New base special 03 august 2014

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NewBase 03 August 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Optimism over Kazakhstan energy outlook
The National – UAE + NewBase
Abu Dhabi investors should look to Kazakhstan for expansion opportunities while it is still
cheap to enter its energy sector, according to the chief executive of an oil producer active
in the country.
Market fundamentals look positive, with Kazakhstan growing at 6 per cent annually, and the
country aiming to produce 2 million barrels per day by 2020. The Kazakh government is planning
new tendering rounds over the next year, when it will award new exploration blocks.
“Opportunities exist for energy firms across the spectrum, because the Kazakh government is
actively pushing to increase [output],” said Don Streu, chief executive of Condor Petroleum.
“National oil companies and energy juniors from the Middle East should pursue Kazakh
opportunities right now as entry valuations are attractive.”
Mr Streu said that Mubadala Petroleum, Ipic, Taqa and Dragon oil would all be well-placed to
benefit from investing in the Kazakh energy industry. “Kazakhstan offers an opportunity for Abu
Dhabi oil companies to diversify their supply sources so they don’t rely solely on domestic
production,” he said. Condor Petroleum said it had identified 1.5 billion barrels of recoverable oil.
But the country’s oilfields have presented international firms with technical challenges.
The country’s US$50 billion Kashagan oilfield, with estimated recoverable reserves of up to 13
billion barrels, is operated by a consortium that includes Eni, Exxon Mobil, Royal Dutch Shell,

Total, and a state-owned Kazakh firm, KazMunaiGas. It was forced to stop production after a
hostile environment caused problems for engineers. In April, production was halted after
kilometres of pipeline were found to be defective. This was due to extreme water pressure
alongside very high concentrations of hydrogen sulphide, which is a flammable, poisonous gas
that can dissolve metal.
But the Kashagan project also has to cope with pack ice, occasional freezing of water surrounding
pipes, the building
of pipeline through
swampland and
the construction of
artificial islands to
harvest the oil.
Kashagan is a
very large part of
the country’s oil
production, said
Julia Nanay, an
analyst at IHS
Energy.
“Meeting
production targets
after this year
could be
problematic
without
Kashagan,” she
said. “The goal of
compensating
Kashagan’s “lost”
barrels in 2014
can be achieved
by either
containing
declines at some
of the older fields or pushing more barrels out of fields with flat or rising output or a combination of
both.”
On Wednesday, the Kazakh oil minister, Uzakbai Karabalin, said production could resume in
2016. Mr Streu was confident that most technical problems faced by energy firms in Kazakhstan
could be overcome. “Sour oil and gas … contain[ing] high percentages of hydrogen sulphide, is
encountered in numerous fields worldwide. The industry has developed the ability safely to deal
with hydrogen sulphide,” he said.
And while “some of the offshore oilfields in the Caspian Sea have to deal with ice flows during the
winter season … this challenge has also been overcome,” he said.
Austria’s OMV, in which Ipic holds a stake, said this month that it would take a €110 million
(Dh452.5m) impairment in Kazakhstan due to unsuccessful field redevelopment. OMV operates
four producing onshore oilfields; Tasbulat, Turkmenoi, Aktas and Komsomolskoye in the

Mangistau region of West Kazakhstan near the Caspian Sea, according to its website.
Kazakhstan’s positive macroeconomic outlook, driven by rising oil revenue, is a cause for
optimism, analysts say.
“Kazakhstan was the first to pay off its International Monetary Fund debts following economic
reconstruction in 2000, seven years ahead of schedule; it was the first regional state to obtain a
favourable credit rating; the first to implement financial institutions approaching western standards
of efficiency and reliability; and the first to develop and introduce a national, fully funded pension
programme,” John Daly, an academic who covers Kazakhstan, wrote in the May issue of the
Central Asia-Caucasus Institute Analyst journal.
The government intends to take advantage of this benign environment to follow a model of export-
oriented industrialisation. Richard Weitz, writing in the March issue of the same journal, said that
Kazakhstan should take advantage of “rising global demand for [its] energy products to construct
a strong manufacturing sector and follow the successful modernisation paths of Singapore, South
Korea, and the other already successfully industrialising states”.
Easy access to the Chinese market is another boost to producers. Construction of the Atasu-
Alashankou oil pipeline between Kazakhstan and Xinjiang in China, which is expected to have a
maximum capacity of 20 million tonnes per year, began transporting oil in 2005.
“Given Kazakhstan’s close proximity and access to China, it competes very favourably with other
countries striving to meet China’s energy needs,” Mr Streu said. Kazakhstan has been working to
attract international investment into its energy and other industrial sectors. KazMunaiGas is
weighing a potential stock market flotation in London, media reported last month.
Last November,
DP World and the
Kazakhstan
national railway
company,
Kazakhstan Temir
Zholy, signed an
agreement for DP
World to provide
management
services for the
development of
the new Khorgos
Special Economic
Zone and Inland
Container Depot.
DP World is also
providing similar
services under a
separate contract
at the Port of
Aktau, Kazakhstan’s main cargo and bulk terminal on the Caspian Sea.

