New base special 22 january 2014

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NewBase 22 January 2014 Khaled Al Awadi

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Adnoc to boost oil output by injecting CO2 into reservoirs Dania Saadi , ttp://www.thenational.ae/business

Abu Dhabi National Oil Company (Adnoc) is on track to start injecting carbon dioxide (CO2) into some reservoirs in 2016 as part of plans to boost oil production and replace the use of hydrogen gas in the fields.

Adnoc has set up a joint venture with the green energy firm Masdar for carbon capture, usage and storage projects, which will utilise CO2 emitted from the country’s largest steelmaker, Emirates Steel. Masdar and Adnoc will announce this year the price formula for the CO2.

“We have our set price agreement, but it is not yet public to be announced,” said Arafat Al Yafei, the manager of the CO2 and Nitrogen development department.The emirate of Abu Dhabi, which holds more than 90 per cent of the country’s oil reserves, is one of the first in the Arabian Gulf to work on such a project for use in Enhanced Oil Recovery (EOR) for difficult reservoirs in oilfields.

As many as 100 carbon capture projects are needed by 2020 and 3,000 by 2050 to slow the speed of global warming, according to the Paris-based International Energy Agency. Globally,




many such projects have failed because they proved not to be commercially viable and because of concerns about the risk of storing carbon dioxide underground.

The joint venture between Adnoc and Masdar has a budget of Dh450 million and in July it awarded Dodsal Group an engineering, procurement and construction contract to build facilities for the project. From the Emirates Steel plant in Mussafah, 800,000 tonnes a year of CO2 will be piped 50 kilometres to the Rumaitha field, one of the smaller fields in Abu Dhabi’s main onshore concession, and later to Bab, its largest onshore oilfield. In 2009, Adnoc injected 60 tonnes a day of CO2 in a two-year pilot project at Rumaitha to get information about reservoir behaviour.

But the EOR project has the potential to grow further. “We have many demand locations within Abu Dhabi reservoirs. Rumaitha and Bab is the starting [point]. So potentially it will grow with time and it will add value to the oil and gas industry in Abu Dhabi,’’ said Mr Al Yafei.

“We are preparing ourselves for the future. We want to be proactive in that approach. We don’t want to be shocked with the demand or need to inject EOR while we are not ready.” The project will help increase production from the fields, as part of Abu Dhabi’s plans to boost oil production capacity to 3.5 million barrels per day (bpd) by 2017 from less than 3 million bpd today.

“For the time we are trying to prove the concept, once we start in 2016 the actual operation we will know exactly how much additional oil will come from this project,” said Mr Al Yafei.

Abu Dhabi needs more gas and would like to replace the use of gas in oilfields with carbon doixide to free it up for other usage. The emirate also has one of the world’s highest carbon footprints and would like to reduce its emissions.

NewBase Analysis :- Toward Energy Policy and Technology for a Sustainable Future

HC fuels are abundant in the GCC . and HC-fired electric generating units are effective in meeting baseload,

intermediate load, and peak demands given their high reliability. On the other hand, energy conversion from

traditional HC-fired power plants generates

the highest levels of CO2 emissions on a per-

unit-of energy basis . CO2 is produced as a

combustion product of any carbon-containing

fuel. All fossil fuels contain significant

amounts of fuel-bound carbon that is oxidized

into carbon monoxide (CO) and CO2 during

combustion. For example CO2 emissions from

conventional coal combustion technologies

generally amount to approximately 1 ton per

MWh of electricity generated, compared to

0.4 to 0.6 ton per MWh from natural gas-fired

generation (e.g., combined cycle/simple cycle

gas turbines). Figure 5-4 shows the

approximate level of CO2 formed when

combusting various fossil fuels. As shown in

the figure, the combustion of natural gas yields approximately 40 to 50 percent less CO2 than the combustion of coal

and petroleum coke, and approximately 25 to 30 percent less CO2 than the combustion of distillate and residual oil.

