New base 554 special 05 march 2015

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 05 March 2015 - Issue No. 554 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
ADNOC signs MoU with Korea's KNOC, KIGAM for cooperation
on oil field development
(WAM + NewBase) The Abu Dhabi National Oil Company (ADNOC) on Wednesday signed a
Memorandum of Understanding (MoU) with the Korea National Oil Corporation (KNOC) and Korea
Institute of Geoscience and Mineral Resources (KIGAM). The MoU provides for cooperation in
research and development activities for oil fields development in UAE.
The agreement was signed by Abdulla Nasser Al Suwaidi, ADNOC’s Director General, Moon Kyu
Seo, KNOC’s President and CEO and Kyu Han Kim, KIGAM President in the presence of a
number of senior officials from all parties.
By entering into the MoU, ADNOC, KNOC and KIGAM have expressed their intentions to promote
joint research and technological cooperation related to oil concessions in UAE. The scope of
cooperation will include petroleum geology/geophysics/basin/geo-chemical analysis; reservoir
characterization by using field data; well stimulation and enhanced oil recovery considering the
reservoir characteristics. ADNOC, KNOC and KIGAM also have plans for exchange of experts,
regular technical seminars and workshops, aiming at promoting R&D cooperation.

Abdulla Nasser Al Suwaidi, ADNOC Director General, said "initiatives such as the recent signing
of a Memorandum of Understanding (MoU) between ADNOC, KNOC and KIGAM reinforce
ADNOC’s commitment to grow its oil and gas portfolio capacity and demonstrate that ADNOC
have a road map to achieve this objective through research and development (R&D.)" "ADNOC
fully believes in the importance of scientific research and modern technology in enhancing oil
recovery, for that end we are seeking to build constructive partnerships with the major
international companies to provide a solid research and development that contribute to our efforts
aiming at increasing ADNOC’s oil and gas portfolio capacity", he added.
On his part Kyu Han Kim, President of KIGAM, said, "Through the MoU, KIGAM is going to
expand joint research collaborations with UAE, the oil-producing country with advanced
technologies". He also added that as a leading organization responsible for R&D program, KIGAM
is committed to do its best to make sure that joint research and exchange of experts will go as
smoothly as planned.
Moon Kyu Seo, President and CEO of KNOC, said that "We highly anticipate this MoU will be able
to give a momentum for ADNOC, KNOC and KIGAM to implement field oriented R&D programs in
our concessions. And I hope this cooperation in R&D will contribute to benefits in technology and
economics of Haliba’s appraisal and development." It is expected that this partnership between
UAE and Korea will be helpful not only to strengthen the R&D capabilities of all the
parties(ADNOC, KIGAM, and KNOC), but also to bring higher productivity to the oil field business,
currently operated by Al Dhafra.
Korea Abu Dhabi Oil Corporation (KADOC), the Korean Consortium which joins KNOC and GS
Energy is currently engaging in development activities in three oil concessions. Al Dhafra
Petroleum Operations Company, a product of a Joint Venture and Field Entry Agreement that was
signed in 2012 between ADNOC and KADOC, is now engaging in overall activities in the three oil
concessions.

