new base special 05 february 2014 (recovered)

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NewBase 05 February 2014 Khaled Al Awadi

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TAQA AND FEWA TO DEVELOP WATER DESALINATION PLANT IN AJMAN By Taqaglobal.com – Press release 04 Feb 2014

Abu Dhabi, United Arab Emirates – TAQA, the international energy and water company from Abu Dhabi, has signed a Memorandum of Understanding with Federal Electricity & Water Authority (FEWA) to develop a standalone seawater desalination plant in Al Zawra in the Emirate of Ajman.

The agreement was signed in Abu Dhabi by H.E. Mohammed Mohammed Saleh, Director General of FEWA and Carl Sheldon, CEO of Abu Dhabi National

Energy Company PJSC (TAQA). in the presence of H.E. Suhail Mohammed Al Mazrouei, UAE Minister of Energy and Chairman of Federal Electricity & Water Authority (FEWA) and H.E. Hamad Al-Hurr Al-Suwaidi, Chairman of TAQA. Al Zawra independent water project (IWP) will have a capacity of 30 million imperial gallons per day (MIGD), enough to supply 250,000 people in the Northern Emirates with clean drinking water.

H.E. Suhail bin Mohammed Al Mazrouei, the UAE Minister of Energy and Chairman of the Board of Directors of the Federal Electricity and Water Authority, said: “The Al Zawra project demonstrates the UAE’s determination to develop and apply new technologies that will protect the security of water supply while actively working towards greater energy efficiency.” H.E. Hamad Al-Hurr Al-Suwaidi, Chairman of the Board of Directors of TAQA, said: “At a time of strong demographic and economic growth across the UAE, and particularly in the Northern Emirates, this project will ensure that sufficient water infrastructure is in place to meet increasing demand.”

H.E. Mohammed Mohammed Saleh, Director General of FEWA, commented: "The Northern Emirates are developing at an increasing pace and the demand for water will continue to grow. FEWA has allocated significant funds for developing water and electricity projects there, over the coming three years. Al Zawra is a crucial element in that strategy.” The Ajman facility will use the reverse osmosis process, where salt and impurities are removed from the water by pushing it through a semi-permeable membrane. Unlike most of the UAE’s existing desalination capacity, which is based on thermal technologies and tied to power plants, reverse osmosis plants run on electricity. This means they can be run more efficiently and located close to consumption areas, enhancing the security of water supply.




According to the development plan, the project would be owned by FEWA and TAQA, underpinned by a long-term water purchase agreement with FEWA and funded with project finance. Construction is expected to start in early 2015 and the plant would begin commercial operations in 2017. TAQA, one of the largest desalination companies in the world, is majority owner of eight power and water plants across the UAE supplying 98% of Abu Dhabi’s power and water requirements. TAQA’s plants also supply the Emirates of Fujairah, Umm Al Quwain and Sharjah with clean water. FEWA has reverse osmosis desalination plants in the emirate of Ajman, Ras Al Khaimah and Umm Al Quwain with a total production capacity of 50 MIGD.

About TAQA

TAQA, meaning energy in Arabic, is the brand name of Abu Dhabi National Energy Company PJSC. We are an international energy and water company listed in Abu Dhabi operating in 11 countries across four continents.

We strive to be safe and sustainable, and embrace the challenge of delivering affordable and reliable energy and water. We are proud to align our strategy with Abu Dhabi’s Economic Vision 2030, a roadmap for a sustainable economy with a focus on knowledge-based industry.

Our interests lie in conventional and alternative power generation, water desalination, oil and gas exploration and production, pipelines and gas storage. We operate in Canada, Ghana, India, Iraq, Morocco, the Netherlands, Oman, Saudi Arabia, the United Arab Emirates, the United Kingdom and the United States.

For details about FEWA , http://www.fewa.gov.ae

FEWA , Al zawra power plant in Ajman , currently with 2 F9 GE gas turbines running in Open cycle .




Qatargas 3 signs SPA with Japan’s Tohoku Electric http://www.gulf-times.com/business

Qatargas 3 has entered into a new long term LNG Sale and Purchase Agreement (SPA) with Tohoku Electric, under which the Qatari LNG major will supply liquefied natural gas to the

Japanese firm.

Under the terms of the SPA, Qatargas 3 will deliver LNG to Tohoku Electric for a period of 15 years beginning 2016, building up to a plateau volume of 0.18mn tonnes per year (tpy) from 2019. The LNG will be supplied from Qatargas 3 (Train 6), a joint venture between Qatar Petroleum, ConocoPhillips and Mitsui & Company, which started production in January 2010, and will be delivered on board Q-Flex LNG vessels.

The agreement was signed by HE the Minister of Energy and Industry, Dr Mohamed bin Saleh al-Sada, also Qatargas 3 chairman and Makoto Kaiwa, representative director and president of Tohoku Electric.

Al-Sada welcomed the agreement and described it as “another contribution towards global energy security.” “This agreement reinforces our strong relationship with one of Qatargas’ foundation customers and demonstrates our continued commitment to long-term LNG supplies to Japan. As the largest LNG producing company in the world, Qatargas is committed to providing reliable energy supplies to all four corners of the world,” al-Sada said.

Qatargas Trains 6 and 7 facilities in Ras Laffan City




Qatargas chief executive officer Sheikh Khalid bin Khalifa al-Thani said: “Today, we have achieved a significant milestone in our excellent partnership with Tohoku Electric, which started in 1994 when we signed an agreement with a consortium of Japanese buyers, including Tohoku Electric. This agreement is further testimony of our long-term commitment to Japan and reinforces Qatargas’ global reputation as a safe and reliable supplier of LNG. We remain committed to supporting Japan’s continuous requirement for stable energy supplies.”

Tohoku Electric is one of the original eight Japanese buyers, which signed contracts with the Qatargas 1 joint venture in 1994. In December 2007, Tohoku Electric became the first Japanese utility company to receive a cargo of LNG on-board a Q-Flex vessel.Following the Great East Japan Earthquake in March 2011 that severely affected the Tohoku Region, Qatargas supplied increased volumes of LNG to Tohoku Electric to help meet the region’s demand for stable and reliable supplies of energy.

Global transport sector looks to ride LNG boom Reuters/London

Natural gas has started to challenge oil as the dominant transport fuel with companies building gas-powered ships and installing networks of service stations on water and land. The expectation of cheaper gas and tighter environmental regulation have created demand for a cleaner alternative to the oil-based fuels that have so far dominated the transport world. Although European and Asian liquefied natural gas (LNG) prices are currently high, trading at almost $20 per million British thermal unit (mmBtu) in Asia and around $10 per mmBtu in Europe because of booming demand, analysts expect prices to drop substantially later this decade when new production rises.