CO2 mitigation for HC-derived power is a highly debated topic; however, there are several options that can be effective:




• Improving generation efficiency (providing a reduction in overall CO2 emissions per megawatt of electricity generated), either through the development of new plants or upgrading existing facilities;

• Substituting a fraction of the HC-fuel with a carbon-neutral fuel such as biomass (biomass co-firing). Some modern coal-fired boiler designs are currently capable of accommodating up to 20 to 30 percent biomass co-firing, with a corresponding reduction in CO2 emissions; and

• CO2 capture and geological storage; federal programs are beginning to provide support to validate this option.

Currently, three general methods are available to capture CO2:

• Post-combustion capture, in which CO2 is separated from flue gases typically using sorbent or solvent systems;

• Pre-combustion capture, in which CO2 is captured prior to combustion and generally involves a shift reaction to convert synthesis gas to CO2 and hydrogen; and

• Oxyfuel firing, in which the fuel is fired with an oxygen/ CO2 mixture, thus producing a CO2-rich flue gas that is easier for CO2 capture. Oxyfuel firing methods have been demonstrated in several projects abroad. Several feasibility studies are currently underway for options using advanced supercritical plants.

Beneficial Use of CO2

An increasing global concern over CO2 emissions coupled with complicated economics has resulted in the

development of techniques to use CO2 rather than simply sequestering it. Recent studies encourage the acceptance

of CO2 as a commodity, in response to its usefulness in enhanced recovery of oil and gases. As attitudes toward

carbon capture, storage, and use improve, issues such as economics, technology, and global policy become

increasingly important. Although the potential for CCS projects has been demonstrated, the execution of CCS is

often costprohibitive due to the expense of capture and transport, which typically accounts for 70 to 90 percent of

the total implementation costs. Many studies suggest regional reuse of CO2 as the best technique.

The United Arab Emirates (UAE) continues to be a leading nation in CCS research. The state-controlled companies Adma- Opco and Adco are currently studying the behavior of CO2 injected into offshore oil fields and its effect on EOR. Since 2009, Adco has captured 60 tons of CO2 daily from industry for injections into the Rumaitha pilot well in the Bab field. These two subsidiary companies of the state have reported positive results from the pilot injections. As seen above, Masdar, is planning a multibillion dollar CCS network in the UAE to capture CO2 from a steel plant in Musaffah and transport it through a 500-km pipeline for EOR in the Abu Dhabi oil fields. Dubai Petroleum has begun work on what Oil & Gas Journal has called “the world’s largest CO2 capture and EOR project”.

Although many nations have adopted the concept of CO2 as a commodity, there are unresolved issues regarding CCS projects. As a leading country in carbon capture and use, the UAE has been working with the United Nations to encourage them to include CCS as an accepted technology in their Clean Development Mechanism. In addition to the issue of worldwide acceptance of CCS, the issues of technology, infrastructure, and economics require continued research. Global policy issues involve the debate over CCS as a worthwhile investment, and whether CO2 used for economic gain, like EOR, would be considered eligible for carbon credits. Technological issues suggest the need for further study to assure that carbon is permanently sequestered and that the potential for future leaks is minimized. A worldwide effort to examine the issues and improve techniques and policy would facilitate the success of global CCS development.




Abu Dhabi's TAQA eyes water projects in MENA, India http://www.arabianbusiness.com/abu-dhabi-s-taqa-eyes-water-projects-in-mena-india-535569.html#.Ut9L0p1fqcM

Abu Dhabi National Energy Company (TAQA) plans to grow its water business via new projects and acquisitions across the Middle East and North Africa (MENA) as well as India by creating an independent operation, a company executive said on Tuesday.

TAQA's Fujairah F2 ppwer and desalination plant, inaugurated 2011.

Currently, the firm's power and water businesses operate together as in many of its markets water desalination and power generation plants are situated in close proximity. The state-owned utility has investments in the energy and power sector from India and the Middle Eastand Africa to the United Kingdom and north America. Its desalination assets, however, are all located in the UAE.

As its sets up a separate water business within the company later this year, TAQA aims to boost its water output by at least 120 mgpd (million gallons per day) in five years by building new desalination plants or through acquisitions. That would mean about four plants each with a capacity of 30 mgpd.