Qatar oil production drops to 674,000 bpd in January 2015
Gulf Times + NewBase
Weaker global demand has seen Qatar’s oil production falling to about 674,000 bpd in January,
new data shows. But, according to QNB, “redevelopment plans” should “stabilise” output going
forward.
Qatar Petroleum (QP) is implementing a redevelopment programme to “steady production” at its
oil fields. This “heavy investment” in maturing oil fields should “limit further declines” in oil
production, QNB said in its ‘Monthly monitor’. Qatar oil prices fell in January owing to weaker
global demand, it said.
The stagnant eurozone economy, recession in Japan and slowdown in emerging markets,
especially China, are contributing to the weakness in hydrocarbon demand and an oil supply glut,
which is putting downward pressure on international oil prices.
Earlier in its ‘Qatar Economic Insight 2015’ QNB said the Barzan project is expected to drive
growth in the hydrocarbon sector, which may grow by 0.8% in 2015, 1.8% in 2016 and 1.9% in
2017 despite declining oil production due to maturing oil fields.
Lower hydrocarbon revenue and rising capital spending are expected to tip the fiscal balance into
deficits of 2.2% of GDP in 2015, 3.4% in 2016 and 3.7% in 2017. Hydrocarbon revenue is
expected to decline with lower oil prices and crude oil production, but this will be partly offset by
higher non-hydrocarbon revenue, supported by better corporate tax collection.
The ‘Monthly monitor’ said Qatar’s international reserves fell slightly to $41.1bn at end-January
2015. This compares to $41.9bn at end-January 2014. Despite the slight fall, the import cover
remains more than adequate at 7.5 months of prospective imports at end-January 2015, well
above the IMF-recommended level of three months for pegged exchange rates.
More broadly, Qatar’s international reserves have been steadily rising over the years on large
current account surpluses.
Going forward, QNB
expects international
reserves to remain broadly
stable at eight months of
prospective import cover
over the medium term,
notwithstanding the lower
trade surplus.
Qatar’s foreign
merchandise trade balance
registered a surplus of
QR18.5bn in January 2015,
down from QR35.8bn in
January 2014.
This, QNB said, was mainly
a result of lower
international crude oil prices. Total exports fell by 36.7% year-on-year. At the same time, QNB
said, imports rose robustly (10.2% year-on-year), reflecting the growing population and large
investment spending

Indian State of Gujarat to Get Two New LNG Terminals
Press trust of India + NewBase
Government of Indian state of Gujarat plans to set up two more LNG terminals of 10 Million Metric
Tonnes Per Annum (MMTPA) combined capacity in the near future.
According to Press trust of India, this information was provided in the state assembly on Tuesday
by state’s Chief Minister Anandiben Patel who handles the ports portfolio.
Currently there are two LNG terminals in operation in the state, one at Hazira in Surat and the
another at Dahej in Bharuch district. Both these terminals have a combined capacity to handle
17.5 MMT LNG per annum.
The two new terminals being planned are expected to come up at Jafrabad in Amreli district and
at Mundra port in Kutch district, Patel said in a written reply . Patel said that an LNG port terminal
with Floating Storage and Re-gassification Unit (FSRU) with a capacity of 5 MMTPA would be
built in Jafrabad, Press Trust reported.
According to Press Trust, for the Jafrabad project, Gujarat Maritime Board (GMB) had selected
Swan Energy Ltd as the developer on a Build, Own, Operate and Transfer (BOOT) basis.
For the Mundra project Adani Group and the state government-owned Gujarat State Petroleum
Corporation (GSPC) have joined hands to set up an LNG import terminal at Mundra with an initial
capacity of 5 MMTPA.

Asian Spot LNG Price Could See Short Term Relief,
Says Wood Mackenzie
Decline in Asian LNG spot prices will find temporary relief in the summer with demand growth in
the Pacific outpacing that of global LNG supply, Wood Mackenzie said in its new quarterly
analysis of global LNG fundamentals.
However the energy consultant added that as new Australian LNG supply ramps up towards the
end of the year, prices will come under further downward pressure, converging back to European
spot prices.
"For the first time since 2009, Asian LNG spot prices are trading at a discount to European spot
prices, like the NBP. Benign weather conditions in North East Asia and ample supply availability,
combined with low oil prices continues to put pressure on Asian LNG prices. In contrast, high
seasonal demand and the cap imposed on Groningen production for the first half of 2015 are
resulting in European spot prices trading relatively high and close to oil indexed contract prices,
despite abundant LNG imports,” Massimo Di-Odoardo, Principal European gas analyst for Wood
Mackenzie said.
However, Di-Odoardo warns that a typical summer price decline is not assured, that instead Asian
LNG and European spot price levels will be sustained through this summer. And, further, that
rising winter prices are also not assured, and that instead prices in Q4 will fall, despite the
beginning of the winter season.
Yingying Zhou, Asia LNG research analyst for Wood Mackenzie summarises the outlook for Asian
demand: "The restart of some nuclear capacity in Japan and the commissioning of new nuclear
and coal capacity in South Korea will result in lower demand in 2015. However under normal
weather conditions we expect more LNG demand in China, while the ramp up of new contracts
and more regasification capacity will facilitate new demand in South East Asia, India and the
Middle East. Overall, we expect Asia Pacific LNG demand to be some 6 million tonnes higher in
2015 compared to last year, despite Q1 being lower."
The prognosis for Asia in the summer is that spot prices should rise, Through Q2 and Q3 Wood
Mackenzie forecasts year-on-year demand growth to outpace that of LNG supply, helped by
reduced LNG supply from West Africa, North Africa and SE Asia. However, spot prices will be
capped by fuel oil equivalent levels, peaking around $8.5 per million British Thermal Unit
($/mmbtu), it stated.