Germany, Singapore and the Netherlands are among the countries investing in natural gas transport hubs while companies including Royal Dutch Shell, Gazprom and Total, are also developing LNG fuel infrastructure. Germany is making its first move into LNG for transport after Bomin Linde LNG signed a deal in January to supply ferry firm AG EMS and it is now building two LNG bunker terminals in Hamburg and Bremerhaven, due to start operations in 2015. “Supplying their ferries with LNG makes AG EMS a pioneer in Germany and sends a clear signal that this low-emission propulsion system has arrived here,” said Ruben Benders, managing director at Bomin Linde LNG. In the Dutch port of Antwerp, Europe’s second largest, the harbour authority says that there are “all kinds of initiatives” through which the use of LNG as fuel for shipping is encouraged. At Rotterdam, Europe’s biggest port, LNG also plays an increasing role in transport as the Gate LNG import terminal has begun supplying local river vessels and port tugs, as well as sending it on for use in the Baltic Sea where LNG is also seeing a pick-up in the marine sector. In Asia, Singapore has invested in LNG bunkering capacity in anticipation of rising demand from large ships. Singapore’s motivation to enter the gas for transport sector is driven by the expectation of huge growth in China, currently still a small user of natural gas, but where new regulation is aimed at shifting the power generation sector from coal to gas and the transport sector from oil towards more gas use. Energy consultancy Wood Mackenzie says global gas demand in the transport sector could grow from under 5bn cubic metres (bcm) in 2012 to over 160 bcm by 2030, which would be equivalent to two years’ worth of current British gas demand or around 3mn barrels of oil. “Gas has traditionally played a niche role in global transport but it is now garnering greater attention,” said Noel Tomnay, head of research at Wood Mackenzie. “Oil and gas price differentials are now making investment in gas re-fuelling infrastructure




worthwhile and... increased environmental restrictions on emissions are encouraging wider global uptake.” Various new regulations on sulphur emissions in the shipping sector will come into place for much of the North and Baltic Sea as well as the US and Canada in 2015, which has driven interest in alternative fuels to diesel. In North America, LNG is also gaining traction on land as a shale gas boom has led to a 50% drop in US gas prices since 2008, making it competitive with oil in the transport sector. Shell and TravelCenters of America are developing a network of LNG truck fuel stations that will allow US coast-to-coast LNG-fueled road transport within a few years. “Gas is cleaner and gas is cheaper - at least for now,” said Bruce Carlton, president and chief executive of the US National Industrial Transportation League, a trade association. “We are seeing a lot of attention being given to conversions to gas/LNG in the USA... Rail is probably a bit behind, but very interested in it as well,” he said.

Tucker Gilliam of US transport and logistics group Crowley Liner Services, whose firm has ordered two LNG-powered vessels to operate between the US and Puerto Rico, said LNG for transport would gain further traction. “As more is invested in infrastructure to produce and deliver the fuel, there will be greater opportunities for wider scale adoption,” he said. He added that for Crowley, the driving force were “significant environmental benefits”.




BP and China sign methanol plants at Port of Kalama and Port Westward http://www.2b1stconsulting.com

The UK super major BP and China Academy of Sciences created a cascade of joint venture called Clean Energy Technology Company to run the Northwest Innovation Works joint venture, a newly formed company, to build and operate twin major greenfield methanol plants at Port of Kalama in Washington, and at Port Westward in Oregon, USA.

With a total capital expenditure of $3.6 billion, BP and China Academy of Sciences intend to use the gas-to-methanol conversion to facilitate the export of natural gas to China. The newly formed

joint venture Northwest Innovation Works selected the Port of Kalama and Port Westward because of their ideal position along the lower Columbia River. On both locations, BP and China Academy of Sciences have identified 80-acre sites that could fit perfectly to host these greenfield methanol plants.

At Port of Kalama, BP and local Authorities are focusing on large available space along the existing Steelscape mill. In Port Westward, BP and local Authorities are still evaluating best options to set the Northwest Innovation Works close to the Columbia River.

In building these twin methanol facilities on the US west coast, BP and China Academy of Sciences are willing to measure at large scale the environmental and financial benefits to export natural gas under the methanol form compared with the export of conventional liquefied natural gas (LNG) and the domestic production of methanol from coal.

In this particular project China is targeting to use this methanol-converted gas as feedstock for its petrochemical industry on the China east coast. The China Academy of Sciences involvement in this project is to represent all the Chinese research institutes and share all the experienced




acquired through this project. The the second joint venture Northwest Innovation Works has been established to welcome other investors directly interested in this export line of competitive natural gas out of the US shale gas.

Dalian to build Lianing methanol import terminal

The City of Dalian in the Lianing Province is one of these investors as most of the exported methanol-converted gas will be used to feed its local petrochemical industry to produce olefin.

Another partner is coming from USA with the H&Q Asia Pacific private equity company, based in the Silicon Valley and well introduced in China.

In this context, BP and China Academy of Sciences are planning to invest the $3.6 billion capital expenditure in phases.

Each methanol plant will require $1.8 billion capital expenditure and will be opened for a second phase expansion.

The Northwest Innovation Works twin facilities will have a production capacity of 5,000 tons per day (t/d) of methanol each.

This methanol will be exported to Dalian in China with 50,000 tons Panamax ships. On the Chinese east coast, the City of Dalian will build storage facility to receive the methanol with a capacity of 8 million tons.

As usual with Chinese driven projects, their implement is planned on fast track, so that BP and China Academy of Sciences are expecting the Northwest Innovation Works methanol-converted gas to come on stream in 2018 with the expansion phase to start in following at Port of Kalama, Washington and Port Westward, Oregon, USA.




Lundin rig on the way to drill in Indonesia http://www.upstreamonline.com/live/article1351285.ece

Swedish player Lundin Petroleum has started towing the Haluryu-1 jack-up rig to the site of the first well it

will drill in Indonesia.

The rig will be used by Lundin to drill the Balqis-1 well in the Baronang production sharing contract in

Indonesia. Joint venture partner Nido Petroleum announced the start of the tow and added it would update

the market once drilling operations start at the well.

After Balqis-1 is drilled, the rig will drill the Boni-1 well which will be drilled as an exploratory side-track

well from the same surface location. The delivery of the rig was delayed by bad weather in Vietnam where

the rig was stationed.

Both wells are designed to test the pre-Miocene basement basin margin play. Balqis-1 has best prospective

resource of 46.6 million barrels of oil, while Boni-1 has best prospective resources of 55 million barrels.




