New base special 03 june 2014

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NewBase 03 June 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Dolphin Energy reports zero interruption in supply, 100%
plant availability
Dolphin Energy has reported zero interruption in supply to customers and about 100% plant
availability throughout the year, besides achieving about 23mn man-hours without a lost time
incident.
These, along with 52% Emiratisation and 29% Qatarisation levels, were reported by Dolphin
Energy, which is involved in the production and processing of natural gas from Qatar’s North Field
and transportation of the dry gas by sub-sea export pipeline from Qatar to the UAE, at its 2013
Sustainability Report. Environmental
commitments saw Dolphin register a 20%
reduction in flaring, a 4% in total greenhouse
gas emissions, a 51% in sulphur dioxide
emissions and a 12% in water consumption.
“Last year emphasised the role we played in
meeting the requirements of our customers,
it highlighted our continued commitment to
environmental stewardship and illustrated
our commitment to fulfilling a responsibility to
supporting the communities in which we
operate,” Dolphin Energy’s CEO, Ibrahim
Ahmed al-Ansaari said.
Notable achievements for the year saw positive developments in the company’s economic,
environmental and societal performance with the successful negotiation of a gas agreement to
help meet customer requirements over the summer months.
Community investment contributions crossed the $4mn mark in 2013 and included the inaugural
Dolphin Energy Doha Dash, a mass community fun run held to mark Qatar National Sport Day
and the first of its kind in the country.
In 2013, the company further incorporated the principles of sustainability into its management
system with the development of a sustainability management plan and policy.
“The policy sets out five strategic objectives to focus our approach — we strive to put our people
first, operate with excellence, create value, protect the environment and become a better
corporate citizen. This will drive our performance in 2014 and in the years ahead,” al-Ansaari said.
DEL Gas Processing Plant in Ras Laffan - Qatar

Oman Oil Refineries and Petroleum Industries starts work on
Sohar refinery expansion project . BYTIMES NEWS SERVICE,
Oman Oil Refineries and Petroleum Industries (Orpic) has conducted a groundbreaking
ceremony for its Sohar Refinery improvement project on Monday.
Sohar Refinery will add 82,000 barrels per day (bpd) to its existing capacity of 116,000bpd, taking
the total capacity to 198,000bpd. This indicates an 70 per cent growth in fuel production- 90 per
cent for diesel, 37 per cent for gasoline, 93 per cent for kerosene, 93 per cent for jet fuel, 91 per
cent for LPG, 175 per cent for naphtha and 44 per cent for propylene.
The project will improve the refinery's overall efficiency and productivity by overcoming the
existing technical constraints resulting from the change in Oman export blend crude quality. This
will give Sohar Refinery the ability to meet the increasing demand for oil and refined products,
supporting the economic development of the Sultanate. Within the company's operations, the level
of integration will be raised significantly, with both the aromatics and polypropylene plants
receiving increased feedstock
requirements from within the Orpic
Sohar complex, replacing imports, said a
company release.
As a result, Sohar Refinery will take its
place as one of the high capacity
manufacturing operations in the region,
and thanks to the current Residue Fluid
Catalytic Cracker (RFCC) unit and the
additional five new units such as the
Hydrocracker, it will be able to refine
crude oil of a much greater range of
quality. The new additions will also
enable the refinery to further increase
utilisation of each barrel of Omani crude.
The refinery will be able to handle all
primary initial quantities entering its units, allowing the output of refining operations to be high-
quality fuel and high-value petrochemical products. The project will also enable the refinery to
cope with unforeseen changes in crude oil quality, demonstrating the project's importance at the
national level in enhancing the extracted value from an oil barrel.
The event was organised under the patronage of Muhana bin Saif Al Malki, Governor of Al Batina
North Governorate, and in the presence of Musab bin Abdullah Al Mahruqi, chief executive officer
of Orpic.
"This is a highly significant moment for all of us at Orpic, and for the nation. The first of our three
major projects is now officially under construction. On completion Sohar refinery Improvement
Project (SRIP) will begin the fulfilment of Orpic's mission and vision by ensuring the nation's fuel
needs are met and that our plants environmental performance is significantly better. It will ensure
deeper conversion of the Omani crude barrel and extract more value that currently the case."
It marks a major step forward in Orpic's future plans as it will significantly improve environmental
performance and help Sohar Refinery overcome constraints resulting from changes in the quality
of Oman export blend crude oil. A key outcome of SRIP will be the guarantee that the Sultanate's