Angola: VAALCO Energy spuds its first well on Block 5 offshore
Source: VAALCO Energy + NewBase
VAALCO Energy on March 2, 2015, spudded the post-salt Kindele-1 well, its first exploration well
on Block 5 offshore Angola. As previously announced, VAALCO contracted the Transocean
'Celtic Sea' semi-submersible rig to drill
the Kindele-1 well to a planned total depth
of 2,250 meters in a water depth of
approx. 100 meters.
Steve Guidry, Chairman and CEO,
commented, 'We are very pleased to
announce this major step forward for our
operations offshore Angola. After nearly
nine years of continued commitment to
our Block 5 license, we are embarking
on an important phase in our efforts to
explore for hydrocarbons from a second
West African country. We continue to
believe that Block 5 is within an area
with potential in both post- and pre-salt formations including the syn-rift and sag play.'
As previously announced in October 2014, VAALCO, together with its working interest partner,
Sonangol P&P, entered into the Subsequent Exploration Phase ('SEP') on Block 5. Under the
SEP, VAALCO and Sonangol P&P have committed to drill a total of four exploration wells during
the exploration extension period, which expires in November 2017. The four-well obligation
includes the original two-well commitment under the primary exploration period that carries over
to the SEP period.
The Kindele-1 well will test a fault block adjacent to the Mubafo discovery which tested oil from
the Mucanzo sand
section within the Pinda
group formations. The
Kindele-1 will be drilled
to a depth of 1,800
meters to evaluate the
Mucanzo sand section.
The well will then be
deepened to the salt to
an estimated depth of
2,250 meters for
geologic and
geophysical
correlation. The well is
expected to take
approx. six weeks to
drill to total depth.
Additionally, the Company is nearing finalization of the seismic processing in the outboard
portion of Block 5. The seismic processing is being performed to image pre-salt structures as
potential targets for future exploration wells on Block 5.

Exxon Mobil reduces 2015 capex by 12%
U.S. oil giant Exxon Mobil today said it expects its capital expenditure for 2015 will be $34 billion
in 2015 – 12 percent less than in 2014. The company further said that annual capital and exploration
expenditures are expected to average less than $34 billion in 2016 and 2017.
“We are capturing savings in raw materials, service, and construction costs,” Rex W. Tillerson, chairman
and chief executive officer said. “The lower capital outlook also reflects actions we are taking to improve
our set of opportunities while enhancing specific terms and conditions and optimizing development plans.”
He said that Exxon Mobil Corporation expects to start up 16 major oil and natural gas projects during the
next three years and is on track to increase daily production to 4.3 million oil-equivalent barrels by 2017.
“Our long-term capital allocation approach has not changed,” Tillerson said at the company’s annual
analyst meeting at the New York Stock Exchange. “We remain committed to our investment discipline and
maintaining a reliable and growing dividend. Our integrated model along with our unmatched financial
flexibility enable us to execute our business strategy and create shareholder value through the commodity
price cycle.”
“The lower capital outlook also reflects actions we are taking to improve our set of opportunities
while enhancing specific terms and conditions and optimizing development plans.”
In 2015, ExxonMobil expects to increase production volumes 2 percent to 4.1 million oil-equivalent barrels
per day, driven by 7 percent liquids growth. The volume increase is supported by the ramp up of several
projects completed in 2014 and the expected startup of seven new major developments in 2015, including
Hadrian South in the Gulf of Mexico, expansion of the Kearl project in Canada, Banyu Urip in Indonesia
and deepwater expansion projects at Erha in Nigeria and Kizomba in Angola.
In 2016 and 2017, production ramp up is expected from several projects including Gorgon Jansz in
Australia, Hebron in Eastern Canada and expansions of Upper Zakum in United Arab Emirates and Odoptu
in Far East Russia.
“ExxonMobil has a deep and diverse portfolio of opportunities around the world and a total resource base
of more than 92 billion oil-equivalent barrels,” Tillerson said. “We have unparalleled flexibility to select and
invest in only the most attractive development projects.”
ExxonMobil anticipates capital spending of about $34 billion in 2015 – 12 percent less than in 2014 – as it
continues to bring major projects online. Annual capital and exploration expenditures are expected to
average less than $34 billion in 2016 and 2017.
“ExxonMobil’s Downstream and Chemical businesses remain resilient in the lower commodity price
environment and continue to generate solid cash flow, helped by abundant North American crude and
natural gas supplies that have led to lower feedstock and energy costs,” Tillerson said.
“Approximately 75 percent of ExxonMobil’s refining operations are integrated with chemical and lubricant
manufacturing, resulting in economies of scale and greater flexibility to produce higher-value products,
including diesel, jet fuel, lubes, and chemicals based on market conditions,” Tillerson said.