Pollution from Canada's oil sands underestimated, Voice of Russia, Futurity, Edmonton Journal

Extracting petroleum from oil sands in a region of Alberta, Canada, may result in much greater risks than previously suggested. According to a new assessment, officially reported emissions of certain highly hazardous air pollutants have been grossly underestimated.

The team modeled emissions of a group of atmospheric pollutants known as polycyclic aromatic hydrocarbons

(PAHs). Many PAHs are highly carcinogenic. Children born from women who were exposed to PAHs while

pregnant may have lower IQs, a higher risk of asthma, and other issues.

“When dealing with chemicals that have such great potential to harm people and animals, it is absolutely vital

that we truly understand how, and how much they are being released into the environment,” says Abha

Parajulee, a PhD candidate at the University of Toronto Scarborough and lead author of the paper published in

the Proceedings of the National Academy of Science.

PAHs are produced during the process of extracting petroleum from the oil sands. Previous models have

assessed only the PAHs that are released directly into the atmosphere during extraction. These numbers tend to

fall within acceptable regulatory levels.

Parajulee’s model takes into account other indirect pathways for the release of PAHs that haven’t been

assessed before. For instance, he found that evaporation from tailing ponds—lakes of polluted water also

created through oil extraction—may actually introduce more PAHs into the atmosphere than direct emissions.

“Tailing ponds are not the end of the journey for the pollutants they contain. PAHs are highly volatile, meaning

they escape into the air much more than many people think,” says Parajulee. The higher levels of PAHs the

scientists’ model predicts are consistent with what have actually been measured in samples taken from areas

near and in the Athabasca Oil Sands Region.

The new model also factors in additional PAHs that are released during the transport and storage of other waste

materials from oil sands operations. The researchers modeled only three types of PAHs, which they believe are

representative of many other types of air pollutant. Still, they say, their model indicates better monitoring data

and emissions information could improve our understanding of the environmental impact of the oil sands even

further.

Oil sands facility in Alberta The Canadian

province of Alberta has vast oil sand reserves.




“We need to take a holistic approach that includes both modeling and monitoring,” says Frank Wania, an

environmental chemistry professor, who collaborated with Parajulee on the analysis. “This is the single most

powerful way to inform public policy and private management strategies for the region.”

Human health & PAHs :-

The toxicity of PAHs is structure-dependent. Isomers (PAHs with the same formula and number of rings) can vary from being nontoxic to extremely toxic. One PAH compound, benzo[a]pyrene, is notable for being the first chemical carcinogen to be discovered (and is one of many carcinogens found in cigarette smoke). The EPA has classified seven PAH compounds as probable human carcinogens: benz[a]anthracene,

benzo[a]pyrene, benzo[b]fluoranthene, benzo[k]fluoranthene, chrysene, dibenz(a,h)anthracene, and indeno(1,2,3-cd)pyrene.

PAHs known for their carcinogenic, mutagenic, and teratogenic properties are benz[a]anthracene and chrysene, benzo[b]fluoranthene, benzo[j]fluoranthene, benzo[k]fluoranthene, benzo[a]pyrene, benzo[ghi]perylene, coronene, dibenz(a,h)anthracene (C

20H

14), indeno(1,2,3-cd)pyrene (C

22H

12), and ovalene.

High prenatal exposure to PAH is associated with lower IQ and childhood asthma. The Center for Children's Environmental Health reports studies that demonstrate that exposure to PAH pollution during pregnancy is related to adverse birth outcomes including low birth weight, premature delivery, and heart malformations.

Cord blood of exposed babies shows DNA damage that has been linked to cancer. Follow-up studies show a higher level of developmental delays at age three, lower scores on IQ tests and increased behaviorial problems at ages six and eight.

In addition, a 2012 Columbia University study in Environmental Health Perspectives linked prenatal exposure to pollutants and eventual child behavioral outcomes. The study found that exposure to higher levels of PAH was associated with a 24% higher score of anxiety/depression for children ages 6 to 7 than those with low exposure levels. Infants found to have elevated PAH levels in their umbilical cord blood were 46% more likely to eventually score highly on the anxiety/depression scale than those with low PAH levels in cord blood.




French trade delegation in Iran to boost business ties Voice of Russia, AFP

A French trade delegation arrived in Tehran Monday to try to restore business ties with Iran, ahead of a possible comprehensive nuclear deal between the Islamic republic and world powers.

Some 107 representatives from the French employers' union Medef travelled to Iran, with official news agency IRNA calling it the biggest "French and European economic and business delegation" to visit the country. A deal reached with world powers on Iran's nuclear programme - which the West charges is aimed at developing an

atomic bomb, which Tehran denies - in November has raised hopes biting Western sanctions on the oil-rich country could be lifted. "A new chapter has opened in the relations of Iran and Europe," IRNA quoted Mohammad Nahavandian, President Hassan Rouhani's chief of staff, as saying. While no contracts will be signed during the trip because of the international sanctions still in place, the visit is seen as a first step towards regaining a foothold in the country. Thierry Courtaigne, vice president of Medef, told AFP that the business delegates "were informed from the start about the visit, about the interim agreement. You don't play around with reality". The visit, which comes after delegations from Italy, Germany, Austria, Portugal and South Korea travelled to Iran, will last until Wednesday. The French trade delegates are slated to meet their Iranian counterparts on Tuesday, but no meetings have been scheduled with politicians. The delegation includes representatives from top French businesses, such as automobile giants Peugeot and Renault, major players in Iran's auto industry until last year, as well as energy giant Total.

About : MEDEF

Founded in 1989, MEDEF International is a non-profit private-funded organisation, chaired by Mr Jean BURELLE, CEO of BURELLE SA (20.000 employees throughout the world) and Honorary Chairman of PLASTIC OMNIUM Company.

MEDEF International is the most representative organisation of the French private sector at an international level: it represents the French Business Confederation (MEDEF) and its 800.000 companies, in the world.

It gathers more than 4.000 French companies already operating in the world, in 71 Business Councils headed by 41 CEOs of major international French companies.

MEDEF International is the Private Sector Liaison Officer for the World Bank, the EBRD, the ADB, the IDB and other Development Banks and International organisations .

MEDEF International promotes the know-how and supports trade and investments by French companies in the world.

MEDEF International relates international French companies with the world public and private decision-makers to enlarge or found new sustainable and long-term partnerships between French and foreign companies .

MEDEF International eases direct and constructive dialogue at the highest level, with heads of State and Government.

MEDEF International fosters improvements in the governance and business climate.