increasing demand for fuel will be met. Orpic has recently awarded the engineering, procurement
and construction (EPC) contracts to Daelim of South Korea and UK based Petrofac, and signed a
contract for supply of the long lead equipment required for the project with a number of
companies, all of which have long experience in implementing such projects.
Employment opportunities
SRIP will also offer more than 500 new jobs. To staff the project a blended approach will be used,
with new graduates and diploma holders being appointed to compliment experienced employees
from the Sohar and Mina Al Fahal refineries, who will in turn have to be replaced by a new intake
of talent. The company recently announced over 250 job opportunities for Omani graduates,
continuing its mission to empower Omani youth and provide them with the necessary skills and
knowledge needed for specialised jobs. Omanisation in the company currently stands at nearly 73
per cent.
Environmental improvements
Enhancement of environmental performance will be a key benefit that SRIP will bring to Sohar
Refinery. The new units will ease the pressure on the existing set-up in the refinery which
currently operates at maximum capacity to meet the growing fuel demand in the Sultanate.
With the new units online emissions resulting from capacity pressure will be reduced. After the
improvement, the refinery will be also able to process high density crude oil effectively, which will
in turn increase performance efficiency and operational utilisation and reduce the potential for
technical failures as a result of the challenge of processing high density crude oil, and for resulting
emissions and odours.
In-country value support
In-country value (ICV) is a key theme for Orpic, so the company has developed frameworks and
insights to support ICV within SRIP,
offering the maximum benefit to local
business owners from the economic
value of the various elements of the
project. Meetings have already been
held between the SRIP contractor and
the local vendors in the Al Batinah
North Governorate. These meetings
will continue to engage with potential
local and national suppliers throughout
the project execution stage in order to
maximise the value from the project.
Orpic currently provides 100 per cent
of the Sultanate's needs of fuel, so
with SRIP raising the refinery's
productivity, Orpic will be able to meet
growing local demand (10 per cent per
annum) and increase profitability.

Oman LNG: 2013 Revenues at USD 4.49 Billion
Oman LNG said that the company’s revenues were at $4.49 billion in 2013, $149 million higher when
compared to 2012. The company operates 3 liquefaction trains with a capacity of 10.4 mtpa ( 1,500
CF/day or 1,600,000 MMBTU /day )) at its site in Qalhat near Sur. Two of the trains are owned by Oman
LNG and one by Qalhat LNG.
Oman LNG’s net income after tax was $2,018 million in 2013, an increase of $68 million from 2012, the
company said in its annual report for 2013. According to the report, 139 cargoes were loaded from Oman
LNG’s plant in Sur last year, 90 for Oman LNG and 49 for Qalhat LNG. Oman’s LNG industry entered a
new era in September of 2013 with the fusion of the country’s only two liquefied natural gas companies,
Oman LNG and Qalhat LNG, into one fully integrated entity.

Iraq: Gazprom Neft begins production at the Badra oil field
Source: Gazprom Neft
On 31 May, Gazprom Neft began production at the Badra oil field in Iraq. The central gathering station
(CGS) is currently undergoing complex testing of its crude oil processing system. Testing will be completed
in three months once enough oil has been accumulated for commercial production to begin. The Badra field
will then be ready to reach
planned production levels
of 15 thousand barrels per
day. The Badra oil field is
located in Wasit Province
in Eastern Iraq
New infrastructure for the
field’s commercial
development has been put
in place. The CGS’s first
line has been constructed
with a capacity of 60
thousand barrels per day
and in March 2014 the
Badra field was connected
to the 165–kilometre-long
main Iraqi oil pipeline
system. Production in the
field will reach its peak of
170 thousand barrels per
day (around 8.5 million tonnes per year) in 2017 and then remain the same for a period of 7 years.
Vadim Yakovlev, First Deputy CEO of Gazprom Neft said:
'Development at the Badra field is one of Gazprom Neft’s first international assets in oil production. We
launched this project from scratch and over a short period of time have completed all of the complex work
necessary for the industrial development of the Badra field. The experience of being an operator on this
project has further strengthened Gazprom Neft’s expertise, which will contribute to work on other new
projects, for example in the Near East and other regions where the company is exploring opportunities for
further development.'
Background
The Badra oil field is located in Wasit Province in Eastern Iraq. According to preliminary estimates,
geologic reserves at the Badra field amount to 3 billion barrels of oil. The contract with the Iraqi
government for development of the oil field was signed in January 2010 upon completion of a bid process.
The winning bid was submitted by a consortium of companies consisting of Gazprom Neft, KOGAS
(Korea), PETRONAS (Malaysia), and TPAO (Turkey).
Gazprom Neft is the project operator. Gazprom Neft’s share in the project is 30 percent, while KOGAS has
22.5 percent, PETRONAS has 15 percent, and TPAO has 7.5 percent. The share of the Iraqi government,
represented in the project by the Iraqi Oil Exploration Company (OEC), is 25 percent. Under the contract,
investors will be reimbursed for costs incurred and paid a fee of $ 5.5 per barrel of oil equivalent produced.
The Badrah development project has a projected lifetime of 20 years with a possible extension of five years.

