol, which provides
open and non-discriminatory access to power generation sources and
transmission facilities. In order to fully establish the WAPP within
ECOWAS, project managers have identified four phases of the project that
will be carried out over a 20-year period. The first phase involves laying
the ground rules for how the WAPP will function and linking
interconnection lines between zone A countries (Burkina Faso,
Côte d'Ivoire, Ghana, Niger and Togo) and zone B countries
(Cape Verde, the Gambia, Guinea, Guinea Bissau, Liberia, Mali,
Senegal and Sierra Leone). Completion of the first phase is set for
the end of 2006. The second phase (2007 – 2012) includes building missing
links along Nigeria’s coastal line, development of new institutional
entities and implementing policies from phase one. Phases three and four
(2012 – 2023) involve making the system fully operational.
USAID
has funded the planning for WAPP which included (1) ECOWAS Vision
Statement and Action Plan for WAPP (2) agreements on rules for trading
electricity (3) regional regulatory body (4) dispute resolution mechanism
(5) mechanisms for cooperation to maintain grid stability and (6) training
in energy modeling and forecasting. The World Bank has committed a $350
million credit for the development of WAPP. Of this amount, $40 million
has been secured by Ghana to implement the 330 kv Aboadze-Volta
transmission line. USAID-funded implementing partners working with ECOWAS
and national utility corporations include PA Consulting, Nexant,
Associates for International Resources and Development, Purdue University,
and the U.S. Energy Association.
Organization for the Development
of the Senegal River (OMVS)The Organization for the Development of the Senegal River (OMVS),
which consists of Mali, Mauritania and Senegal, has constructed two dams.
Senegal completed the Diama dam in 1986 and its primary function is to
stop the upstream encroachment of seawater from the Atlantic Ocean. In
1987, Mali completed the Manatali dam, which OMVS built on the Bafing
River, the main tributary of the Senegal River. The Manatali project was
also to include a 200-MW power station and an 800-mile network of
transmission lines to the capitals of Mali (Bamako), Mauritania
(Nouakchott) and Senegal (Dakar). Cost overruns, coupled with political
and military tensions between Mauritania and Senegal initially canceled
the construction of the power facilities. In March 2000, ADB approved a
$33.5 million loan for the Manatali energy project. The Manatali's
generating facilities came online in December 2001, supplying power to
Mali's grid. Senegal connected its power grid to Manatali in July 2002 and
Nouakchott was connected in November 2002. The OMVS signed a new charter
in May 2002 to allocate water resources and hydroelectric power, and
approved the restructuring of the Manatali Water Management Company
(SOGEM). SOGEM will maintain ownership of infrastructure and equipment at
Manatali, but Eskom will handle marketing and distribution of power
generated at Manatali.
Since 2004, OMVS has been conducting a feasibility study on the
construction of the Felou hydroelectric power plant (60 MW) in Mali. In
February 2006, the European Commission and the European Investment Bank
set up a trust fund for infrastructure in Africa that is expected to
finance the construction of the Felou power plant and an interconnection
between grids in Malawi and Mozambique. The trust fund has a $422 million
budget, which will be coupled with loans from the European Bank.
Organization for the Development
of the River Gambia (OMVG)In 2004, the ADB agreed to issue a $5.4 million grant to finance the
study on electricity production and transmission to the member states of
the Organization for the Development of the River Gambia (OMVG), a
regional organization whose members are The Gambia, Guinea, Guinea Bissau
and Senegal. The focus of the study will be the Sambangalou hydroelectric
project on the Gambia River in The Gambia, the Kaleta dam on the Konkoure
River in central Guinea, and regional integration of power grids in the
four countries. A larger production of hydropower is set to help end the
persistent problem of power shortages and the heavy dependence on imported
petroleum products for the production of electricity.