MEDEF International runs over 135 high-level meetings each year, in Paris and abroad .




Total sells its 15% in Angolian Block 15/06 to Sonangol www.Total.com

Total announces the sale of its 15% participating interest in the offshore Angola Block 15/06 to Sonangol

E&P. The transaction is valued at 750 million dollars and remains subject to customary approvals.

“The sale of our interest in Block 15/06 is in line

with Total’s global strategy to actively manage

its portfolio and focus its investment capability

on core assets in which it has more material

interests, such as Block 17 with the CLOV

project currently under development and the

future development of Kaombo on Block 32 in

Angola” said Jacques Marraud des Grottes,

Senior Vice-President Africa at Total’s

Exploration and Production.

Block 15/06

Block 15/06 is located approximately 350 km

northwest of Luanda in deep offshore Angola

and covers approximately 2,984 square

kilometres, with a water depth ranging from

220 to 1,700 m.

The north-western hub of the block, currently

under construction, is expected to produce in

2015 and a final investment decision for a

north-east project is expected to be taken in

2014.

The block is operated by Eni (35%) with partners Total (15%), Sonangol (15%), SSI (a joint affiliate of

Sinopec and Sonangol, 25%), Statoil (5%) and Falcon Oil Angola Investimentos (5%).

Total Exploration & Production in Angola

Total has been present in Angola since 1953. In 2013, Total’s SEC* equity production amounted to 186,000

barrels of oil equivalent per day (boe/d). Most of this production comes from Blocks 17, 0 and 14. At the

end of 2013, Total’s operated production was around 600,000 boe/d, making it the country’s leading oil

operator.

Block 17, where the Group is operator with a 40% interest, is Total's main asset in Angola. The block

contains four major hubs: Girassol-Rosa, Dalia and Pazflor, which are currently in production; and CLOV

pooling the discoveries of Cravo, Lirio, Orquidea and Violeta. CLOV’s development was launched in 2010

and is expected to start-up in 2014.

Total is also operator of the ultra-deepwater Block 32, in which it holds a 30% stake. Twelve discoveries

have confirmed the block's potential for oil production, and studies are underway for a development in the

central southeastern sector of the block, the Kaombo development project.




In addition, the Angola LNG project (Total 13.6%), near Soyo, is bringing the country’s natural gas reserves

to market. The LNG plant will initially be supplied with associated gas from fields on blocks 15, 17 and 18

and later on from gas fields on blocks 0 and 14.

In Angola, as in all its host countries, the Group ensures that health, safety and environment are

paramount priorities. Moreover, Total is committed to developing the Angolan oil industry by recruiting

and training local workforce. Total is strengthening the local economy through its ambitious

“Angolanization” and technology transfer plan. Total E&P Angola implements a transparent, wide-reaching

corporate social responsibility process focused on three main areas: health, education and local economic

development.

“Total, as one of the major International Oil Companies, has been a permanent partner of Sonangol in the

development of oil resources since 1952. Our goal is to reinforce this

partnership in the years to come by developing the discovered field, by

replacing the produced reserves through exploration of new acreage and

new geological themes and by developing the human resources of the

company. A large part of the work which covers all the steps from

exploration to production is performed locally by Total’s staff. One of our

main objectives is to make Angolanization a success by sharing our

expertise and knowledge with our local staff and with the concessionaire

Sonangol. To sustain an increase of production and staff of more than 60% in the coming years, an

adequate training program has been set up for the new hired staff and to

reinforce the expertise of our present staff. Achieving this program with

the partnership of Sonangol and the Ministry of Petroleum, will be the

key of our future and one step further for the future of oil industry in

Angola.”

The project has seven dedicated vessels, according to the

website of Angola LNG Supply Services LLC, the affiliate

providing transportation. Chevron Corp. is the project’s

largest stakeholder with 36.4 percent, followed by state-

owned Sonangol EP with 22.8 percent and Total, BP Plc

and Eni SpA with 13.6 percent each, according to Angola

LNG’s website.




Italian PM Discusses Possibility of Qatari Investment in Eni Robert Tuttle and Anthony DiPaola http://oilandgas.einnews.com/

Italy’s Prime Minister Enrico Letta discussed with Qatar the possibility of investing in Eni SpA as the European country seeks to cut debt by selling state assets.

Qatar might add capital to the Rome-based company under a deal, Letta said in Doha. Italy owns the biggest stake in the oil producer, which rebounded from lows today in Milan trading. Letta said he thanked the Middle Eastern country for “the bilateral discussions we had about Eni, the possibility of an investment by Qatar, new investment in Eni capital.”

A team from the Qatar Investment Authority will go to Italy to discuss investing “in different sectors,” said Mohammed Al- Sada, the Arabian Gulf state’s energy minister. Qatar is open to tie-ups with energy and construction companies, he said. Italy plans to sell stakes in some state companies to help reduce debt. In September, Letta’s cabinet committed to a three- year program of tax cuts, infrastructure improvements and changes to the civil justice system to make the country more appealing to foreign investors.

Last month the government said it would sell 40 percent of the state postal service. Letta met with officials in the United Arab Emirates in the past two days to discuss partnerships and investment by Abu Dhabi and Dubai companies in businesses and state ventures, he said late yesterday. He backed talks between Etihad Airways PJSC and Alitalia SpA aimed at determining whether the Arabian Gulf carrier would buy a stake in Italy’s ailing airline. Eni fell 0.2 percent to 16.82 euros by 1:34 p.m. in Milan, paring a decline of as much as 0.8 percent before Letta spoke.

About Eni SpA .

Eni S.p.A. is an Italian multinational oil and gas company headquartered in Rome. It has operations in in 79 countries, and is currently Italy's largest industrial company with a market capitalization of 68 billion euros (US$ 90 billion), as of August 14, 2013. The Italian government owns a 30.3% golden share in the company, 3.93% held through the state Treasury and 26.37% held through the Cassa depositi e prestiti. Another 39.40% of the shares are held by BNP Paribas.[

The name "ENI" was initially the acronym of "Ente Nazionale Idrocarburi" (national hydrocarbons authority). Through the years after its foundation however, it operated in a large number of fields including contracting, nuclear power, energy, mining, chemicals and plastics, refining/extraction and distribution machinery, hospitality industry and even textile industry and news. As exploration and reserve replacement being major drivers for the company, Eni boosts for production additions in its core oil field areas (North and Sub-Saharan Africa,Venezuela, Barents Sea, Yamal Peninsula, Kazakhstan, Iraq and the Far East). Eni has about 130 exploration and production subsidiaries, such as Eni Norge. In 2012 Eni reported liquids and gas production for the full year of 1,701 kboe/d, this being calculated assuming a natural gas conversion factor to barrel equivalent, updated to 5,492 cubic feet of gas equal 1 barrel of oil from July 1, 2012. During 2012 60 new exploratory wells were drilled, as 56 were drilled in 2011 and 47 in 2010. The overall commercial success rate was 40% (40.8% net to Eni) as compared to 42% in 2011 (38.6% net to Eni) and 41% in 2010 (39% net to Eni). In 2012 351 development wells were drilled as well, as 407 in 2011 and 399 in 2011.