Nigeria: Seadrill secures commitment from Total for newbuild ultra-
deepwater unit West Jupiter . Source: Seadrill
Seadrill has secured a contract with Total Upstream Nigeria for employment of the newbuild ultra-
deepwater drillship West Jupiter, in support of the EGINA ultra-deep offshore project in Nigeria. The
contract is for a firm period of 5 years and has a total revenue potential for the primary contract term of
approx. US$1.1 billion inclusive of mobilization. Seadrill's total consolidated backlog stands at approx.
US$20 billion with the execution of this contract.
The West Jupiter is one of eight 6th generation drillships currently under construction for Seadrill and is
expected to be delivered from the Samsung Heavy Industries shipyard in Geoje, South Korea in August
2014. The rig will be outfitted to work in up to 10,000 ft of water and is capable of water depths up to
12,000 ft and drilling depths up to 37,500 ft.
Per Wullf, Seadrill CEO commented, 'We are very pleased to have been chosen by Total and its
partners for this important project. This contract provides an opportunity to deepen our
relationship with a key customer and strategically increase our rig fleet in Nigeria, adding the West
Jupiter alongside the West Capella which has been operating in the Usan field Offshore Nigeria
since 2008. Seadrill takes pride in continuing to build its presence in the Nigerian oil & gas
industry'.

Norway: Faroe Petroleum announces spudding of Centrica-operated
Butch South West exploration well 8/10-6S .. Source: Faroe Petroleum
Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and
production opportunities in Norway, the Atlantic margin and the North Sea, has announced the spudding of
the Centrica-operated Butch South West exploration well 8/10-6S (Faroe 15%).
Butch South West, which is adjacent
to the Company's 2011 Butch
discovery, is situated in approx. 65
metres water depth in the Norwegian
North Sea, close to significant existing
infrastructure with the giant Ula field
approx. seven kilometres to the north-
west, Tambar approx. ten kilometres
to the south west and Gyda approx. 20
kilometres to the south.
The significant Butch Main oil
discovery (Faroe 15%) was made in
late 2011 and contains a light crude oil
in a high quality reservoir, the Upper
Jurassic reservoir of the Ula
formation. The Butch South West
exploration well is located in a
separate segment from both the Butch
East well, the results of which were
announced on 12 May 2014, and the
Butch Main well.
The operator is currently working on a
development plan for the Butch Main
discovery, in parallel with drilling the
Butch South West well. If Butch South
West is successful the development has the potential to become a stand-alone design, with its own dedicated
facility, instead of a sub-sea tie-back to existing nearby infrastructure.
The Butch licence drilling operations are operated by Centrica (40%) using the Maersk Giant jack-up
drilling rig, together with the other joint venture partners Suncor Norge AS (30)% and Tullow Oil Norge
AS (15)%.
Graham Stewart, Chief Executive of Faroe Petroleum commented:
'We are pleased to announce the spudding of the Butch South West exploration well which, if successful,
offers the potential to add substantially to the volumes and value of the Butch field, as the adjacent Butch
Main field is already on track for near-term development. In the near term we also look forward to reporting
the results from exploration drilling on the Bue prospect (Faroe 25%) in the Norwegian Sea in close
proximity to the recently announced significant Pil oil and gas discovery.'