KSA shifting to unconventional gas resources
SG ( S.R Husain ) + NewBase
SAUDI Arabia's decade long 'Gas Initiative' is unraveling - taking new turns and twists!
Launched by the then Crown Prince, and now Custodian of the Two Holy Mosques King Abdullah
Bin Abdul Aziz, way back in September 1998, when during an hour long private meeting with
senior executives of seven US oil majors he invited them to help develop the Kingdom's energy
resources. The unexpected overture,
which took everyone by surprise then,
was made at the opulent McLean,
Virginia, residence of the then Saudi
ambassador in Washington Prince
Bandar Bin Sultan. Those attending the
meeting included senior executives from
four American oil giants - Mobil, Exxon,
Texaco and Chevron - which established
the Arabian American Oil Co., now known
as Saudi Aramco, in the 1930s. Senior
executives from Atlantic Richfield,
Conoco and Phillips Petroleum also
attended. The executives attending the
meeting were apparently "shocked" at the
offer, reports later said.
The Saudi Strategic Gas Initiative was
heralded as the first foreign investment in
Saudi Arabia's upstream energy sectors.
Western oil firms shown strong interest in
the Initiative, hoping that a foot in the door
with less than desirable gas projects
might ultimately be rewarded with more
lucrative upstream crude deals.
Initially, the three mooted gas projects focused on a $15 billion scheme to develop gas reserves in
South Ghawar field and two minor $5 billion ventures that involved gas production for
petrochemical, power and water desalination projects. However, internal opposition and drawn out
negotiations, as well as questions about the Aramco reserve estimates, stifled the early euphoria.
The Initiative ended up with only a handful of projects, led mainly by Russian, Chinese and
European firms. US oil majors which had originally negotiated for participation, interestingly
abstained. The revised gas projects entailed exploration and processing of the non-associated
gas found in designated blocks in Empty Quarters.
In October 2003 Royal Dutch/Shell and France's Total finalized agreement with Saudi Aramco for
the Shaybah gas project, covering a 200,000 square kilometer area of the Empty Quarters. Initially
Shell, which led the consortium, had a 40 percent stake in the project with Total and Saudi
Aramco each holding 30 percent stake. In May 2004, Russia's Lukoil was also awarded an 80
percent stake in 29, 900 sq.km. Block A and China's Sinopec was also awarded 80 percent stake
in 38,800 sq.km Block B with Saudi Aramco holding the remaining 20 percent in both the blocks.