US:Oil production in federal Gulf of Mexico increasing
Source: U.S. Energy Information Administration
Because of the long timelines associated with Gulf of Mexico (GOM) projects, the recent downturn
in oil prices is expected to have minimal direct impact on GOM crude oil production through 2016.
EIA projects GOM production to reach 1.52 million barrels per day (bbl/d) in 2015 and 1.61 million
bbl/d in 2016, or about 16% and 17% of total U.S. crude oil production in those two years,
respectively.
The forecasted production growth is driven both by new projects and the redevelopment and
expansion of older producing fields. Five deepwater projects began in the last three months of
2014: Stone Energy-operated Cardamom Deep and Cardona projects, Chevron-operated Jack/St.
Malo fields, Murphy Oil-operated Dalmatian, and Hess-operated Tubular Bells. Also occurring at
the end of 2014 was the redevelopment of Mars (Mars B) and Na Kika (Na Kika Phase 3), both of
which are mature fields.
Cardamom Deep, Jack/St. Malo, and Tubular Bells were slated for a late 2014 start-up, as well.
Although industry press releases have indicated they have started producing, their production
data have not yet been reported to the Bureau of Safety and Environmental Enforcement (BSEE)
under the U.S. Department of the Interior.
The relatively high number of fields that came online in 2014 and are scheduled for 2015 and
2016 production start-ups reflects the revival of interest and activity in the GOM following the
moratorium on deepwater drilling after the 2010 Deepwater Horizon incident. While the
moratorium officially lasted from April 30 to October 12, 2010, there were relatively few field start-
ups in 2011 through 2013.

Thirteen fields are expected to start up in the next two years, eight in 2015 and five in 2016.
Development of offshore fields requires both surface and subsea production equipment. The high
cost of surface structures limits their application to large fields.
Those fields with reserves not large enough to justify the necessary capital expenditure use
subsea infrastructure to connect to nearby existing platforms. This approach, known as a subsea
tieback, can reduce project costs and start-up times. More than half of the projects starting up in
2015 and 2016 will be subsea tiebacks to existing production platforms. These new projects,
combined with continuing production from the developments brought online in late 2014, are
forecast to add 265,000 bbl/d by the end of 2015. The production estimates for 2015 and 2016
(see first graph) include adjustments to account for seasonal shut-ins from hurricanes.
The current low oil price
adds uncertainty to the
timelines of deepwater
GOM projects, with projects
in early development
stages exposed to the
greatest risk of delay. In an
effort to reduce this risk,
producers are collaborating
to develop projects more
cost-effectively, to shorten
the time to final investment
decision and first
production, and by sharing
development costs. For
instance, Chevron, BP, and
ConocoPhillips recently
announced a collaborative
effort to explore and
appraise 24 jointly held
offshore leases in the
northwest portion of the
Gulf of Mexico's Keathley Canyon.