The Challenges that face Mediterranean leviathan
By: Dirk Frame, T.A. Cook Consultants, Germany
Economic advancement, population growth and with it, a sudden increase in energy demand
mean that recent offshore natural gas developments in the eastern Mediterranean could engineer
a power shift in the region, ultimately resulting in a new Eastern Mediterranean Energy Corridor.
However, continuing political tensions between the key players pose a serious threat to the
success and even the very existence of regional upstream projects.
This article will examine the recent offshore natural gas discoveries in the region, with particular
focus on Cyprus, Turkey and Israel to explore how energy infrastructure is the focal point upon
which the entire success of upstream development in the region pivots.
Recent discoveries
In 2009, Texas-based Noble Energy announced the discovery of 250 billion m3
of gas in offshore
Israel: the Tamar field. Shortly afterwards,
Noble then announced the discovery of the
Leviathan field (worth 476 billion m3
) in
offshore Israel, as well as the Aphrodite
field, which lies in offshore Cyprus. These
findings were then supported by the United
States Geological Society: in 2010 it
published a report on the Levant Basin,
which lies underneath Syria, Lebanon,
Israel, Jordan, Palestine and the waters
between those countries and around
Cyprus and Turkey.
The report concluded that a total of 1.7
billion bbls of undiscovered oil and 122
trillion ft3
of undiscovered gas resources
lay in the basin as a whole, adding a whole new angle to the investment interest in the area.
According to a report by the US Energy Information Administration (EIA), those discoveries “could
meet current regional demand almost indefinitely.”
The fact that Israel alone consumed 90.5 billion ft3
of gas in 2011 but only produced 87.5 billion
ft3
, thus forcing the country to import energy from its neighbours, means that both the financial
and economic value of these discoveries is significant.
Leviathan politics
While Israel has traditionally filled the gap between oil supply and demand via imports, its gas
needs had been accounted for by the El Arish-Ashkelon Pipeline running between Israel and
Egypt, and owned and operated by the East Mediterranean Gas Company (EMG). However,
following the 25 January revolution in Egypt in 2011, many Egyptians called for the ending of gas
exports to Israel, some even accusing it of breaching its obligations and of having stopped
payments a few months prior. In 2012, gas supplies to Israel were unilaterally halted, representing
a new low in political relations between the countries.

As Israel has begun to receive supplies from its Tamar and Mari-B fields since the beginning of
2013, it no longer needs the El Arish-Ashkelon Pipeline. Indeed, according to current forecasts the
Leviathan and Tamar fields together can meet Israel’s domestic needs for up to 25 years and may
transform the country into a net exporter of gas. As Tamar is considered to be able to fulfil Israel’s
domestic requirements alone, it
is likely that Leviathan outputs
will be pushed towards export.
However, two obstacles
currently hamper such a golden
future for Israel. Firstly, the fact
that the Leviathan spoils lie
beneath more than 5000 ft of
water means that significant
investment will be required in
order to remove the oil and gas
that lies there safely and
profitably. That investment not
only depends on the security of
the region, but also on the
clarity of Israeli policy towards
exports.
Currently, the ownership of the
Leviathan field is split between
Texas-based Noble Energy,
Israel’s Delek Drilling and Avner
Oil Exploration,
Ratio Oil Exploration and
Australia’s Woodside Petroleum
Limited, to whom the partners
sold a stake earlier this
February. However, following the US$ 2.3 billion investment from Woodside, some uncertainty
has prevailed over the future of the project, due largely to the reluctance of the Israeli government
to clarify exactly how much of the recoverable resources they will allow the partners to export. In
an analyst conference presentation given on 17 December, 2013, Noble stated that the figure
stood at 40% of the total, but the delays had already caused the company to postpone their
production start-date for a year to Q4, 2017.
A new energy axis
The resulting drop in partners’ share prices that followed has no doubt caused some to carefully
consider their investment, while further disputes with Lebanon over a maritime border between the
two countries could lead to further instability. The risk that ongoing troubles in Syria could spill
over into Lebanon exists and contributes strongly to the pressing need to find a way of
transporting oil and gas from these fields safely to Europe. As the extension of the Arab Gas
Pipeline through Syria to Turkey is unlikely to happen in the near future and taking into account
the unrest in Egypt, not to mention the number of jihadist attacks on the pipeline in Sinai over
recent years, another way of connecting the fields in the eastern Mediterranean sea to Europe is
urgently needed.