Italy's ENI and Spain's Repsol-YPF, won 50 percent and 30 percent stakes respectively in the
52,000 km, Block C with Saudi Aramco accounting for the remaining 20 percent.
The entire Initiative however is in doldrums! Early last month, Royal Dutch Shell announced
ending investments in the project, complicating efforts to exploit the gas potential in the Kingdom.
Already last year, industry sources told media that Royal Dutch Shell was set to end investments
in the venture due to disagreements over terms. At least three other foreign firms - Italy's ENI,
Spain's Repsol and France's Total - have also abandoned the search for commercially viable gas
deposits in that part of Saudi Arabia.
Shell stuck it out longer in its South Rub Al-Khali Co.
(SRAK) project after finding small quantities of sour gas
in Kidan, near the Shaybah oilfield. Sour gas has high
levels of potentially deadly hydrogen sulphide and
therefore is tougher to produce than conventional gas
reserves. The relatively high cost of developing
challenging deposits while gas sales prices fixed at a
fraction of probable production costs were discouraging
Shell and others, industry sources familiar with the
matter were quoted by Reuters earlier.
When Eni and Repsol quit the project two years ago,
media reports said that the companies opted to leave
out because even if gas was discovered easily there,
the find would not have been economically feasible due to the hydrogen sulphide richness of the
'sour' gas located in the area. Last year it was also reported that China's Sinopec too had
suspended drilling operations in the Empty Quarter.
Low domestic gas pricing has been an issue here. Saudi Aramco corridors in Dhahran have been
abuzz with voices calling for changes in the price regimen. The country will not be able to develop
the known gas resources in the Rub Al Khali (Empty Quarter) desert until the government raises
the domestic gas price, Saudi Aramco CEO and president Khalid Al Falih was quoted in press as
saying.
“One challenge we have is the pricing of gas is very low in Saudi Arabia and does not make
unconventional gas or tight gas in the Rub Al Khali economic,” he argued. Al Falih said he hopes
the gas price issue “will be addressed by the government in due course.” However, he refrained
out from providing any timeline.
The focus is now shifting to unconventional resources. Saudi Oil Minister Ali Al-Naimi had
estimated the country's unconventional gas reserves - those held in reservoirs that have not been
traditionally exploited - at over 600 trillion cubic feet, more than double the proven conventional
reserves of 288 trillion cubic feet.
Saudi deserts may hold as much as 645 trillion cubic feet of technically recoverable shale gas, the
world's fifth-largest deposits, behind China, the US, Argentina and Mexico, according to estimates
by Baker Hughes Inc.
Russia's Lukoil was reportedly interested in tapping unconventional gas deposits in the Empty
Quarter. "This is tight gas. The negotiations are under way. No details on deal and future
production plans yet," a spokesman for Lukoil Overseas was quoted as saying.

And in order to make unconventional gas economically viable, Saudi Aramco is endeavoring to
reduce the cost of producing natural gas from so-called tight rock formations, putting it on equal
footing to gas from the best plays in the US.
Saudi Aramco, is now targeting a cost of$2 to $3 per thousand cubic feet of tight gas, Adnan
Kanaan, of Aramco's Gas Reservoir Managing department said in a report published last month
by the Society of Petroleum Engineers.
The Kingdom, holding the world's fifth largest proven reserves of gas, expects domestic demand
for natural gas - used mainly for power generation - to almost double by 2030 from 2011 levels of
3.5 trillion cubic feet per year. After a decade of efforts, finding new gas resources still remains
one of the key challenges before the energy managers of the Kingdom.
NewBase Commentry :-
It is obvious that with growth in population in the KSA more electricity & water will be needed, thus
more energy source ( low cost ) are indeed needed . i.e. natural gas , rather than the current
crude oil usage in power plants . To save oil revenues being wasted in fuel subsidies and power
generation , along with low priced gas to mega
chemical plants when international oil & gas
price are 10 times the sale prices in KSA .
There are many steps to save the energy
crises expected :-
1- Ignore the search for unconventional
gas as its cost will never be below
$5/MMBTU
2- Gradually remove fuel , electricity,
water & gas to industries subsidies to
reach international prices or 10 % less
3- Divert the above budget allocated for
the above ( step 1& 2 ) to renewable
energy sources a long with nuclear
power generation in coastal areas ,,,
this is a must to survive the crisice
4- Study the break even cost for the gas injection in EOR with alternatives solutions to
increase or degrease the gas injection during summer , using international gas prices .
5- Allow private companies to generate power and government to contract in BOOT basis
along with other industrial practices currently impleneted in UAE using private companies.
6- Pressure to speed up the construction of the GCC power and water master grid to
efficiently generate power where gas is more available and at lower prices ,, Qatar could
house the master power station .
7- Ignore the construction of LNG terminal on the Red Sea coast and utilize the budget in
renewable , as this will escalate the gas prices issue a long with gas shotages issues .

