New base special 20 february 2014

Copyright © 2014 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced,
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NewBase 20 February 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
South Korean consortium wins $6bn deal to build Iraq refinery
Hadeel al Sayegh www.thenational.ae/business/energy
The Iraqi oil ministry awarded Hyundai E&C, Hyundai Engineering, GS Engineering &
Construction, and SK Engineering to undertake engineering, procurement and construction works
for the planned 140,000 barrels per day (bpd) refinery, which is located 100 kilometres south of
Baghdad.
The project follows regional economic development plans that include power plants and refineries
to increase electricity production, build up infrastructure and spur job creation. The Karbala
Refinery Project, which includes the construction of four refineries, is expected to produce a range
of products including liquefied gas, petrol, gas oil, fuel oil and jet fuel to serve growing domestic
needs.
Hyundai E&C and its affiliate Hyundai Engineering have taken a 37.5 per cent share in the project
worth $2.26bn, Hyundai E&C said in a regulatory filing yesterday, GS has a 37.5 per cent share,
while SK has a 25 per cent share, the statement said.
“Gas represents a valuable commodity and economic multiplier for Iraq’s reconstruction and
infrastructure development,” Luay Al Khateeb, the visiting fellow at Brookings International, wrote
in a paper co-published by Harvard University’s Belfer Centre and Rice University’s Baker Institute
Center for Energy Studies in November.
“As much of Iraq’s gas is associated and will be a by-product of oil production – unlike other
Middle Eastern countries – its production could be cost effective and competitive to regional
markets; the development cost of gas is linked to capturing, processing, and transportation, with
no cost required for exploration and production,” Mr Al Khateeb said. “However, due to the lack of
infrastructure facilities, 55 per cent of current gas production is flared, leaving very little to feed the
deprived national grid and industry.” Iraq’s monthly oil production in January was 3.05 million bpd,
according to Bloomberg data.
About Iraq Refining ( NewBase research )
Current Iraqi refining capacity is estimated at over 900,000 bbl/d, although estimates vary because effective
capacity has fallen below nameplate capacity in many cases.

Existing refineries in Iraq
Refinery Location Nameplate capacity (bbl/d) Notes
North Refining Company
Baiji North-Central Iraq 310,000 New Fluid Catatylic Cracker being installed
Haditha North-West Iraq 16,000
Kisik North Iraq 10,000 10,000 bbl/d under contstruction
Kirkuk North-East Iraq 30,000
Qaiarah North Iraq 20,000 Needs extension of pipeline
Siniya North Iraq 20,000
Midland Refining Company
Daura Baghdad 210,000 Needs extension of pipeline
Diwaniya East of Najaf 20,000
Najaf Najaf 30,000
Samawa Najaf 30,000
South Refining Company
Basrah Near Basrah 140,000 Adding 70,000 bbl/d
Missan South-East Iraq 30,000
Nassiriya South-Central Iraq 30,000
Kar Group (private)
Erbil Erbil 40,000
Source: Middle East Economic Survey, FACTS Global Energy
Iraqi refineries produce too much heavy fuel oil relative to domestic needs, and not enough other refined
products such as gasoline. To alleviate product shortages, Iraq set a goal of increasing refining capacity to
1.5 million bbl/d. Iraq has plans for four new refineries as well as plans for expanding the existing Daura
and Basrah refineries.
Planned new refineries in Iraq
Refinery Nameplate capacity (bbl/d) Investment Front end engineering contract
Nassiriya 300,000 $9 billion Foster Wheeler
Kirkuk 150,000 $5.5 billion Shaw Group
Missan 150,000 $5 billion Shaw Group
Karbala 140,000 $5 billion Technip
Total 740,000
Source: Middle East Economic Survey, FACTS Global Energy