Follow up Angola Oil & Gas :- By NewBase auditorial :- Refence from www.eia.gov

Emerging East Africa Energy

Angola is the second-largest oil producer in Sub-Saharan Africa

behind Nigeria, and recent exploration suggests that Angola's reserves may be larger than

initially estimated.

Angola's rapid rise as an energy producer over the past two decades came despite a civil war that lasted until 2002 and without many of the advantages found in other energy-rich regions. In particular, Angola lacked the appropriate infrastructure and the regulatory oversight necessary to operate a modern energy sector. With the end of the Angolan civil war in 2002, and steady investment in the country's energy infrastructure, the future of Angolan production is bright. Challenges remain—notably the tensions in the Cabinda province—but as the demand for oil continues to rebound from the global recession, Angolan crude will be an important resource for China, the United States, and other major energy importers.

Since becoming a member of the Organization of the Petroleum Exporting Countries (OPEC) in 2007, Angola's production levels have been subject to oversight by the group. However, Angola has not always acceded to the group's demands, and Angola's leadership plans to continue boosting production of oil and natural gas over the coming decade to help increase government revenue. In particular, Angola's offshore pre-salt formations and the construction of natural gas-processing facilities are viewed as potentially lucrative sources of future revenues.

Angola's economy is almost entirely dependent on oil production, as oil exports accounted for approximately 98 percent of government revenues in 2011 according to the International Monetary Fund. High international oil prices will be important for the future prospects of exploration, production, and exports of oil and natural gas, and will directly affect Angola's government spending. In recent years, roughly three-quarters of Angola's total government revenues came from the energy sector.

With a gross domestic product (GDP) of over $104 billion in 2011 on the strength of its oil exports, Angola has the third-largest economy in Africa. The International Monetary Fund estimates Angola's GDP per capita in 2011 was approximately $5,900 in current international dollars; however, much of the oil wealth in the country does not find its way to the average citizen, which is one of the reasons why nearly 60 percent of primary energy consumption consists of solid biomass.

The August 2012 presidential election again brought the country's energy sector into the public discourse, as the

management of profits from the export of crude oil became an issue of some importance. Over the past decade, Angola made progress towards better capturing and distributing the profits associated with its




hydrocarbon industries—notably through its Oil Investment Fund—but opposition voices disagree on the level of success the country has made. A policy of "Angolanization" intends to help the Angolan populace become more integrated into the country's energy sector, and to obtain a greater share of the wealth being generated by the country's oil exports. Additionally, in October of 2012 plans for a $5 billion sovereign wealth fund were announced. While such programs have not yet achieved great success, Angolans remain optimistic that the government's efforts will succeed.

Oil

Successful exploration in Angola's pre-salt formations continues to drive optimistic oil

production forecasts for the country, and the Angolan government is targeting 2 million barrel

per day production levels by 2014.

According to Oil & Gas Journal estimates for the end of 2011, Angola had proved reserves of 9.5 billion barrels of crude oil. That figure is the second-largest in Sub-Saharan Africa behind Nigeria, and ranks 18th in the world. Angola's crude oil is light and sweet, making it ideal for export to major world markets like China and the United States. Exploration and production in offshore Angola is advancing at a rapid pace, and foreign investors are beginning to consider some onshore opportunities economically viable. Exports continue to drive Angolan oil production, but the development of new refining capacity could help ease domestic demand shortages that have plagued the country since the end of the civil war in 2002. Prospects for growth in the oil sector are good, but instability and the threat of conflict continue to temper expectations.

Sector organization

In 1976, the government of Angola created a national oil company, the Sociedade Nacional de Combustiveis de Angola (Sonangol). In 1978, Sonangol became the sole concessionaire and majority shareholder in all oil and gas exploration in Angola, and took charge of all petroleum industry activities.

Sonangol operates 17 subsidiaries throughout the oil and natural gas (and related) industries. Key subsidiaries include: Sonangol Pesquisa e Produção (P&P), which undertakes all exploration and production activities for Sonangol in Angola; Sonaref, which runs refining operations in Angola; and Sonagás, which is in charge of the exploration, production, and transportation of natural gas in Angola.

Foreign companies involved in Angola operate under joint venture operations and production-sharing agreements (PSAs) with Sonangol, and major partners include Chevron, ExxonMobil, British Petroleum (BP),

Statoil, Eni, and Total, among others. China's Sinopec and the China National Offshore Oil Corporation (CNOOC) are also involved in Angola, and are providing development assistance as well as oil-backed loans and trade. Sonangol funds its operations though oil-backed borrowing, so finding partners able to provide such services is an important goal for the company.




Sonangol is becoming more involved in international ventures, and the company currently has interests in Brazil, Cuba, Iraq, São Tome and Principe, Venezuela, and in the Gulf of Mexico. Early in 2012, Sonangol pulled out of a natural gas project in Iran after a tightening of US-led sanctions on that country. Nevertheless, Sonangol continues to explore opportunities across the globe as it tries to establish itself as a major international player.

Over the past few years, Angola instituted local-content (notably labor) requirements in its energy sector, but the so-called "Angolanization" regulations have yet to make a sizeable impact. The regulations require international companies operating in the country to meet a 70 percent Angolanization threshold, but to date this figure has rarely—if ever—been met. Despite these requirements, less than 1 percent of Angolans are employed in the energy sector, although the government hopes that will change as the technical capacity of its citizen's increases in the coming years. This may occur through the contributions to training programs that is now required of all international oil companies doing business in Angola. Companies are expected to provide $200,000 per year, per block during the exploration phase of their operations to fund technical training programs, and $0.15 per barrel of oil during the production phase. These regulations are designed to improve the technical and financial capacity of Sonangol, its subsidiaries, and Angola's citizens. In 2011, Angola also passed a law that requires the international oil companies to utilize the services of local banks.

Exploration and production

Exploration in Angola's offshore blocks continues to be successful, and recent forays into onshore blocks have been met with positive results. Angola's position as the second-largest producer of crude oil in Sub-Saharan Africa, and as a member of the OPEC, means that international oil companies are already very familiar with the country's resource endowments. Nevertheless, recent drilling success in Angola's pre-salt formations created a palpable buzz in the industry.