Oil Price Drop Special Coverage
Oil Price holds above $60
Reuters + NewBase
Brent crude was holding above the U$D 60 till now,
Brent has traded around $60 since mid-February, rebounding from a six-year low of about $45 hit
in January. The April contract inched down 3 cents to $60.52 a barrel by 0326 GMT while West
Texas Intermediate (WTI) crude edged up 22 cents to $51.75 a barrel.
A 2 percent gain in the previous session narrowed WTI's spread with global benchmark Brent
<CL-LCO1=R> to less than $9 a barrel. "We've got a technically more constructive picture now,"
Michael McCarthy, chief strategist at CMC Markets in Sydney said, pointing to the end of seven
straight months of oil price falls.
"That could be contributing to the surprisingly bullish reaction to the overnight news," he said.
Government data showed commercial crude stockpiles in the United States hit a record high,
rising 10.3 million barrels last week, which was twice as much as expected, but that failed to push
prices down.
Saudi Arabia's oil minister voiced cautious optimism about the market outlook on Wednesday,
saying he expected oil prices to stabilise. A deteriorating security situation led Libya's state oil
company to declare force majeure on 11 of its oilfields on Wednesday.
"It's not a huge difference but supportive of the market overall," McCarthy said. Output from the
Opec producer was at more than 400,000 barrels per day on March 1.

5 Big Geopolitical Risks for 2015
Aon Political Risk Map 2015
The map shows levels of geopolitical risk in developing nations. Yellow indicates medium risk,
orange high, and red very high risk. Developed nations are not rated.
Aon Risk Solutions, a unit of Aon Plc, today issued its annual Political Risk Map, intended to
provide the British insurer's clients with answers to common questions about where it’s getting
safer, and more dangerous, to do business.
There isn't a lot of good news. Just seven of 163 developing countries reduced their political risk
since last year, and most of those, like Zimbabwe and Laos, still have plenty of room for
improvement. Twelve countries face greater strain this year, including Libya, Haiti, and Pakistan.
“The last 12 months have just been catastrophic country-risk-wise,” said Curtis Ingram, vice
president of the political-risk practice. It’s almost like “a vacuum has opened up and a lot of bad
actors have moved in,” in Crimea and Eastern Ukraine, Nigeria, Iraq, and elsewhere.
Aon and research partner Roubini Global Economics, founded by the economist Nouriel
Roubini, evaluate each nation across nine categories of risk, such as foreign currency exchange
and capital conditions, law and regulation, and political interference and violence. The report
considers only developing nations; members of the Organization for Economic Co-Operation and
Development (OECD) together form the baseline for the research and are therefore excluded.
Here are five of the things the report says we should keep an eye on in the months ahead.

Russia
Low oil prices and international sanctions stemming from the Ukraine conflict have taken their toll
on the Russian economy. The murder last week of Boris Nemtsov, an opposition leader and
Yeltsin-era deputy prime minister — not mentioned in the report but a dark omen — has
exacerbated internal political tensions.
Russia’s instability will “continue to cast a shadow over the region,” according to the political risk
report, which projects consequent hardships for trading partners Belarus and Kazakhstan.
Researchers see “a possible frozen conflict and continued sanctions” in Ukraine, unlikely to be
resolved in the months ahead.
Oil and other commodities
Russia, Venezuela and Iran have drawn much of the attention, and punishment, from the oil glut.
It’s also a problem for smaller powers, such as Uzbekistan and Turkmenistan, whose fragile
foreign currency exchange and capital policies leave them vulnerable to trade shocks. Mining- and
energy-heavy nations in Africa — Angola, Cameroon, Congo, and Nigeria — all face weaker
incomes and likely spending cuts.
Conflict and violence
The horrors of Islamic State in Syria and Iraq, and Boko Haram in Nigeria, are top threats to
regional stability. Porous borders and immature civic institutions in parts of the Middle East and
Africa make nations there particularly sensitive to violence.
Interest rates
Even modest interest-rate increases by the Fed will intensify the global competition for capital and
make it costlier to service external debt.
The Middle East and North Africa
Countries such as Egypt, Tunisia, and Morocco should see a boost from the oil price drop, the
report's authors suggest. Yet all three countries, rated either high or very high risks, face
countervailing security risks from what the report calls power vacuums in Iraq, Libya and Syria.
There's also everywhere else. Private insurers have offered political risk coverage for several
decades, to help companies take some of the edge off doing business in new and emerging
markets. But, like most of us, the problems of these places like to travel. Turkey and Mexico, for
example, may be particularly politically or economically vulnerable to tumult in the Middle East and
Latin America. But as OECD members, they pose risks that aren’t addressed in the report.