This is where Cyprus, Greece and Turkey come into the picture. Noble, again a key player in the
region, gained the exploration rights of Block 12 in Cyprus’ Exclusive Economic Zone (EEZ) in
2008, where it then went on to discover the Aphrodite field. Following its finds there, Total of
France went on to pay Cyprus €24 million for the license to explore Blocks 10 and 11, while Italy’s
ENI and South Korea’s KoreaGas Corp. (Kogas) gained access to Blocks 2, 3 and 9. Production
is not expected to start until 2018 for domestic use and 2019 for export, but that still leaves little
time for the transport problem to be solved.
The first and most cost-friendly option would be to build a pipeline to Turkey in order to feed into
existing infrastructure there, but Turkey claims the waters in which Aphrodite lies as its own and
therefore rejects the Cypriot claim to it. Cypriots worry that even if an agreement could be reached
with Turkey as to ownership and use, Turkey would use it as a political tool against them.
As a result, in November 2012 Cyprus, Greece and Israel agreed to set-up an Eastern
Mediterranean Energy Corridor, which would connect gas from offshore fields in Israel and Cyprus
to a liquefying plant at Vassilikos, Cyprus and to ship it on from there to Greece. This project
contains a number of advantages: firstly, Leviathan and Aphrodite are only 34 km apart from each
other, meaning connecting their supplies would not be too difficult; and secondly, it conveniently
bypasses Turkey. Additionally, some domestic resistance in Israel against building LNG plants at
Ashdod, Ashkelon and Eilat mean that building the plant at Vassilikos Cyprus handily gives Israel
access to the EU without too many problems on home soil.
There are however, some drawbacks to this project. The cost of building the LNG plant at
Vassilikos is estimated at US$ 6 billion, which Noble, Delek, Avner and the Cypriot government

will share in parts, perhaps supported by ENI, Kogas and Total at some point in the future. The
area at Vassilikos is, though, only approximately 2 km2
and some question whether it will be able
to support the level of exports the investors plan. For Israel, there is some concern as to how to
control export revenues, which as mentioned above, is a key issue for the Israeli government.
Equally, should Cyprus become further entangled in deeper political tensions with Turkey, the
security of the plant and the whole project could be jeopardised.
Perhaps the most appealing option of all ,until tensions in the area relax is a floating liquefied
natural gas (FLNG) installation. The Tamar FLNG project, which attempts to draw on volumes
from the Tamar field is estimated to cost around US$ 5 billion, but would allow the export of
almost 144 billion ft3
per
year.
The skills required not only
to make such projects
materialise but to function
safely and profitably
demand a high level of staff
expertise and advance
planning though, which can
sometimes mean huge
cultural barriers need to be
overcome. Operating in an
area riddled with political
and religious dispute and
occupied by military forces,
which are sometimes hostile
towards one another makes
employee safety perhaps
the most important issue. This factor alone will likely deter the influx of skills from abroad, adding
handsomely to the cost of employment and employee protection. Where skilled workers can be
recruited locally, the probability that deep cultural tensions would exist between them is high and
could require some nifty managerial footwork to keep operational peace.
Furthermore, the inherently dangerous nature of working offshore with resources that lie so deep
means that particularly stringent safety operations and transport logistics processes must be put
in place. External factors such as wind speed, direction and currents must also be taken into
account, while traffic concentration and helicopter or boat utilisation will need to be regularly
scrutinised. If space is limited, poor platform and deck space organisation can further add to
costs: operators will need to be extremely vigilant if blocks are to be made – and kept – profitable.
Worldwide influence
Taking into all of these aspects into account, it is likely to take some time before any of the fields
connect with EU soil. The EU has a vested interest in the development of the Eastern
Mediterranean Energy Corridor due to its current dependence on the Russian Federation, Norway
and Algeria for gas. Obviously, the Russian Federation is keen to remain prominent in the area
and has so far been the largest foreign direct investor in Cyprus, bailing out the island’s banking
sector at the end of December 2011. It has also been actively collaborating with Israel, with whom
it signed an initial agreement to export LNG from Tamar early last year.