Abu Dhabi, Vitol buy Shell's Australian oil assets for $2.2bn
By Reuters
Royal Dutch Shell has sold its downstream Australian assets to Dutch-owned oil trader Vitol and the Abu
Dhabi Investment Council for about A$2.4 billion ($2.2 billion), The Australian Financial Review reported
on Wednesday.
The sale would mean Australia's Macquarie Group and its
partner Glencore Xstrata were not successful in their efforts to
buy the assets, the newspaper said without attributing sources.
Shell has been planning to sell the business, which includes a
refinery, import terminals and 900 service stations, as part of a
reported worldwide divestment program under CEO Ben Van
Beurden, worth about $15 billion.
A Shell spokesman in Australia told Reuters he would not comment on "speculation". A Glencore Xstrata
spokesman declined to comment.
The refinery, which struggles to compete with larger, more efficient facilities in Asia, faces an
uncertain future. It is believed that Vitol, the world’s largest oil trader, has earmarked the 60-year-
old refinery for closure once it takes control of the business.
Shell had planned to convert the refinery, which employs 500 people, into a fuel import terminal if
a buyer could not be found. A Shell spokesman in Australia told Reuters he would not comment
on “speculation”.
A closure would be a further devastating blow to the Victorian economy, coming hard on the heels
of the announcement on Tuesday that Alcoa’s Point Henry smelter will close in August and the
planned withdrawal of car makers Toyota, Holden and Ford from Australia.
Vitol and its partners are reported to have won out in the bid for the assets over another party
made up of Macquarie Capital and powerful miner-trader Glencore Xstrata. Private equity
investment firm TPG had also been vying for the assets though has been out of the sale process
for some time.
The sale is part of Shell’s reported
wider plan under chief executive
Ben van Beurden to offload up to
$US15bn ($16.7bn) of assets
worldwide in the next two years.
Shell, which has a partnership with
supermarket operator Coles in
Australia, has had its Geelong
refinery on the market since April
2013. It later broadened the sale to
include Australian petrol stations.
120,000-barrel-per-day Geelong refinery,
near Melbourne, in Australia.

Nobel to sell Israel's Tamar gas to Jordanian
By: (Reuters) Steven Scheer ,
The partners in the Tamar natural gas field off Israel's Mediterranean coast have signed a deal to
sell at least $500 million of gas over 15 years to two Jordanian companies in the first deal outside
of Israel. Under the agreement, Tamar will supply 66 billion cubic feet to Arab Potash and its unit,
Jordan Bromine - a joint venture with U.S.
Albemarle - at their facilities near the Dead
Sea, Noble Energy said on Wednesday.
Texas-based Noble owns 36 percent of the
field. Israel's Delek Group, through its units
Avner Oil Exploration and Delek Drilling, holds
a 31.25 percent share. Isramco Negev has a
28.75 percent stake, and Dor Gas Exploration
holds 4 percent. Jordan is hungry for gas
amid numerous attacks on a pipeline in the
Sinai peninsula that has halted supplies from
Egypt.
Tamar, discovered in 2009, is estimated to
hold more than 280 billion cubic metres of
gas. It began production last March and has
already signed a number of lucrative deals in
Israel. The field came on line months after Egypt halted gas supplies to Israel.
After a lengthy and heated debate, the government last year decided to allow 40 percent of its
natural gas reserves for export. It is using gas as an opportunity to improve relations with its
neighbours including Jordan. It is also thought Israel could ultimately sell gas to Turkey, although
ties between the two countries have been frosty over the last few years.
The nearby and much larger Leviathan field last month signed a 20-year, $1.2 billion deal to
supply gas to planned a Palestinian power plant once Leviathan starts production in 2016 or 2017.
Leviathan is estimated to hold some 540 billion cubic metres of gas, enough to supply Europe for
a year. Tamar and Leviathan were the two of the largest gas finds in the past decade and
overnight turned Israel into a gas exporter.
Tamar's sales to Jordan are expected to start in 2016 once minimal required infrastructure has
been completed. The selling price will be based on a floor of at least $6.50 per one thousand
cubic feet of gas with upside linked to the price of Brent crude oil. Noble said it would also charge
a fee for marketing and sales services and for the transfer of gas to Jordan. Gross revenue is
expected at $500 million with actual sales dependent on final purchased quantities and oil prices
at the time of sale, Noble said.
"This deal will pave the way for additional export projects which could enhance regional
cooperation as well as provide additional supply to the domestic market and enhanced security of
supply through development of additional reservoirs and infrastructure," said Lawson Freeman,
Noble's Eastern Mediterranean vice president.
Completion of the deal is subject to various closing conditions and regulatory approvals. Noble
said it was in a "number of additional negotiations to sell significant quantities of natural gas from
both fields to multiple customers." Earlier this month, Australia's Woodside Petroleum signed a
deal to take a 25 percent in Leviathan for up to $2.55 billion.