"We are looking at doing some projects in the UAE and some across the MENA region and India where the market is huge," Ahmed bin Abbod al Adawi, head of TAQA's global water operations, told Reuters at an energy conference. TAQA may invest in Ghana's water sector after the African state sought the UAE's expertise in this field, he added.

TAQA is among bidders for a 46 mgpd independent water project in Qurrayat, Oman. "There is a local and regional market shift to independent water projects, a decoupling from power generation," al Adawi said. This is in part due to the new Reverse Osmosis (RO) technology, an alternative desalination technique that is cheaper, needs less energy and can be sited anywhere along a country's coast.

Also, most countries in the region have huge power capacity serving a highly seasonal demand (mainly in summer) that makes it expensive and wasteful to ensure steady water production using power plant-based thermal technology.

TAQA, majority-owned by the Abu Dhabi government, has launched its first RO technology project at its existing Fujairah 1 power and desalination plant, investing $186 million to add 30 mgpd of water. The project is due for completion in 2015.




Japan’s insurer resumes coverage to Iranian ships BY REUTERS

Japan's main private ship insurer yesterday resumed normal coverage for tankers carrying Iranian oil, said

an official with the Japan P&I Club (JPI), the same day the European Union suspended some economic

sanctions against Tehran.

The return to private shipping insurance came after Iran halted its most sensitive nuclear operations under

a deal with world powers, winning some relief from economic sanctions that had slashed its oil revenues

and crippled its economy. As part of the six-month deal, the EU suspended its prohibitions on the provision

of insurance and transport in relation to Iranian crude oil, while the United States paused its efforts to

reduce Tehran's oil shipments.

The international P&I Club, of which JPI is a member, resumed normal coverage of $7.6 billion per ship,

including $1 billion for oil spills, as EU reinsurance became available again for the first time since mid-2012,

the JPI official said. That means Japanese buyers of Iranian oil will not have to rely on Toyko's sovereign

scheme to provide the same level of liability coverage for tankers carrying the crude.

Japan oil buyers were the hardest hit by the shipping insurance provisions because they chose to continue

to use Japanese tankers for deliveries. India, South Korea, and China, at least partially, all began relying on

Iranian shippers and insurance providers for their oil deliveries from Tehran. Japan temporarily halted its

Iranian imports in July 2012 to avoid running afoul of the shipping and insurance sanctions, waiting for the

government's $7.6 billion sovereign liability guarantee per tanker to keep oil trade with Tehran going.

Sovereign scheme

Buyers in India and South Korea said they are still waiting for further information from insurers and their

governments before making any changes to how they have been receiving Iranian oil under the sanctions regime.

Western world powers believe that Tehran's now curbed nuclear programme had been aimed at making weapons.

Iran has said it is for peaceful power generation.

Japan's sovereign scheme will stay in place for the time being, but will no longer be liable for insurance payments

now that buyers can obtain JPI coverage, a government official said. The easing in US sanctions will allow Iran's six

current customers — China, India, Japan, South Korea, Taiwan and Turkey — to maintain their purchases at the

current reduced levels for the six-month duration of the interim nuclear deal between Iran and world powers.




Algeria Launches Energy Bidding Round, 31 Fields On Offer by Reuters and http://www.rigzone.com/news/Hamid Ould Ahmed

ALGIERS, Jan 21 (Reuters) - Algeria launched an energy bidding round on Tuesday with 31 fields on offer for companies, as the OPEC member and key European gas supplier tries to woo foreign firms to help it reverse declining output.

Algeria's announcement came a year after an Islamist militant attack on its Amenas gas facility killed 40 oil workers and rattled foreign investors already wary over the North African state's contract terms. Ali Betata, head of the ALNAFT, the agency in charge of handling bids, told reporters that 17 of the fields on offer would be in the south, five in the north and the rest located in the centre of the country.

"We will explain to our partners the elements and incentives included in the bidding," Energy Minister Youcef Yousfi said, when asked about concerns the bidding may not attract foreign investors. Algeria's last round in 2011 awarded only two contracts out of the 10 offers - one to




Spain's Cepsa and the other to the country's own state energy firm Sonatrach.