|
Table 1: Economic and Demographic Indicators | |||||
|
Country |
Gross Domestic Product (GDP), 2005E (Billions of U.S. $) |
Real GDP Growth Rate, 2005E (percent) |
Real GDP Growth Rate, 2006F (percent) |
Per Capita GDP, 2005E |
Population 2005E (millions) |
|
Benin |
$4.3 |
4.8 |
5.2 |
$604 |
7.1 |
|
Burkina Faso |
$5.2 |
3.5 |
4.2 |
$407 |
12.7 |
|
Cape Verde |
$1.1 |
5.9 |
6.2 |
$2,136 |
0.5 |
|
Cote d’Ivoire |
$16.3 |
1.1 |
2.2 |
$937 |
17.3 |
|
Gambia |
$0.5 |
4.5 |
4.7 |
$348 |
1.5 |
|
Ghana |
$10.2 |
5.7 |
5.9 |
$484 |
21.0 |
|
Guinea |
$3.0 |
3.0 |
3.3 |
$357 |
8.2 |
|
Guinea-Bissau |
$0.3 |
2.3 |
2.8 |
$223 |
1.4 |
|
Liberia |
$0.5 |
7.5 |
6.8 |
$137 |
3.6 |
|
Mali |
$5.3 |
5.8 |
6.2 |
$441 |
12.1 |
|
Niger |
$3.3 |
3.5 |
3.8 |
$268 |
12.5 |
|
Nigeria |
$78.0 |
5.9 |
6.4 |
$611 |
127.7 |
|
Senegal |
$8.1 |
5.8 |
5.2 |
$780 |
10.4 |
|
Sierra Leone |
$1.1 |
6.9 |
6.3 |
$205 |
5.5 |
|
Togo |
$2.1 |
2.8 |
3.5 |
$417 |
5.1 |
|
Regional Total/Weighted Average |
$139.3 |
5.0 |
5.5 |
$624 |
246.6 |
|
Source: Global Insight | |||||
|
Table 2: Total Energy and Carbon Dioxide Emissions, 2003 | ||||
|
Country |
Total Energy Consumption, (Quadrillion Btu) |
Total Energy Production, (Quadrillion Btu) |
Net Energy Exports, (Quadrillion Btu) |
Carbon Dioxide Emissions (Million metric tons of carbon equivalent) |
|
Benin |
0.026 |
0.001 |
-0.025 |
0.47 |
|
Burkina Faso |
0.018 |
0.001 |
-0.017 |
0.31 |
|
Cape Verde |
0.002 |
0.000 |
-0.002 |
0.04 |
|
Cote d’Ivoire |
0.101 |
0.136 |
0.035 |
1.46 |
|
Gambia |
0.004 |
0.000 |
-0.004 |
0.08 |
|
Ghana |
0.126 |
0.061 |
-0.065 |
1.49 |
|
Guinea |
0.022 |
0.004 |
-0.018 |
0.36 |
|
Guinea-Bissau |
0.005 |
0.000 |
-0.005 |
0.10 |
|
Liberia |
0.007 |
0.000 |
-0.007 |
0.14 |
|
Mali |
0.015 |
0.007 |
-0.008 |
0.17 |
|
Niger |
0.016 |
0.005 |
-0.011 |
0.33 |
|
Nigeria |
0.985 |
5.604 |
4.619 |
25.49 |
|
Senegal |
0.066 |
0.002 |
-0.064 |
1.24 |
|
Sierra Leone |
0.014 |
0.000 |
-0.014 |
0.26 |
|
Togo |
0.019 |
0.000 |
-0.019 |
0.34 |
|
Regional Total |
1.426 |
5.821 |
4.395 |
32.28 |
|
Sources: EIA, International Energy Annual, 2003 | ||||
|
Table 3: Petroleum Overview | |||||
|
Country |
Petroleum Production, 2005 (Thousand Barrels Per Day) |
Petroleum Consumption, 2005 (Thousand Barrels Per Day) |
Net Petroleum Exports, 2005 (Thousand Barrels Per Day) |
Crude Oil Reserves, 1/1/2006 (Million Barrels) |
Crude Oil Refining Capacity, 1/1/2006 (Thousand Barrels Per Day) |
|
Benin |
0 |
14 |
-14 |
8.2 |
0.0 |
|
Burkina Faso |
0 |
8 |
-8 |
0.0 |
0.0 |
|
Cape Verde |
0 |
1 |
-1 |
0.0 |
0.0 |
|
Cote d’Ivoire |
57 |
18 |
12 |
100.0 |
65.2 |
|
Gambia |
0 |
2 |
-2 |
0.0 |
0.0 |
|
Ghana |
6 |
45 |
-39 |
16.5 |
45.0 |
|
Guinea |
0 |
9 |
-9 |
0.0 |
0.0 |
|
Guinea-Bissau |
0 |
3 |
-3 |
0.0 |
0.0 |
|
Liberia |
0 |
4 |
-4 |
0.0 |
15.0 |
|
Mali |
0 |
4 |
-4 |
0.0 |
0.0 |
|
Niger |
0 |
6 |
-6 |
0.0 |
0.0 |
|
Nigeria |
2,633 |
321 |
2,105 |
35,876 |
438.8 |
|
Senegal |
0 |
34 |
-34 |
0.0 |
27.0 |
|
Sierra Leone |
0 |
7 |
-7 |
0.0 |
10.0 |
|
Togo |
0 |
11 |
-11 |
0.0 |
0.0 |
|
Regional Total |
2,696 |
487 |
1,975 |
36,000.7 |
601.0 |
|
Sources: Energy Information Administration, Oil and Gas Journal | |||||
|
Table 4: Natural Gas Overview (Billion Cubic Feet) | |||