Eni considers own Mozambique LNG Plant to secure 2018 first shipment
http://www.2b1stconsulting.com
The Italian national oil company Eni and its partners China National Petroleum Corporation (CNPC
or PetroChina), Kogas from South Korea, Galp Energia from Portugal and Mozambique Emprecia
Nacional de Hidrocarbonetos (ENH) are evaluating alternative solutions to develop its Mozambique
liquefied natural gas (LNG) project on fast track in order to load the first shipments in 2018.
Together with the Texas-based Anadarko Petroleum Corporation (Anadarko), Eni managed to unveil
the gigantic resources of natural gas
lying in the deep offshore water
Mozambique.
While Anadarko was leading the
exploration on the Area-1 of the
Rovuma Basin, Eni was confirming the
potential of the region in the Area-4.
On the Area-1, Anadarko expect to
accumulate 100 trillion cubic feet (tcf)
of natural gas and Eni more than 70 tcf.
Geographically, Mozambique is
perfectly located on the Africa East
Coast to export LNG to Asia.
In that perspective, the Mozambique Government motivated the two teams leaders Anadarko and Eni to
sign, end of 2012, a memorandum of understanding (MOU) to develop jointly the onshore part of the
Mozambique LNG projects and coordinate their efforts regarding the offshore part where fields are linked
between the Area-1 and Area-4.
As a result, Eni and Anadarko have started the feasibility study to build the Afungi LNG Park in the
Cabo Delgado Province on the northeast coast of Mozambique. According to the reserves consolidated
by Eni and Anadarko, this onshore of the Mozambique LNG project is planned to be developed jointly
in five different phases of two trains per each phase. Since the feasibility study has been completed for this
onshore Mozambique LNG project, three teams of engineering companies are bidding for the front end
engineering and design (FEED) contract.
Eni and Anadarko to agree on Afungi LNG operator
Eni and Anadarko had decided to call for tender on the base of a competitive FEED in order to save time
on the engineering, procurement and construction (EPC) phase of the project with already the target to
ship first LNG to Asia in 2018.
If it is clear that Anadarko is the operator of the Area-1 and Eni of the Area-4, the question is still pending
on the name of the operator of the jointly developed Afungi LNG Park.

This question will need to be answered before the final investment decision (FID) required to sanction the
competitive FEED to the winning engineering companies team.
On Area-1, the Anadarko holds 36.5% with Mitsui E&P 20%, BPRL Ventures Mozambique 10%,
Videocon 10%, PTTEP 8.5% and ENH 15%.
On Area-4, the Italian leader
Eni concentrates 50% through the joint
venture Eni East Africa by which
PetroChina holds 20%, with the
remaining shares being split between
Kogas 10%, Galp Energia 10%, and
ENH 10%.
With their deep pockets and 70% interests
in the project, Eni and PetroChina do not
intend to lose time in the development of
Mozambique LNG project.
In the same way as they are studying a
floating liquefied natural gas (FLNG) solution to speed up the development of the offshore part in
Mamba , they are now considering to build their own LNG plant in Quionga, close to Tanzania boarder.
In respect with the reserves in places in the Rovuma basin, Mozambique holds enough gas to feed the
Afungi LNG Park, Mamba FLNG and an additional Quionga LNG plant, that would secure first
LNG shipment for Eni and PetroChina from Mozambique LNG by 2018.
NewBase Comments / research :-
Figures given by Anadarko, show the initial two of four trains to be built at the site will require an
investment of $8-10bn. Other facilities cost of investment are as shown below in the attached
image .