With Angola's crude being sweet (low in sulfur) and light, it is well-suited for exports to the United States, China, and other large importers, and the possibility of significant

hydrocarbon resources in pre-salt formations has potential investors intrigued. This is due to the geological similarities between Angola's pre-salt formations and those of Brazil, which have remained largely unchanged since present-day South America and Africa split 165 million years ago. Because of the similar geology on the east coast of Brazil and the west coast of Angola (and its neighbors), many petroleum geologists believe that the hydrocarbon formations of the two areas will be similar.

Angola's rise as a major oil-producing nation came relatively recently due to the country's long civil war (1975-2002), which restricted exploration in the country. Once Angola began to stabilize its oil production increased dramatically, more than doubling from 896,000 barrels per day (bbl/d) in 2002 to 1.84 million bbl/d of total liquids in 2011. Angola briefly challenged Nigeria as the top oil producer in Sub-Saharan




Africa in 2009, but Angola's total liquid production declined slightly in 2010 and again in 2011. Crude oil production in Angola slipped to 1.79 million bbl/d in 2011, but the additions from new projects like the Kizomba Satellites should help Angola reverse that trend. These declines came as a result of regular maintenance and normal decline in the country's older fields, and Angola's government is targeting a return to the 2 million bbl/d production-levels it achieved in 2008 by 2014.

Major blocks

Angola's offshore assets are divided into 41 blocks, and are separated into three bands: Band A (shallow water blocks 0-13), Band B (deepwater blocks 14-30), and Band C (ultra-deepwater blocks 31-40). While limited exploration is underway onshore, the vast majority of exploration and production comes from Angola's offshore blocks, several of which are discussed below.

Block 0

Located of the coast of the Cabinda province, Block 0 is divided into two Areas (A and B) composed of 21 fields. Total liquid production in 2011 averaged 340,000 barrels per day (bbl/d), approximately 94 percent of which is crude oil. Block 0 is operated by a consortium led by Chevron-subsidiary Cabinda Gulf Oil Company (CABGOC) in partnership with Sonangol Total, and Eni; Chevron holds a 39.2 percent share in Block 0. While some of the fields in Block 0 are beginning to experience natural decline rates, drilling and exploration continue and production gains are expected over the next few years. In particular, the Mafumeira Sul development is expected to boost crude oil production by 110,000 bbl/d starting in 2015. The plan also calls for a new central processing facility, two wellhead platforms, 50 wells, and 75 miles of subsea pipelines, although the final investment decision had not been released to the public as of October 2012.

Block 14

Like Block 0, Block 14 is located off the coast of the Cabinda province, and is made up of several development areas: Kuito, Benguela Belize-Lobito Tomboco (BBLT), Tombua-Landana, Negage, Gabela, Lucapa, and Menongue. Of these development areas, only Kuito, BBLT, and Tombua-Landana are currently producing. Kuito is significant because it was Angola's first deepwater oilfield, and because it is a zero-flare development (many of Angola's operators still flare the majority of the associated gas produced at their oilfields). Nevertheless, production levels continue to decline after reaching a high point of 80,000 bbl/d in 2000. These losses, however, are outweighed by the gains made from bringing the Tombula-Landana development online in 2009, and the continued production at the BBLT fields.




Block 14 began producing in 1999, and in 2011 reached approximately 187,000 bbl/d of liquids (including condensates). Chevron—which holds a 31 percent interest in Block 14, and is the chief operator—is pursuing expansion at several of the fields in Block 14, including the BBLT, Kuito, and Tombua-Landana. With improvements at a number of fields coming online in 2011, production in 2012 is expected to surpass 200,000 bbl/d. Other stakeholders in Block 14 include Sonangol (20 percent), Eni (20 percent), Total (10.01 percent), Inpex (9.99 percent), and Petrogal (9 percent). Inpex is the newcomer to the group after buying a 9.99 percent share from Total in August 2012.

Block 15

Block 15 is operated by ExxonMobil-affiliate Esso Exploration Angola Limited (Esso Angola), which holds a 40 percent stake. Other stakeholders in Block 15 include: British Petroleum (26.67 percent), Eni (20 percent), and Statoil (13.33 percent). The first discovery at Block 15 occurred in 1998, and production first began at the Xikomba field in 2003. The Kizomba A (2004), B (2005), and C (2008) all came online in subsequent years, and production reached more than 650,000 bbl/d in 2011. Already the largest producing deepwater block in Angola, additions from the Kizomba Satellite developments should boost production by an additional 100,000 bbl/d in the near future. Cumulative production from the block reached 1 billion barrels in 2009, and remaining recoverable reserves are estimated to be between 2 and 2.5 billion barrels of oil.

Block 17

Production in Block 17 began in 2001 at the Girassol field, and has been boosted by developments at the Jasimin (2003), Dalia (2006), and Rosa (2007) fields. Operated by Total—which holds a 40 percent stake in the block—production in 2011 surpassed 460,000 bbl/d. In August 2011, the Pazflor field began operations and output is expected to average 220,000 bbl/d. Further development at the Cravo, Lirio, Orquidea, and Violeta (CLOV) fields is expected to boost Block 17 production by an additional 160,000 bbl/d beginning in 2014. Other stakeholders in Block 17 are ExxonMobil (through Esso, 20 percent), Statoil (23.33 percent), and BP (16.67 percent).

Block 18

BP is the operator of the deepwater Block 18. Production in the block comes from the Greater Plutonio development, which includes the Plutonio, Galio, Paladio, Cromio, and Cobalto fields. The Greater Plutonio development of Block 18 came online in 2007 at approximately 100,000 bbl/d, and peak production totals




were expected to hit 200,000 bbl/d by 2011. However, technical problems with the water injection system limited production to just 100,000 bbl/d. Fully operational, the Greater Plutonio development will help boost Block 18's overall production beyond the roughly 220,000 bbl/d it produced in 2011.

Block 31

Angola's first ultra-deepwater discoveries came in 2002, when BP drilled successful wells in Block 31. BP was given permission to move ahead on the country's first ultra-deepwater development in 2008; a project that centered on the Plutão, Saturno, Venus, and Marte (PSVM) fields. PSVM production was scheduled to begin in 2012, with levels expected to reach 150,000 bbl/d by late 2013; however, reports indicate the first marketable production may not occur until early 2013. Operations are run through a converted very large crude carrier (VLCC), and the floating production, storage, and offloading (FPSO) vessel is capable of processing more than 150,000 bbl/d and has 1.8 million barrels of storage capacity. Other stakeholders in Block 31 include Sonangol (25 percent), Sonangol P&P (20 percent), Statoil (13.33 percent), Marathon (10 percent), and China Sonangol (5 percent).