The country gets most of its output from mature fields and needs foreign investment to develop new reserves. But the government said recently it had made some "promising" discoveries among the more than 30 finds last year. Algeria's new energy law, passed last year, includes tax and other contractual incentives for foreign companies, and benefits for unconventional energy resource investments such as shale oil and gas contracts.

Yousfi said as part of new developments, the country's offshore explorations would start at the end of this year or early next year. The minister said the bidding includes perimeters for shale oil and shale gas. Algeria has also said it plans to build five oil refineries to double its production capacity, but has not yet given details on when construction would begin.

Oil production is around 1.2 million barrels per day - the same level as 2012 - with energy export earnings $63.5 billion in 2013, down 10 percent from a year ago, officials said. The January 2013 attack on the Amenas plant by militants who crossed over from the remote border with southern Libya, heightened concerns over security for energy producers in North Africa.

BP has yet to send foreign contractors back to the Amenas gas plant, though Algerian officials said new security reinforcements and a landing pad were in place at the desert site. "It is not up to me to decide when they will return," the minister said. "It is up to them."




Energy producers now looking at Asia-Pacific region, says PetroChina By Pratap John/Chief Business Reporter http://www.gulf-times.com/business/

Panellists at a plenary session on “Unlocking Energy through Innovation, Technology and Capability” at the International Petroleum Technology Conference in Doha on Monday. Picture: Jayaram

Demand destruction in North America and OECD (Organisation for Economic Co-operation and Development)

countries mainly in Europe will prompt energy producers to look at emerging countries, particularly in the Asia-Pacific region, said PetroChina vice-president Bo Qilang.

He was speaking at a plenary session on “Unlocking Energy through Innovation, Technology and Capability” at the

International Petroleum Technology Conference in Doha. He said the energy demand in China was rising consequent

on the country’s economic emergence. Natural gas is part of the primary energy mix in the country. Its current share is 5%, which will increase over a period of time, said Qilang, also the president of CNPC International.

Saudi Aramco senior vice-president Amin H Nasser highlighted the role of technology in providing clean energy to people around the world.

“The global population may exceed 10bn in a few decades. Clearly, energy demand will rise as a result of this. We need to invest in technology so that increasing energy needs of global population can be met,” Nasser said.

He also listed Aramco’s initiatives on R&D in energy in collaboration with premier institutes worldwide. Sudhir Vasudeva, chairman and managing director of ONGC (India), said his country has laid out “Hydrocarbons

Vision 2025” with a view to be self-reliant on energy over the next few years.

This is to ensure energy security by achieving self-reliance through increased indigenous production and investment

in equity oil abroad. It also aims to develop India’s hydrocarbon sector as a “globally competitive industry”, which could be benchmarked against the best in the world through technology upgradation and capacity building in all

facets of the industry.

The Hydrocarbons Vision 2025 lays down the framework, which would guide the policies relating to the hydrocarbons

sector. Issues such as energy security, use of alternative fuels, interchangeability of technology are vital to ensuring that the mix of energy sources used in the economy is optimal and sustainable and that adequate quantities of

economically priced clean and green fuels are made available to Indian consumers, Vasudeva said. Maersk Oil CEO Jakob Thomasen spoke on technological strides made by his company with focus on the Al Shaheen

Oil field, which it operates in Qatar.

Maersk Oil entered into an exploration and production sharing agreement (EPSA) with Qatar Petroleum in 1992. The

EPSA included an oil-bearing reservoir – the Al Shaheen field – which had been deemed uneconomic by others as its reservoirs were extremely thin and stretched across vast distances. Despite these difficulties, Maersk Oil produced

first oil just two years later and is now producing over one third of Qatar’s daily oil production, some 300,000 bpd. Total president (upstream) Yves-Louis Darricarrere and a representative of Shell director (upstream international)

Andy Brown also spoke.

Qatar Petroleum International CEO Nasser al-Jaidah moderated the session.