|
Country |
Production, 2003 |
Consumption, 2003 |
Reserves, 1/1/2006 |
|
Benin |
0 |
0 |
40 |
|
Burkina Faso |
0 |
0 |
0 |
|
Cape Verde |
0 |
0 |
0 |
|
Cote d’Ivoire |
50 |
46 |
1,000 |
|
Gambia |
0 |
0 |
0 |
|
Ghana |
0 |
0 |
840 |
|
Guinea |
0 |
0 |
0 |
|
Guinea-Bissau |
0 |
0 |
0 |
|
Liberia |
0 |
0 |
0 |
|
Mali |
0 |
0 |
0 |
|
Niger |
0 |
0 |
0 |
|
Nigeria |
680 |
262 |
184,660 |
|
Senegal |
2 |
2 |
0 |
|
Sierra Leone |
0 |
0 |
0 |
|
Togo |
0 |
0 |
0 |
|
Regional Total |
732 |
310 |
186,540 |
|
Sources: Energy Information Administration, Oil and Gas Journal | |||
|
Table 5: Electricity Overview, Billion Kilowatthours except where noted | |||||
|
Country |
Consumption, 2003 |
Generation, 2003 |
Installed Capacity, 1/1/2003 (gigawatts) |
Thermal Capacity (percent of total) |
Hydroelectric Capacity (percent of total) |
|
Benin |
0.54 |
0.07 |
0.12 |
44.2 |
55.8 |
|
Burkina Faso |
0.35 |
0.38 |
0.12 |
73.3 |
26.7 |
|
Cape Verde |
0.04 |
0.04 |
0.01 |
100.0 |
0.0 |
|
Cote d’Ivoire |
3.42 |
5.13 |
0.92 |
33.3 |
66.7 |
|
Gambia |
0.13 |
0.14 |
0.03 |
100.0 |
0.0 |
|
Ghana |
5.08 |
5.36 |
1.31 |
9.8 |
90.2 |
|
Guinea |
0.72 |
0.78 |
0.28 |
50.4 |
49.6 |
|
Guinea-Bissau |
0.05 |
0.06 |
0.02 |
100.0 |
0.0 |
|
Liberia |
0.47 |
0.51 |
0.33 |
100.0 |
0.0 |
|
Mali |
0.76 |
0.82 |
0.28 |
46.4 |
53.6 |
|
Niger |
0.26 |
0.23 |
0.11 |
100.0 |
0.0 |
|
Nigeria |
14.46 |
15.59 |
5.89 |
67.1 |
32.9 |
|
Senegal |
1.24 |
1.33 |
0.24 |
100.0 |
0.0 |
|
Sierra Leone |
0.24 |
0.26 |
0.12 |
96.7 |
3.3 |
|
Togo |
0.65 |
0.17 |
0.04 |
92.5 |
7.5 |
|
Regional Total |
28.41 |
30.87 |
9.82 |
57.8 |
42.2 |
|
Sources: EIA, International Energy Annual, 2003 | |||||
African Development Bank
African Union (AU)
BBC News: Africa
CNN News: Africa
Country Pages for the African Studies Program at the Univ. of Pennsylvania
Economic Community of West African States
International Finance Corporation Sub-Saharan Africa
Mbendi Information Services
New Partnership for African Development (NEPAD)
Regional News from AllAfrica.com
United Nations Economic Commission for Africa (ECA)
Washington Post Africa Section
West African Economic and Monetary Union (UEMOA)
West Africa News
West Africa Review
World Bank: Africa Region Secti
Foreign Government Agencies
Benin
Burkina Faso
Cape Verde
Cote d'Ivoire
Gambia
Ghana
Guinea
Liberia
Mali
Mauritania
Niger
Nigeria
Senegal
Sierra Leone
Togo
Oil and Natural Gas
Canadian Natural Resources (Cote d'Ivoire)
Dana Petroleum (M
ENI/Agip:
Fusion Oil:
Ghana National Petroleum Corp. (GNPC)
Hardman Resources (Mauritania)
Nigeria LNG (NLNG)
Ocean Energy (Cote d'Ivoire
Petronas (Benin, Mauritania, Niger, & Togo)
Petrosen (Senegal)
Premier Oil (Guinea-Bissau)
Roc Oil (Mauritania)
Shell (Nigeria)
SIR (Cote d'Ivoire)
Vanco Energy: Cote d'Ivoire
Electricity
NEPA (Nigeria)
OMVS (Mali, Mauritania, Senegal)
SENELEC (Senegal)
Perdue University: West African Power Pool (WAPP) Project
Volta River Authority (Ghana)
Africa News Service
CIA World Factbook 2005
Dow Jones
Economist Intelligence Unit ViewsWire
Factiva
Global Insight
International Monetary Fund
Oil and Gas Journal
Petroleum Intelligence Weekly
Panafrican News Agency
Reuters
U.S. Energy Information Administration
World Bank