The entire issue as well as all of the projects associated with these discoveries depends
fundamentally on the growth of demand for gas in the EU and the willingness of Israel to co-
operate in terms of exports. While some predict gas demand to continue to increase steadily after
a sudden decrease following the financial crisis, the EIA expects demand growth to slow to levels
seen before the recession. If the latter scenario occurs, then the viability of any of the projects
outlined above will be crucially undermined.
Equally, if Israel decides to change its policy towards the amount of gas that it allows to be
exported, the return could prove to be too low for key investors, without whom the fields will
remain untapped for an indefinite period of time. Even if policy remains stable, the delays that
Leviathan has already suffered are estimated to be costing the country almost US$ 1 billion a
month in savings, according to estimates from Mr. Silvan Shalom, Minister of Energy and Water
Resources in Israel.
Wider impact
Regardless of the above speculations as to what form the Eastern Mediterranean Energy Corridor
may take, the fact that energy majors such as ENI and Total are willing to invest such large sums
means that the risk is likely, at least in their eyes, to be worth taking. As long as the key players
can find a way to work together without becoming embroiled in the many and varying regional
conflicts in the area, the corridor could provide a way for Cyprus and Greece to climb out of debt
and for Israel to take on a new role as energy supplier. That in itself could have a major impact not
only on relations between Israel and its neighbouring countries, but also on the wider energy
market.
Dependence on Norwegian imports and the impending vote in September as to Scottish
independence from the United Kingdom (implicating the natural reserves of the North Sea at the
same time) could all lead the EU to lean favourably towards supporting growth in the eastern
Mediterranean. That so many factors affect the development of the Levantine fields and that their
development in turn has such wide-reaching effects – both politically and economically – makes it
an unusually unique case. Whether it actually materialises though remains dependent on the
ability of all parties to work together: a Leviathan task.

EIA: 84% of U.S. Energy Demand Satisfied by Domestic Production
Press Release, June 2, 2014
Total U.S. energy production reached 81.7 quadrillion British thermal units (quads) in 2013, enough
to satisfy 84% of total U.S. energy demand, which totaled 97.5 quads.
Natural gas was the largest domestically produced energy resource for the third year in a row and,
together with the other fossil fuels (coal, crude oil, and hydrocarbon gas liquids), accounted for
more than three quarters of U.S. energy production. In total, the United States consumed 97.5 quads
of energy, 82% of which was fossil fuels. Renewable and nuclear energy made up 10% and 8%,
respectively, of U.S. energy consumption.
The portion of U.S. energy consumption supplied by domestic production has been
increasing since 2005, when it was at its historical low point (69%). Since 2005, production
of domestic resources, particularly natural gas and crude oil, has been increasing as a result
of the application of technologies that can develop harder-to-produce resources. At the same
time, reduced road travel, improved vehicle efficiency, and competition among fuels for
electric power generation have limited consumption of petroleum and coal.

The last significant rise in the ratio of domestic production to consumption occurred from 1978 to 1982.
During that period, oil consumption declined in response to higher prices and changing policies, and
production rose as oil started to flow from Alaska’s North Slope. At the same time, domestic coal
production was increasing.
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 &Oil &Oil &Oil & Gas sector. Currently working asGas sector. Currently working asGas sector. Currently working asGas 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 Energy Service as a UAE operations base , Most of the experience were sthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were sthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were sthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operationspent as the Gas Operationspent as the Gas Operationspent as the Gas 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 developedhas developedhas developedhas 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 & regulof gas pipelines, gas metering & regulof gas pipelines, gas metering & regulof gas pipelines, gas metering & regulating stations and in the engineering of supplyating stations and in the engineering of supplyating stations and in the engineering of supplyating stations 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 forOUs forOUs forOUs for
the local authorities. He has become a reference for many of the Oil & Gasthe local authorities. He has become a reference for many of the Oil & Gasthe local authorities. He has become a reference for many of the Oil & Gasthe local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andConferences held in the UAE andConferences held in the UAE andConferences held in the UAE and Energy program broadcastedEnergy program broadcastedEnergy program broadcastedEnergy program broadcasted
internationally , via GCC leading satelliteinternationally , via GCC leading satelliteinternationally , via GCC leading satelliteinternationally , via GCC leading satellite ChannelsChannelsChannelsChannels ....
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
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New base special 03 june 2014

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