Lukoil and Uzbekneftegas to invest $3 billion in Kandym field expansion http://www.2b1stconsulting.com/lukoil-and-uzbekneftegas-to-invest-3-billion-in-kandym-field-expansion

The Russia largest privately-owned company Lukoil Oil Company (Lukoil) and the national oil company (NOC) Uzbekneftegas National Holding Company (Uzbekneftegas) are completing the front end engineering and design (FEED) work for the expansion of the Kandym gas field in the Bukhara region, at the center west of Uzbekistan.

In June 2004, Lukoil and the State-owned company Uzbekneftegas signed a production sharing agreement (PSA) to develop three gas fields in Uzbekistan, named Kandym, Khauzak and Shady. In this PSA, Lukoil and Uzbekneftegas agreed to cooperate in the development of these gas fields and to share the working interests during 35 years in such a way that:

- Lukoil 85% and Uzbekneftegas 15%

At that time the first target is to appraise these fields to evaluate the size and the quality of their reserves in natural gas. The first production started from the Khaukaz and Shady gas fields in 2007.

In November 2011, Lukoil and Uzbekneftegas extended the production to the Shady West area so that in 2012 the Khaukaz and Shady gas fields could deliver:

- 3.8 billion cubic meters of gas and 19,000 tonnes of condensate

In parallel to this first phase of development, Lukoil and Uzbekneftegas completed their evaluations of commercial reserves in natural gas and condensate of the three fields.

With 26 billion cubic meters additional reserves of gas, Lukoil and Uzbekneftegas initiated the second phase of the project with the development of the north Shady area.

This expansion should start commercial operations in 2014.

So far the exploration and development of the Khaukaz – Kandym – Shady gas fields required $2.5 billion capital expenditure and now Lukoil and Uzbekneftegas are preparing to invest an additional $3 billion to develop Kandym along the boarder with Turkmenistan.




Hyundai Engineering completed Kandym FEED

In August 2011, Lukoil and Uzbekneftegas sanctioned the call for tender of the pre-front end engineering and design (pre-FEED) and FEED to Hyundai Engineering Construction Ltd (Hyundai Engineering) for the Kandym Group of Fields Development project.

In that respect the Kandym project covers in fact the development of 6 gas and condensate fields: Akkam, Kandym, Khodji, North Shady, Parsankul and West Khodji, all located in the Karakul District of the Bukhara Region.

The gas treatment strategy as these fields took more time to Lukoil and Uzbekneftegas as the reservoirs contain a high content of hydrogen sulfides.

In March 2012 Lukoil and Uzbekneftegas established the Kandym Enterprise Construction Directorate to run the joint venture dedicated to this Kandym Group of Fields Development project.

From the FEED work completed by Hyundai Engineering, the Kandym project should include:

- 100 gas production wells

- 400 kilometers of gas gathering pipelines system

- Gas booster compression station

- Gas central processing facility (CPF)

- 70 kilometers export pipeline

- Gas treatment facilities

- 90 kilometers water inlet pipeline

- Water treatment facilities

- 80 MW gas-fired power plant

- Storage and loading terminal for natural gas, condensate and granulated sulfur

- Campground for 1400 persons

The Kandym Gas central processing facility (CPF) should have a capacity of 810 million cubic feet per day (cf/d).The compression stations to boost the gas to the Kandym Gas central processing facility (CPF) should be located at Kuvachi-Alat and Northern Shady.

As the project has been approved by the Uzbek Government, Lukoil and Uzbekneftegas are planning Hyundai Engineering to start the engineering, procurement and construction (EPC) work of the Kandym project on the second half 2014 in expecting the first train of the Kandym central processing facility to come into commercial operations at the end of 2016.




German industrial base at risk if green energy shift fails http://uk.reuters.com/article/2014/01/21/germany-energy-gabriel-idUKL5N0KV19I20140121

Germany risks undermining its industrial base if it fails to undertake radical reform of existing incentives for the country's renewable energy sector, its new economy minister said on Tuesday.

German firms must stay competitive, Sigmar Gabriel said one day before he outlines planned changes to a renewable energy law that would make deep cuts in financial support for green energy. "We have reached the limit of what we can ask of our economy," he told the Handelsblatt energy conference in his first major speech as economy minister with responsibility for energy policy and Germany's shift to renewables.