CB&I wins $370m Kuwait refinery contract
TradeArabia News Service
Texas-based CB&I has won a $370 million contract from Kuwait National Petroleum Company (KNPC) for
setting up its new clean fuels project at the Mina Abdullah I refinery. CB&I, a part of a joint venture led
by Petrofac International along with Samsung
Engineering Company, will execute the Mina
Abdullah I refinery project.
The project scope includes engineering and
procurement for two atmospheric residue
desulfurization units, which were previously
licensed by Chevron Lummus Global, a joint
venture between CB&I and Chevron.
The clean fuels project is one of KNPC's major
investment projects to upgrade the Mina
Abdullah and Mina Al-Ahmadi refineries in
order to reach a daily production target of
800,000 bpsd from the current 736,000 bpsd.
Commenting on the win, Patrick K. Mullen, the president of CB&I's Engineering, Construction and
Maintenance operating group, said: "This award builds on CB&I's proven experience in the refining
industry."
"The installation of these units will reduce sulfur, enhancing the ability of Kuwaiti petroleum products to
compete on the world market and meet stringent international environmental regulations," he added.-
AboutAboutAboutAbout CBICBICBICBI
CB&I (NYSE: CBI) is the most complete energy infrastructure focused company in the world and a major
provider of government services. Drawing upon more than a century of experience and the expertise of
approximately 50,000 employees, CB&I provides reliable solutions while maintaining a relentless focus on
safety and an uncompromising
standard of quality.
As one of the most complete
providers of a wide range of
services including design,
engineering, construction,
fabrication, maintenance and
environmental services, no project
is too big for CB&I. Our timely and cost-effective solutions not only satisfy our customers’ needs, but also
improve the quality of life for people around the world.

NewBase Special Report 20th
February 2014
LNG And Challenges Facing Global Gas
Market
by G. Allen Brooks
.as more liquefied natural gas (LNG) volumes from Qatar are going to Asia rather than Europe due to better
prices. As we monitor the growing global gas market, and the role LNG plays in its dynamics, there have
been a series of interesting developments that may impact the market’s future dynamics.
In the United States last week, Sempra Energy (SRE-NYSE) subsidiary Cameron LNG LLC won approval
from the Department of Energy to export domestic natural gas to countries that do not have free trade
agreements (FTA) with the United States. Additionally, the Federal Energy Regulatory Commission okayed
the firms’ environmental impact statement, which allows Sempra to move forward in selecting a contractor
to build the three cooling trains needed to liquefy up to 1.7 billion cubic feet (Bcf) per day of gas for export.
The Cameron terminal becomes the sixth export facility approved by the government to ship gas to
countries without FTAs with the U.S.
The six terminals have a combined
8.5 Bcf per day approved export
capacity when fully up and running,
which represents 11.2% of the current
monthly gross volume of natural gas
withdrawn from fields based on the
latest data as of November 2013 (the
latest data available) from the Energy
Information Administration’s (EIA)
Form 914 survey of gas producers.
If we assume that only these six terminals are built and operate at peak volumes, which would be in 2019
as cited by the press release from Sempra Energy, the 8.5 Bcf per day of LNG exports would represent a
lower percentage of estimated gas output – 9.4% if gas production grows at 3% per year, which is below
the 3.3% growth rate posted for the last 12 months of reported data. (We calculated the increase between
the revised estimate for November 2012 from the Form 914 survey to the initial estimate for the month of
November 2013.) The projected LNG export volumes would represent 9.7% of future domestic gas
production volumes if production grows at 2.5% a year, an estimate below the 2.8% growth for the latest 12
months based on measuring the change from the initial monthly production estimates for the months of
November 2012 and 2013, respectively.
We found it interesting that the November 2013 Form 914 gross production estimate is about 5 Bcf per day
higher than the Lower 48 gas supply estimate employed by the EIA in its Short-Term Energy Outlook
(STEO) that forecasts energy markets for the next two years and is revised every month. The EIA projects
natural gas output to grow by 2.1% in 2014 and 1.3% in 2015, respectively. The EIA provides quarterly
estimates for production and other gas market measures, but if we look at the annual averages that reflect
the agency’s growth projections, dry gas production volumes would be 70.26, 71.49 and 72.28 Bcf per day
for 2013, 2014 and 2015, respectively. To put these numbers in perspective, the initial November 2013
Form 914 production estimate for the Lower 48 states was 75.94 Bcf per day.
While it may appear we are splitting hairs over differences in projections of future natural gas supply, those
differences will become important to the extent the DOE and FERC continue to approve applications for
LNG terminal export permits from among the remaining 20 projects already in the approval queue. The
projections are also important because of the difference in the base from which the projection is made and
the higher Form 914 growth rate compared to the STEO growth rates. At what percentage of supply will