Kuwait Oil Company evaluates bids on Lower Fars Phase-1 project
The wholly state-owned Kuwait Oil Company (KOC) is planning to drill more than 900 wells to
develop the heavy crude oil lying in the Lower Fars field in the north of Kuwait.
Discovered in 1978, the Lower Fars formation belongs to the Ratqa field, a reservoir saturated by crude oil.
Located along the Iraq border, the structure of Lower Fars reservoir lying in a shallow sandstone
underground appeared very quickly fragmented and heterogeneous, thus very challenging to develop.
Classified as extra heavy crude oil the gravity of the Lower Fars field is ranging between 17 API and 11 API
while the viscosity may vary from 10s to 1000s centipoises.
Because of its low depth in the ground, Lower Fars reservoir has a low natural pressure that will not help the
exploration and production of the field.

Despite all the challenges mentioned above, KOC intends to develop Lower Fars in order to compensate the
depletion of aging fields such as Burgan in targeting 5 million barrels per day (b/d) of crude oil production
in Kuwait by 2020.
In 2010, KOC awarded Foster Wheeler the front end engineering and design (FEED) contract for the
development of the Lower Fars field.
In 2012, WorleyParsons completed this FEED work.
According to WorleyParsons FEED conclusions, KOC has decided to develop Lower Fars in phases.
With $7 billion capital expenditure, KOC is planning to produce 60,000 b/d of crude oil by 2018 in a first
phase.
Drilling 900 wells then more than 1,300 wells, KOC is planning to ramp up the production up to 270,000
b/d of crude oil from Lower Fars.
The Lower Fars production is calculated to supply the giant Al-Zour New Refinery Project (NRP) running
in parallel.
Because of the nature of the extra heavy crude oil in Lower Fars reservoir, KOC and WorleyParsons have
decided to use the cyclic steam stimulation (CSS) technique.
Usually implemented in water-rich countries, such as Canada, the CSS technique will require in Kuwait
significant offsites and utilities to support the process.
Therefore Worley
Parsons designed the Lower
Fars Phase-1 project in three
packages:
- Oil central processing
facility (CPF) with water
treatment and waste treatment
- Pipelines systems including
crude oil inlet, water inlet and
oil export to terminal
- Offsites and utilities plus all
associated infrastructures
KOC qualified ten
engineering companies for these three engineering, procurement and construction (EPC) contracts.
Then KOC called for tender these Lower Fars EPC packages on October 2013.
Four engineering companies were bidding the first package estimated to $4.5 billion capital expenditure to
be awarded on second half 2014.

US: Oregon LNG wins DoE exports approval
Press Release
Oregon LNG has received authorization from the U.S. Department of Energy (DOE) to export
liquefied natural gas (LNG) to countries that do not have a Free Trade Agreement (FTA) with the
U.S.The approval comes notwithstanding recently announced modifications to DOE’s licensing
review process and adds strong momentum to Oregon LNG’s project, which is one of the most
advanced in the review process conducted by the Federal Energy Regulatory Commission (FERC).
“We applaud the DOE decision which places Oregon LNG in a very small group of projects in
North America that have received conditional DOE approval for non-FTA exports,” said Peter
Hansen, Chief Executive Officer of Oregon LNG. This approval allows the largest Asian buyers to
purchase from Oregon LNG, which already has authorization to ship to any of the twenty nations
with which the U.S. has an FTA.
“DOE approval is an important step towards the development of a project that will improve energy
security for many of our country’s key trading partners while simultaneously providing Oregon with
significant economic benefits and growth opportunities,” explains Hansen.
“Oregon is one of the nation’s most trade-dependent states, with trade supporting almost 500,000
Oregon jobs in 2012,” Hansen noted. “The Oregon LNG project will strengthen Oregon’s overall
economy and its position in international trade,” he adds.
The $6.3 billion project will create more than 3,000 direct construction jobs with specific amounts
of project spending to be directed towards small, local businesses. Also, the project has agreed to
create new opportunities for minority-, women-, and veteran-owned businesses. More than 150
highly-paid workers will run the plant on an ongoing basis, and the Oregon LNG project will create
more than 1,500 additional indirect and induced jobs in the region.
Canada’s National Energy Board recently authorized Oregon LNG to source from Canada, the
majority of the natural gas to be exported through the proposed terminal, which means that the
Warrenton facility could be operated with little or no impact on the price or supply of U.S. natural
gas. The Oregon LNG project will have the lowest pipeline transportation cost from Canadian gas
fields of any West Coast project.