"The energy transformation has the potential to be an economic success, but it can also cause a dramatic de-industrialisation of our country," he warned. Export-oriented companies have warned that a surge in power costs, caused largely by the green power incentives, will make them internationally uncompetitive and some have even threatened to move production abroad. Industry accounts for around a quarter of Germany's economy.

ATTACK ON BRUSSELS

In a blunt attack on Brussels, Gabriel also made clear he would defend German interests against interference from the EU. "The Commission is using competition law to 'Europeanise' national energy policy," said Gabriel, who will outline his plans to Chancellor Angela Merkel's cabinet on Wednesday.

The EU is investigating exemptions granted to Germany's energy-intensive companies from charges that fund green incentives. Apart from those with exemptions, all power consumers pay for the 'green revolution' via a surcharge added to their electricity bill. Some 2,000 of Germany's' heaviest energy users fear they may have to repay discounts worth around 5 billion euros a year.

Markets have been waiting for Gabriel, who is chairman of her Social Democratic Party (SPD) coalition partner, to show his cards since he took office last December. Germany switched to renewables under an SPD-Greens government more than a decade ago, but Gabriel's party has its roots in the trade union movement and is traditionally a champion of the coal industry.

Merkel gave the transition an unexpected push when she accelerated the exit from nuclear power after Japan's Fukushima disaster in 2011. The shift is one of Merkel's most significant domestic policies and is being watched around the world. Germany faces a delicate balance to maintain a boom in renewables while




also ensuring power is affordable to consumers. It wants to raise the share of renewable power to 40-45 percent in 2025 from about 25 percent.

MODEL?

"We must make the energy shift an economic success ... No one around the world will follow us, otherwise," Gabriel said, adding the cost of the support under the renewable energy law was about 24 billion euros ($32.55 billion) a year. According to a draft proposal seen by Reuters, Gabriel wants Germany to cut the support price paid for electricity from solar and wind power generators by about a third by 2015.

Feed-in tariffs paid to renewable power generators will be cut across all technologies to an average of 12 cents per kilowatt hour by 2015 from 17 cents/kWh. Industry has broadly welcomed the plans for the incentive cuts, which Gabriel wants to push through by the summer.

But representatives of the wind and power branches, Greens politicians and some Social Democrats have attacked the plans, especially the idea of reducing subsidies for onshore wind. "This is like slamming on the brakes and leaving big skid marks," said Eveline Lemke, Greens economy minister in the state of Rhineland Palatinate. Gabriel said he was open to discussions about his plan. Although Merkel's right-left coalition has a big majority in the Bundestag, the Bundesrat upper house, which represents the 16 federal states, could delay the law.

Eight German nuclear power reactors were permanently shutdown on 6

August 2011, following the Japanese Fukushima nuclear disaster.




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Your partner in Energy Services

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

Energy Services & Consultants Mobile : +97150-4822502

[email protected] [email protected]

Khaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 years of experience in theof experience in theof experience in theof experience in the Oil & Gas sector. Oil & Gas sector. Oil & Gas sector. Oil & Gas sector. Currently working as Currently working as Currently working as Currently working as

Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for

the GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations as Operations as Operations as Operations

Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developed has developed has developed has developed

great experiences in the designing & constructinggreat experiences in the designing & constructinggreat experiences in the designing & constructinggreat experiences in the designing & constructing of gas pipelines, gas metering & regulating stationof gas pipelines, gas metering & regulating stationof gas pipelines, gas metering & regulating stationof gas pipelines, gas metering & regulating stations and in the engineering of supply s and in the engineering of supply s and in the engineering of supply s and in the engineering of supply

routes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs for OUs for OUs for OUs for

the local authorities. He has become a reference for many of the Oil & Gas Conferences the local authorities. He has become a reference for many of the Oil & Gas Conferences the local authorities. He has become a reference for many of the Oil & Gas Conferences the local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andheld in the UAE andheld in the UAE andheld in the UAE and Energy program broadcasted Energy program broadcasted Energy program broadcasted Energy program broadcasted

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NewBase 22 January 2014 K. Al Awadi

Economy & Finance

New base special 22 january 2014