New base 545 special 22 february 2015

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NewBase 22 February 2015 - Issue No. 545 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Russia Gets Second Junk Rating From Moody’s on Ukraine, Oil
By: Bloomberg- Boris KorbyOlga Tanas
Russia’s credit rating was cut to below investment grade by Moody’s Investors Service, which
joined Standard & Poor’s in ranking the country’s debt as junk, citing the conflict in Ukraine and
plunging oil prices.
The rating company
downgraded Russia one
step to Ba1, the highest
non-investment level and
in line with countries
including Hungary and
Portugal. Moody’s has a
negative rating outlook
on the country, according
to a report released
Friday. Standard & Poor’s
decision cut the country
to speculative grade in
January.
“The existing and
potential future
international sanctions,
the erosion of the country’s foreign exchange buffers and persistently lower oil prices plus high
and rising inflation will take a negative toll on incomes as well as business and consumer
confidence,” Moody’s said in the report. “While the fall in the oil price and the exchange rate have
reversed somewhat since the start of the year, the impact on inflation, confidence and growth is
likely to be sustained.”
The world’s biggest energy exporter is on the brink of
a recession after crude fell to the lowest since 2009
and the U.S. and its allies imposed sanctions
following President Vladimir Putin’s annexation of
Crimea from Ukraine in March. The penalties have
locked Russian corporate borrowers out of
international debt markets and curbed investor
appetite for the ruble, stocks and bonds.
‘Forced Selling’
Downgrades to junk from at least two rating

companies may force money managers whose investment guidelines prohibit them from holding
debt rated below investment grade to sell as much as $5.8 billion of Russian dollar and local
bonds, according to a January report from JPMorgan Chase & Co.
“Most bond funds, which have rules against investing in non-investment-grade securities, will have
to sell bonds regardless of whether they want to do that or not”, Slava Smolyaninov, a strategist at
UralSib Capital in Moscow, said by phone Saturday. “Investors will re-evaluate Russia and regard
it as more risky. As a result, risk premiums will be higher.”
Non-residents held 877 billion rubles ($14.1 billion) of Russia’s local-currency bonds known as
OFZs as of Dec. 1, or 24.2 percent of the total, according to the latest figures available from the
central bank. That’s down from a peak of 28.1 percent on May 1, 2013, though up from just 3.7
percent at the start of 2012.
‘Beyond Reason’
The decision by Moody’s ignores information provided by Russia’s finance ministry about the
economy as well as the country’s fiscal and financial policies, Finance Minister Anton Siluanov
said in an e-mailed statement after the report.
“The decision by Moody’s isn’t just negative beyond all reason, but it’s based on an extremely
pessimistic outlook,” Siluanov said. “The agency was guided primarily by political factors when
deciding to cut the rating.”
Moody’s estimates capital outflow from Russia will reach $400 billion in 2015-2016, while the
economy will shrink 8.5 percent during that period, Siluanov said. The figures weren’t included in
the rating company’s statement.
Russia’s Economy Ministry predicts gross domestic product will contract 3 percent with capital
outflow at $115 billion this year, according to its forecast submitted to the government this month.
GDP fell 1.5 percent in January from a year earlier, according to the ministry’s preliminary
estimates.

Standard & Poor’s confirms Abu Dhabi’s credit rating at AA
The National + NewBase
The Standard & Poor’s credit rating agency has reaffirmed Abu Dhabi’s rating, saying the emirate
was in a good financial position to weather lower oil prices despite its relatively undiversified
economy.
The long-term sovereign debt
rating was affirmed at AA, with
short-term debt getting the top
A1+ rating, as S&P said the
outlook for the emirate
remained stable.
The assessment reaffirmed the
preliminary rating issued this
month when S&P reviewed the
whole Arabian Gulf region in
light of the sharp fall in oil
prices in recent months.
The full report by the agency concluded: “The ratings on Abu Dhabi are supported by its strong
fiscal and external positions, which afford it fiscal policy flexibility,” adding “the exceptional
strength of its net asset positions also provides a buffer to counter the negative effect of oil price
swings on economic growth and government revenue, as well as on the external account”.
One of the constraints on Abu Dhabi’s economy is a lack of economic diversity, where the GDP (a
broad measure of economic activity) is 55 per cent dependent on oil, and 90 per cent of
government revenue is derived from the hydrocarbons sector.
Also, a lack of development of its government institutions, lack of flexibility in monetary policy (with
the dirham pegged to the US dollar), and an underdeveloped local bond market were cited by
S&P as keeping the emirate from getting the highest long-term sovereign debt rating.
S&P also said its rating view was limited by a lack of transparency in Abu Dhabi’s finances and
data about the economy.
The agency said that for this reason it would be changing its assumption about transfers to the
government from the Abu Dhabi Investment Authority, the main sovereign wealth fund, and would
be revising down its estimate of the government surplus from 10 per cent to 6 per cent of GDP for
the 2010 to 2014 period.
Including dividends from the state oil company Adnoc, S&P said it now forecasts the government
surplus will average about 2 per cent in the three years to 2018.
The government’s overall current spending, along with aid payments and federal contribution, will
decline, but development spending will double this year to 10 per cent of total spending to support
economic growth, S&P forecasts.
The agency based its outlook on an assumed average Brent oil price of $55 per barrel this year
and $70 in the three years to 2018.