exports significantly begin to impact natural gas prices? That topic will become the center of the debate
over whether the federal government should approve additional LNG export terminals. Manufacturing
companies that use natural gas and who are building new plants to capitalize on low U.S. prices will be up
in arms if the current cost competitive advantage these manufacturers have against producers from other
regions of the world narrows or possibly
disappears due to government policies. There
does remain the possibility that the federal
government could rescind or restrict export
approvals if it determined that shipping natural
gas out of the United States was no longer in the
nation’s best interest. We remind you that this
would not be the first time the federal government
reversed energy policies when faced with
conditions that could harm the general public. A
reversal, or significant limitation of LNG exports,
would certainly upset the current view of how the
global LNG market will be functioning by the end
of the decade.
Another development that could upset the global
LNG market is the current expansion of the
Panama Canal. Panama has been building bigger locks and dredging deeper and wider channels to allow
the larger container ships and LNG carriers that are increasingly populating the global shipping fleet to
traverse the isthmus and reduce the time necessary to move cargos from the Atlantic to Pacific basins.
Reducing the travel time could materially improve the profitability of trade, although Panama will extract
some of that profit for the use of its canal. For the emerging U.S. LNG export business, the most attractive
market on a relative profit measure is to ship gas from the Gulf Coast to Asian markets rather than
European buyers. Today, the price difference between Japan and Europe may be as much as $5 per
thousand cubic feet of natural gas, not all of which is consumed by extra transportation costs.
A significant issue for the Panama Canal
expansion is that the contract was likely
underbid. In addition, there appear to be issues
with the design specifications and the soils
involved in the construction. As a result, the
project has fallen behind its original construction
schedule and now the third locks’ construction is
considerably over budget. The cost overrun is
estimated at $1.6 billion out of a total estimated
project cost of $5.25 billion. The project was
approved by the Panamanians in a referendum
in 2006 and commenced work in 2007. The
Panama Canal Authority successfully arranged
$2.3 billion in financing from a consortium of
international banks in December 2008 at the height of the financial crisis. How to resolve the cost overrun
has been an issue for several months but recently reached a critical point when the construction
consortium led by Spanish construction company Sacyr said that without resolution it would be forced to
stop work. In the past week, reports are that progress on resolving the problem has been made and
construction will continue. The original completion date for the expansion was 2015. With the addition of
the third set of locks to enable the canal to capture the largest ships to be available by 2025, the project will
not be finished until 2019.

The expansion will allow larger cargo ships to pass through the canal. Now, those large ships must offload
their containers at one end of the canal, have them loaded on smaller ships that traverse the canal and
then have them re-loaded on to the large ships waiting at the other end. To understand the impact the
canal expansion will have on shipping economics, note the relative size difference between ships that can
currently pass through the canal compared to those that can pass once the expansion is finished. The
impact will also be true for LNG carriers. The new, large carriers – Q-Max – that were built to move gas
from Qatar to customers worldwide are 1,132-feet long, 177-feet wide and have a draft of 39-feet. This puts
them in the same category as the post-
panamax ships in Exhibit 6.
Being able to move very large LNG carriers
through the canal will open up more
profitable Asian routes to US exporters.
Based on the delay in the canal’s
expansion, access to Asia may not be
available until close to the end of this
decade.
The third major issue to potentially impact
the global LNG market was the February
9th election for the governor of Tokyo.
Japanese voters elected the candidate backed by Prime Minister Shinzo Abe who favors reducing the
country’s reliance on nuclear power in the medium- and long-term and increasing the share of power
generated from renewable resources. The opposition candidate attempted to make the election a
referendum over nuclear power. Surveys continue to show that the Japanese people favor abandoning
nuclear power, either immediately or in the longer term. However, these surveys also show that nuclear
power is not as high on the list of voter concerns as jobs, the Japanese economy, an aging population and
growing welfare payments.
The last of the country’s
nuclear power plants
were shut down last
September, although
there are efforts
underway to convince
certain provinces to allow
restarting some plants. In
the interim, the Japanese
utility industry has been
an aggressive buyer of
LNG to fuel its gas-
powered plants and the
14 new ones scheduled
to enter service between
April 2014 and March
2015. Japan accounts for
about one-third of all the
global LNG shipments. At
the same time, the government waved the country’s carbon emissions restrictions, thus enabling utilities to
burn more coal. The industry responded last year by increasing its coal consumption by 16% during the
first ten months, while it imported 11% more coal. The use of coal will continue to increase for the