Block 32

The AB32 Southeast Hub development in Block 32 is expected to have production capacity topping 200,000 bbl/d, and the block holds an estimated 1.4 billion barrels of oil equivalent (boe). The block is operated by Total—which holds a 30 percent stake—and Sonangol P&P (20 percent), China Sonangol (20 percent), Esso (15 percent), Marathon (10 percent), and Petrogal (5 percent) are also stakeholders in the block. In late 2011, Marathon was rumored to be interested in selling off its stake in Block 32, though no sale has been reported.

Onshore

Early in 2012, Sonangol P&P announced that it intends to begin onshore exploration in the Cabinda Norte Block. However, the security environment—and therefore the operating conditions—are problematic, as the Front for the Liberation of the Enclave of Cabinda (a separatist group) remains active in the region. Nevertheless, Angola is expected to hold a licensing round for onshore blocks some time in 2013.

Shared development areas

Republic of the Congo (Brazzaville)

Chevron announced in August 2012 that it will develop the offshore Lianzi field, which straddles the Angola-Republic of the Congo border. Once it is producing, the field is slated to be connected to the BBLT development in Block 14. While the available resources are not as significant as those found in other blocks, the major breakthrough in trans-border developments is an encouraging sign. Revenues from the field, which is estimated to contain proven reserves of 70 million barrels, will be split 50-50 between Angola and the Republic of the Congo.

Democratic Republic of the Congo

The boundary dispute between Angola and the Democratic Republic of the Congo (DRC) is more problematic, but industry analysts hope that the Lianzi development can serve as a template for moving discussions forward. In particular, unresolved border disputes (both land and maritime) have led both sides to lay claim to energy and mineral resources in the area. In September of 2012, the DRC's Minister of Hydrocarbons stated that Angola and the DRC would come to an agreement over the so-called Common Interest Zone within six months, but shared production of any resources is still some time away.




Pre-Salt

The Angolan government held a closed licensing round in January 2011, and invited only major international firms with deepwater expertise. Many are intrigued by the similarities between Angola's pre-salt geology and those found on the other side of the Atlantic Ocean in Brazil. With Brazil's pre-salt formations estimated to have at least 50 billion

barrels of oil equivalent, exploration in Angola's pre-salt formations is beginning to ramp up.

Cobalt International's announcement

in December 2011

confirming the presence of

hydrocarbons in the pre-salt formations of Block 21 excited foreign investors, and in February 2012 Cobalt announced that

the test results exceeded earlier expectations. Maersk also encountered hydrocarbon deposits at an exploratory well in Angola's pre-salt formations in Block 23 (in the Kwanza basin). While encouraging, technical difficulties have plagued both companies, and serve to temper expectations about the viability of such developments. Nevertheless, Angola's pre-salt potential is something on which industry experts will be keeping a close watch on.

Angola - Brazil sub-sea geology




Licensing

The most recent exploration and production licensing round occurred in January of 2011, as Angola opened bidding for 11 of the country's pre-salt blocks. There are plans to open another licensing round sometime in 2013 for the country's onshore blocks, particularly those in the Kwanza basin where discoveries in pre-salt formations were made recently.

Refining and downstream

Angola has only one refinery, which was constructed in 1955 and has a capacity of just 39,000 bbl/d. On the horizon, however, is the new Sonaref refinery in Lobito, which is scheduled to begin operations in 2016. The refinery is expected to produce approximately 120,000 bbl/d initially, and will eventually reach a 200,000 bbl/d capacity. It will be able to process heavy and acidic crudes, drawn from fields like Dalia and others like it. The project was originally to be built in partnership with China's Sinopec, but the Chinese company withdrew citing concerns about the current market for refined products. Sonangol is exploring possible collaboration with a number of other international oil companies, but to date no agreements have been reached. While the new refinery will help to meet domestic demand for refined products, Angola will most likely remain heavily dependent on imports for the foreseeable future.

Consumption of refined products in Angola remains relatively low due to low levels of economic development across large segments of the population, but it is increasing steadily. In 2011, total consumption of oil products was approximately 88,000 bbl/d, up substantially from 75,300 bbl/d in 2009. Transportation fuel prices are among the lowest in the world due to state subsidies that have been in place for years; subsidies which equaled 7.8 percent of GDP in 2011 (the equivalent of 90 percent of the government's public investment spending).




Exports

The majority of Angolan crude oil is medium- to light-crude (30 degrees - 40 degrees API) and has low sulfur content (0.12 percent - 0.14 percent), making it ideal for export. With domestic consumption of under 100,000 bbl/d, nearly all of Angola's oil production is available for export. In 2011, Angola exported approximately 1.53 million bbl/d, with the largest shares going to China (38 percent) and the United States (14 percent). In 2011, Angola was the second-largest supplier of oil to China (behind only Saudi Arabia) and the 10th largest supplier to the United States. All told, Angola exports nearly 80 percent of its total oil production.

Angola has several export terminals, including many very large floating production, storage, and offloading (FPSO) vessels like the Sanha LPG FPSO and the Kizomba A FPSO.

The Sanha vessel was the first to combine all the LPG processing and export functions on the same vessel; it is also the largest of its kind. The Kizomba A has a storage capacity of 2.2 million barrels of oil, and is one of the largest vessels of its kind in the world (perhaps even the largest).

While Angola does not currently have any export pipelines, in the spring of 2012 a $2.5 billion memorandum of understanding (MoU) was signed between Angola and Zambia to construct a pipeline from Lobito in Angola to Lusaka in Zambia. The pipeline will be 870 miles long and is

intended to send refined products (including gasoline, diesel, and jet fuel) to Zambia. The project is scheduled to begin in 2013, and will be operational in 2016.

With its location on the western coast of Africa, shipping time to North American and European markets is significantly lower than those for Angola's oil-exporting competitors in the Middle East. In addition, Angola's position as a major oil exporter free from the geopolitical risks of the Strait of Hormuz (see EIA's World Oil Chokepoints analysis brief) make it a potentially reliable trade partner (along with Nigeria) for the United States and other importing countries.




Natural gas

With the first cargo of liquefied natural gas (LNG) scheduled to leave Angola in early 2013, the

country is in a position to capitalize on the high demand for LNG to bolster its export portfolio.