Oil slump impact ‘limited’ on Qatar financial sector, says central bank
Gulf Times + NewBase
The fall in oil prices has had “limited impact” on Qatar’s financial sector, said HE the Qatar
Central Bank Governor, Sheikh Abdullah bin Saoud al-Thani.
Total assets of the banking system continued to grow robustly at around 5% in
the second half of 2014. The growth has been driven by credit to the private
sector and rise in Islamic finance.
At end-December 2014, the banking system remains well-capitalised and
profitable. In fact, credit quality has improved, with Tier I capital ratio well
above the regulatory minimum required under the Basel III framework and the
NPL ratio falling, while remaining below 2%.
Profitability levels also remain high, with return on assets in excess of 2%, which reflects an
improvement during the second half of the year. “Thus, the banking sector continues to be
resilient and robust despite the fall in global oil prices and associated uncertainties, reflecting
strong macroeconomic performance and sound policies,” he told the Meed.
Although, the performance of the oil companies could have direct impact on the financial sector,
as lower have some revenue may reflect on the extent of leveraging, oil companies have
generated large surpluses in recent years and their dependence on bank borrowings have been low.
Therefore, it is expected that the impact on the assets of the banks will be minimal. Nevertheless,
if the low oil prices are sustained in the long-run, the financial sector could be affected by low
deposit growth and tighter liquidity.
On the other hand, credit growth in the financial sector is now supported by a growing non-
hydrocarbon sector which could well offset the adverse impact expected from the hydrocarbon
sector. In fact, significant progress has been made under the Strategic Plan for the financial sector
to develop a diversified and more resilient economy, which will have lesser reliance on
hydrocarbon revenues.
“Finally, our preparations for the World Cup 2022 and other large infrastructure projects are
expected to sustain the strong growth of the economy which would, in turn, support the health of
the financial sector,” Sheikh Abdullah said.

Asked how the market sustained so many projects without overheating, he said, “Qatar has
maintained strong GDP growth at about 6% over the past two years, driven by double digit growth
in the non-hydrocarbon sector, reflecting the ongoing diversification strategy.
The large public investment spending to diversify the economy and prepare for the FIFA World
Cup 2022, in turn, has resulted in significant inflow of expatriate population. While this has added
to aggregate demand and thereby has supported growth, it has also boosted housing demand and
thereby rental prices.
However, moderation in domestic prices of food amid falling global commodity prices and some
services (medical care and entertainment and recreation) has helped in containing overall inflation
to 2.7% in December 2014.
In addition, the budget continues to post surpluses despite the sharp fall in oil prices and growth is
expected to accelerate in 2015, reflecting solid expansion in non-hydrocarbon activities propelled
by investment spending, expansionary fiscal stance and population growth.
QCB, he said, on its part is actively managing systemic liquidity through auctions of T-bills/bonds
to ensure that monetary and liquidity conditions remain consistent with growth and price stability.
“At the same time, QCB is closely monitoring emerging risks to the financial system, in particular
with respect to inflation and real estate sector risks, and implementing macro-prudential measures
to ensure financial stability.
Mindful of the risks associated with the public investment programme, including related financial
sector vulnerabilities, the Ministry of Finance has taken steps to prioritise public investment while
raising its efficiency. Additional land is being provided to priority sectors such as housing, logistics,
and warehousing to address supply bottlenecks.
“All these steps are expected to sustain growth while maintaining price and financial stability,” the
QCB Governor said.

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Your partner in Energy Services
NewBase energy news is produced daily (Sunday to Thursday) and
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For additional free subscription emails please contact Hawk Energy
Khaled Malallah Al Awadi,
Energy Consultant
MS & BS Mechanical Engineering (HON), USA
Emarat member since 1990
ASME member since 1995
Hawk Energy member 2010
Mobile : +97150-4822502
khdmohd@hawkenergy.net
khdmohd@hotmail.com
Khaled Al Awadi is a UAE National with a total of 25 years of experience in
the Oil & Gas sector. Currently working as Technical Affairs Specialist for
Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy
consultation for the GCC area via Hawk Energy Service as a UAE
operations base , Most of the experience were spent as the Gas Operations
Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility &
gas compressor stations . Through the years , he has developed great
experiences in the designing & constructing 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 for the local
authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE
and Energy program broadcasted 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 05 March 2015 K. Al Awadi

New base 554 special 05 march 2015

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