foreseeable future as the industry plans to construct more coal-fired power plants. Cheap coal contributed
to a 0.7% decline in the value of coal imports for the first ten months of 2013 while LNG costs soared by
14.3%. Some forecasters believe that the attraction of cheap coal may undercut the LNG market in Japan,
although others say
gas purchase decisions
are not impacted by
low coal prices.
Taken together, the
continued approval of
U.S. LNG export
terminals, the potential
delay in the expansion
of the Panama Canal
and Japan’s push to
use more coal and
renewables to help
offset expensive LNG,
along with the
Groningen field output
reduction and the
resulting increase in
Russian gas supplies
to Europe, these developments make clear that the global LNG market will be subject to headwinds,
tailwinds and crosswinds through 2020. Whatever we may think about how the LNG business will evolve by
2020, those thoughts should probably include alternative scenarios. The global gas industry certainly isn’t
going to shrink given the momentum from consumers, producers and regulators, but the projections of
market growth may need adjusting. Those adjustments will create knock-on effects in other markets –
some relatively easy to forecast, but others unforeseen.
+++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
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
khalid_malallah@emarat.ae
khdmohd@hotmail.com
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. Currently working as Technical Affairs Specialist for EmiratesOil & Gas sector. Currently working as Technical Affairs Specialist for EmiratesOil & Gas sector. Currently working as Technical Affairs Specialist for EmiratesOil & Gas sector. Currently working as Technical Affairs Specialist for Emirates
General Petroleum Corp. “Emarat“ witGeneral Petroleum Corp. “Emarat“ witGeneral Petroleum Corp. “Emarat“ witGeneral Petroleum Corp. “Emarat“ with external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most ofh external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most ofh external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most ofh 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 Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility &the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility &the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility &the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas comprgas comprgas comprgas compressor stations . Throughessor stations . Throughessor stations . Throughessor stations . Through
the years , he has developed great experiences in the designing & constructingthe years , he has developed great experiences in the designing & constructingthe years , he has developed great experiences in the designing & constructingthe years , he has developed great experiences in the designing & constructing of gas pipelines, gas metering & regulating stations and in the engineering of supply routes. Manyof gas pipelines, gas metering & regulating stations and in the engineering of supply routes. Manyof gas pipelines, gas metering & regulating stations and in the engineering of supply routes. Manyof gas pipelines, gas metering & regulating stations and in the engineering of supply routes. Many
years were spent drafting, & compiling gas transportyears were spent drafting, & compiling gas transportyears were spent drafting, & compiling gas transportyears were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference foration , operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference foration , operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference foration , operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference for
many of the Oil & Gas Conferences held in the UAE andmany of the Oil & Gas Conferences held in the UAE andmany of the Oil & Gas Conferences held in the UAE andmany of the Oil & Gas Conferences held in the UAE and Energy program broadcasted internationally , via GCC leading satelliteEnergy program broadcasted internationally , via GCC leading satelliteEnergy program broadcasted internationally , via GCC leading satelliteEnergy program broadcasted internationally , via GCC leading satellite ChanneChanneChanneChannelslslsls ....
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase 20 February 2014 K. Al Awadi

New base special 20 february 2014

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