Glencore gets $7 billion from Las Bambas mine sale
AFP + NewBase
Glencore Plc said it received $7 billion from the sale of one of the world’s largest copper projects,
the Las Bambas mine in Peru, and is expected to return at least half the cash to its shareholders.
Swiss-based Glencore’s announcement yesterday was the first time the
final sum for completion of the sale of Las Bambas to China’s MMG Ltd
and its partners has been revealed. Glencore had to sell the Las Bambas
project or other assets by September to win China’s approval for its
takeover of miner Xstrata last year, as Beijing feared the merged group
would hold too much sway over global copper supply.
“Glencore will continue to look for opportunities to reinvest capital,” the company said. “Any
surplus capital, subject to maintaining an efficient balance sheet… will be returned to
shareholders, within an appropriate time frame and structure.”
With the sale having closed on July 31, Glencore is in a strong position to announce a capital
return to shareholders with its half-year results due on August 20, rather than having to wait until
its annual results in February.
“It’s a lot of cash they don’t particularly need on their balance sheet,” said Tim Schroeders, a
portfolio manager at Pengana Capital. “I wouldn’t be surprised if they announced a special
dividend or capital return at the half-year results.” He estimated the company would return $3
billion to $5 billion over 12 to 18 months, rather than in a single hit.
MMG and its partners Guoxin International Investment Corp Ltd and state-owned CITIC Metal Co
Ltd agreed in April to pay $5.85 billion, plus the money spent by Glencore since the beginning of
2014 on building the mine.
MMG Chief
Executive Andrew
Michelmore was in
Peru yesterday
meeting the Las
Bambas team and
has said the
company would run
a detailed study
before updating
investors on plans
for completing the
mine and any
revised cost
estimates. The
mine, due to start
producing in 2015,
is expected to produce 2 million tonnes of copper in concentrate in its first five years of operation.

US:West Coast governors ‘strongly oppose’ offshore oil lease sale
Governors of California, Oregon and Washington are against the offshore oil & gas lease sale
proposed by the U.S. Department of Interior.
In a letter addressed to Sally Jewell, Secretary at U.S. Department of the Interior, Governor Edmund G.
Brown of California, John A. Kitzhaber of Oregon and Jay Inslee of Washington said their respective
states prefer clean energy and floating wind turbines, over a potentially devastating oil spill that could harm
their coastal dependent
economies.
Below is the letter in
full:
“As Governors of
California, Oregon,
and Washington, we
write to express our
strong opposition to
the inclusion of any
new proposed oil and
gas lease sale off our
shared coast in the
2017-2022 Outer
Continental Shelf Oil
and Gas Leasing
Program. Together,
our three states
represent the fifth
largest economy in the world.
Our ocean dependent industries contribute billions of dollars annually to our region and sustain our coastal
communities. Residents and visitors from around the world enjoy the recreation, scenic, and spiritual
bounty of our spectacular shores. While new technology reduces the risk of a catastrophic event such as the
1969 Santa Barbara oil spill, a sizeable spill anywhere along our shared coast would have a devastating
impact on our population, recreation, natural resources, and our ocean and coastal dependent economies.
Of equal importance is the commitment of our three states, together with British Columbia, to a
comprehensive and far-reaching strategy to combat climate change and promote a clean energy economy,
the Pacific Coast Action Plan on Climate and Energy. The Plan aligns closely with the President’s own
Climate Action Plan.
Our commitment to clean energy development in the marine environment is exemplified by the partnership
to usher in the nation’s first floating wind project and wave energy test facility located off the coast of
Oregon. Oil and gas leasing may be appropriate for regions where there is state support for such
development and the impacts can be mitigated. However, along the West Coast, our states stand ready to
work with the Obama Administration to help craft a comprehensive and science based national energy
policy that aligns with the actions we are taking to invest in energy efficiency, alternative renewable energy
sources, and pricing carbon. We must meet the environmental and economic imperative of climate change,
and in so doing, seize the opportunity for our region and our nation to build a low-carbon economy that can
be the envy of the world.”