According to Oil and Gas Journal estimates, at the end of 2011 Angola had proved reserves of natural gas of 10.95 trillion cubic feet (Tcf). That is the fifth-largest endowment in Africa, and ranks second in Sub-Saharan Africa behind only Nigeria. While the majority of Angolan natural gas is re-injected into the country's oilfields to aid recovery—or simply flared off—efforts are underway to enhance Angola's ability to produce and market its natural gas reserves. To date, these efforts have been focused on the development of the country's first liquefied natural gas (LNG) terminal at Soyo. With operations set to begin in early 2013, Angola should be able to capitalize on the recent demand spike for LNG cargoes resulting from Japan's continued shuttering of its nuclear program.

Angola's natural gas sector is run through a subsidiary of national oil company Sonangol, called Sonangás. Sonangás was formed in 2004, and is tasked with the exploration, evaluation, production, storage, and transport of Angola's natural gas and natural gas derivatives. Sonangás is working with Sonangol P&P to establish a regulatory environment—including taxation—to help spur research and development in the natural gas sector of Angola.

Exploration and production

Natural gas production in Angola has more than tripled over the past two decades, growing from 98 billion cubic feet (Bcf) in 1990 to 379 Bcf in 2011. The vast majority of Angolan natural gas is re-injected into oil fields to help recovery, or it is simply flared off as a by-product of oil operations. In 2011, re-injection and flaring accounted for 91 percent of all the natural gas produced in the country. Angola's natural gas production comes almost entirely from associated fields, but the completion of the Soyo LNG facility (Angola LNG) could begin raising the incentives for natural gas production in the country.

Chevron's $1.9 billion Sanha project (located offshore near Soyo) began operations in 2005, and is able to process 100,000 bbl/d of oil, condensate, and liquefied petroleum gas (LPG). The project significantly reduced the need for gas-flaring in Areas A, B, and C in Block 0 (shown on map), as the roughly 500 million cubic feet per day (MMcf/d) of dry gas (which is what remains after the raw product is stripped of condensate and LPG) will be re-injected into the Sanha reservoir to help with oil recovery operations. This process is estimated to both reduce flaring in Block 0 by at least 50 percent and to reduce carbon dioxide emissions by more than 2 million tons per year according to

Offshore magazine.

With offshore oil exploration continuing apace, Angola will need to address its capacity for processing the large volumes of associated gas its oil operations will inevitably produce. Enhancing LNG capabilities, developing the domestic market for natural gas—specifically commercial customers—and enhanced oil recovery techniques will all be important components of Angola's natural gas strategy moving forward.




Liquefied natural gas

Central to Angola's plan of reducing flaring and monetizing its significant natural gas reserves is the LNG facility at Soyo, which was completed in 2012. The Angola LNG project is a joint venture between Sonangol (22.8 percent), Chevron (36.4 percent), Total (13.6 percent), BP (13.6 percent), and Eni (13.6 percent), and is slated to process 1 billion cubic feet (Bcf) per day of natural gas for domestic and international markets. The facility has a capacity of 5.2 million tons per year of LNG, and will also provide up to 125,000 cubic feet per day of natural gas for domestic consumption.

Plans call for the gas to be sourced from Blocks 0, 1, 2, 14, 15, 17 and 18.

According to Angola LNG—the Sonangol subsidiary in charge of the project in Soyo—the project represents the largest single investment in Angola in history. Operations were set to begin in the first quarter of 2012, but numerous delays pushed the scheduled start date back to the beginning of 2013. Angola LNG has seven LNG carriers at its disposal, each with a capacity of 160,000 cubic meters, though due to the delays at the facility in Soyo several of the vessels have been contracted out to other companies. Initial plans called for the LNG cargoes to be shipped to a re-gasification facility in Pascagoula, Mississippi operated by Gulf LNG; however, the market conditions in the United States are no longer favorable due to the gas-glut caused by the boom in unconventional gas. Instead, Angola LNG is targeting consumers in Europe and Asia, and is rumored to want to send its first shipment to fellow Lusophone country Brazil.

Angola LNG potential gas pipelines




Electricity

Angola's fractured electricity system serves 30 percent of the population and progress towards

providing greater access is proving difficult. The Angolan government plans to invest billions of

dollars in the country's electricity system, but in the short-term access to power will remain a

challenge.

Angola's electricity sector is run almost exclusively by the state company Empresa Nacional de Electricidade (ENE), but some private companies in the extractive industries have built power plants to run their operations. Angola is a member of the Southern African Power Pool (SAPP), a group that includes Botswana, the DRC, Lesotho, Malawi, Mozambique, Namibia, South Africa, Swaziland, Tanzania, Zambia, and Zimbabwe. The SAPP is designed to promote cooperation between member countries with the aim of creating a common electricity market that can provide reliable, and affordable, electricity to the citizens of member countries.

At present, Angola does not have a national electricity grid, instead relying on three independent systems that provide electricity to different parts of the country: The Northern, Central, and Southern Systems. The Northern System is connected to the Cuanza river basin and is the country's largest, serving the country's capital, Luanda. The Central and Southern Systems are linked to the Catumbela and Cunene river basins, respectively. The government hopes to link the three independent grids as part of a national grid system, and eventually to link its grid with neighboring SAPP members.

Currently, only 30 percent of Angolans have regular access to electricity, with that figure declining to below 10 percent in rural areas according to IHS. Limited existing infrastructure and a lack of funding for the power sector mean that Angola's ability to improve these rates substantially is limited. In late 2011, the Angolan government announced that it intends to invest $16 billion in the electricity sector by 2016 in an effort to improve the country's transmission and distribution networks, and to help bring electricity to the country's remote rural regions. The plan proposes to increase overall electricity supplies by 12 percent in order to help meet rising domestic demand.

In 2010, over 68 percent of Angola's electricity was generated at the country's hydroelectric facilities, primarily from hydroelectric dams on the Cuanza, Catumbela, and Cunene rivers. Some analysis suggests that the country's potential hydroelectric generating capacity is well over 10 times the currently-installed generating capacity, but tangible plans to develop the country's hydroelectric resources have not yet emerged. The largest facility is the Capanda hydropower dam, which has installed capacity of 520

megawatts.

Given Angola's vast natural gas reserves, thermal generation is likely to gain increasing importance in the coming years. There have been discussions about building gas-fired facilities near the country's oil operations, in part to support industry there, but firm proposals have yet to emerge. In that same vein, in 2006 Angola began discussions with the International Atomic Energy Agency about developing a domestic nuclear power program, but

details remain scarce and any project is still decades away from becoming a reality.




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Khaled Malallah Al Awadi, MSc. & BSc. Mechanical Engineering (HON), USA ASME member since 1995 Emarat member since 1990

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