Metal-based durables manufacturers are fueled by electricity and natural gas
Source: U.S. Energy Information Administration,
Unlike many manufacturing industries, the energy used for the production of metal-based durables (MBD)
is mostly electricity and natural gas, rather than other fossil fuels (residual fuel oil, diesel, liquefied
petroleum gases, natural gas liquids, and coal) or renewable sources. MBD producers are therefore well-
positioned to benefit from energy efficiency programs and the increased availability and lower cost of
natural gas.
MBD industries comprise fabricated metal products, transportation equipment, machinery, computers and
electronic products, and electrical equipment appliances and components. Cutlery, aircraft engines,
photocopiers, computer hard drives, and electric motors are some examples of the many products produced
in the MBD industries.
Many other industries are more energy intensive than MBD industries, including petroleum and coal
products, paper, primary metals, and chemicals. MBD industries used 942 trillion British thermal units (Btu)
of energy in 2010, according to the EIA Manufacturing Energy Consumption Survey (MECS) 2010. This
represents 7% of total manufacturing energy use.
MBD industries used 466 trillion Btu of electricity in 2010, representing nearly 20% of total electricity use
in manufacturing. Electricity accounted for nearly 50% of total energy used by MBD industries. Some other
industries where electricity use accounts for 40% or more of their energy use include textile mills, apparel,
and aluminum production.
MBD manufacturing is typically housed in a building, and the manufacturing processes are not as energy
intensive as many other industries. Direct non-process electricity use, which includes facility heating,
ventilation, and air-conditioning (HVAC), facility lighting, and other facility support, represents 36% of
MBD electricity use as compared to 14% of electricity use in other manufacturing (see graph below). As a
result, buildings are a particularly important part of efforts to reduce energy use in the MBD industries.

EIA's Annual Energy Outlook 2014 (AEO2014) projects that shipments for MBD industries will increase
substantially from 2012 to 2040. MBD industries will benefit from the increased availability and lower cost
of natural gas. These industries are expected to continue to have high levels of innovation that contribute to
growth, particularly in the computers and electronic products and transportation equipment industries. MBD
industries are also expected to continue to improve their international competitiveness. Given the high
dependence of MBD industries on electricity, there are significant potential benefits from improved energy
efficiency associated with machine drives, buildings, and the reduction of losses associated with on-site
electrical distribution systems.
Source: U.S. Energy Information Administration, Annual Energy Outlook 2014 Reference case

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 AwadKhaled Al AwadKhaled Al AwadKhaled Al Awadi is a UAE National with a total of 24 yearsi is a UAE National with a total of 24 yearsi is a UAE National with a total of 24 yearsi is a UAE National with a total of 24 years ofofofof
experience in theexperience in theexperience in theexperience in the Oil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working as
Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for
the GCC area via Hawk Ethe GCC area via Hawk Ethe GCC area via Hawk Ethe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager innergy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager innergy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager innergy 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 & gas compressor stations . Through the years , he has develoEmarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has develoEmarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has develoEmarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developed greatped greatped greatped great
experiencexperiencexperiencexperiences in the designing & constructinges in the designing & constructinges in the designing & constructinges in the designing & constructing of gas pipelines, gas metering & regulating stations and in the engineering of supply routes.of gas pipelines, gas metering & regulating stations and in the engineering of supply routes.of gas pipelines, gas metering & regulating stations and in the engineering of supply routes.of gas pipelines, gas metering & regulating stations and in the engineering of supply routes.
Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs forMany years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs forMany years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs forMany years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs for tttthe localhe localhe localhe local
authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andauthorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andauthorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andauthorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcastedEnergy program broadcastedEnergy program broadcastedEnergy program broadcasted
internationally , via GCC leading satellite Channels .internationally , via GCC leading satellite Channels .internationally , via GCC leading satellite Channels .internationally , via GCC leading satellite Channels .
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase 03 August 2014 K. Al Awadi

New base special 03 august 2014

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