Iraq to boost southern oil storage to 15m barrels
Reuters + NewBase
Iraq plans to increase its southern oil storage capacity to 15 million barrels by the end of
2015, to help cope with export bottlenecks caused by bad weather and to absorb rising
production, a senior official said.
Speaking at the opening of three new oil storage tanks near the southern city of Basra, deputy oil
minister Fayadh Al-Nema said the new facility will add more than one million barrels of capacity to
the existing 9.5 million.
"Today we have managed to add more than one million barrels and boost oil storage capacity up
to 10.5 million barrels. Another four to five million barrels capacity will be added by the end of this
year," Fayadh Al-Nema told reporters.
Nema said the storage capacity increase will help Iraq to absorb expected rising oil production
from the southern oilfields and also avoid export halts during rough weather. "Production is rising
steadily from the southern oilfields and we need more infrastructure to deal with extra crude
volumes," Nema said.
Export infrastructure, rather than production, is the main hurdle to the Opec member keeping
exports steady. The southern oilfields produce the bulk of Iraq's oil and the terminals are its main
outlet to world markets.
Iraq's oil exports fell to 2.535 million barrels per day (bpd) in January from a high of 2.94 million
bpd in December due to rough weather.
The Al Basrah Oil Terminal stretches over half a mile from the south platform to the north platform.
The terminal, 30 miles off the Iraqi coast in the Persian Gulf, can host four tankers at a time and
pumps more than 1.5 million barrels a day.

Qatar Consortium wins Doha Metro deal
The Peninsula + NewBase
A five-member consortium consisting of Mitsubishi Heavy Industries, Mitsubishi Corporation,
Hitachi Ltd, The Kinki Sharyo Co and Thales received a Letter of Conditional Acceptance from the
Qatar Railways Company (Qatar Rail) for a systems package for the Doha Metro, on Friday.
The newly accepted package calls for turnkey construction of a fully automated driverless metro
system. Included are 75 sets of three-car trains, platform screen doors, tracks, a railway yard, and
systems for signalling, power distribution, telecommunications and tunnel ventilation. The package
is also expected to include maximum 20-year maintenance services for the metro system after its
completion, Mitsubishi Heavy Industries, the leader of the consortium, announced in Japan.

Mitsubishi Heavy Industries will supply the power distribution system, platform screen doors,
tracks and tunnel ventilation work, and will also undertake overall project management and
system integration.
Mitsubishi Corporation and Kinki Sharyo will jointly provide the railway cars. Thales will supply the
advanced Communications Based Train Control (CBTC) signalling, telecommunications and
security, integrated operational control centre and automatic fare collection systems. Hitachi will
perform some project management duties and also handle facilities maintenance, including the
supply of special maintenance vehicles that comprehensively inspect the safety of infrastructure
such as railway tracks and electric train lines.
“The Doha Metro ongoing works are being done according to our timeline that we set at the
beginning of the project,” Mitsubishi Heavy Industries’ Japanese corporate website quoted Qatar
Rail’s CEO Saad Ahmed Al Muhannadi as saying.
“In 2013 and 2014, we signed many agreements that reached a remarkable value promising to
deliver the best standards of metro railway in the near future. Today, with the five-member Japan
consortium led by Mitsubishi Heavy Industries, we look forward to add more value to our project
knowing the international expertise of the Japanese fellows and provide Doha with a fully secure
and automated driverless metro system.”
The Doha Metro will run through the city of Doha and will consist of four lines in two phases —
Red, Green, Gold and Blue — covering a total distance of 241km with 106 stations, of which
123km will be constructed underground. The new metro system will connect the main areas of
Doha, including the Hamad International Airport, the Old City, and newly developing inner city
areas such as West Bay and Lusail. Phase 1 of the network will be launched in 2019.
After submitting its bid in March 2014, the consortium underwent 11 months of detailed
negotiations. The Letter of Conditional acceptance was received after convincingly demonstrating
to the client the consortium’s high technical capabilities and robust track record in the construction
of metro systems, the consortium leader said.

Algeria: Gazprom confirms productivity of hydrocarbon deposits for El Assel area
Gazprom on Thursday hosted a working meeting with Sonatrach. The parties looked at the
current status of and the outlook for the cooperation in the gas sector, among other things,
as part of the joint development of hydrocarbon fields in Algeria.
It was highlighted that starting from 2010, a great scope of 2D and 3D seismic survey operations
had been conducted and six exploratory wells had been drilled as part of the project for
exploration and development of the El Assel oil- and gas-bearing area in Algeria. The well survey
has proven the availability of hydrocarbons pay zones.
At present, the delineation of deposits is underway at the field. The meeting also considered joint
actions within new oil and gas projects, while giving particular attention to potential LNG supplies.
Background
Algeria's Sonatrach is the largest oil and gas company in Africa. It is engaged in exploration,
transportation and marketing of oil and natural gas as well as controls most of gas production
and wholesale trade.
The El Assel licensed area is located in the Berkine Basin, 500 kms south of Algeria's capital city
Algiers and 150 kms away from the oil production center – town of Hassi
Messaoud.Gazprom is implementing the El Assel project in partnership with Algeria's Sonatrach
with the following shareholding structure: 49 and 51 per cent respectively. Gazprom
EP International (Company's wholly-owned subsidiary) is the project's operator.

US: ExxonMobil filed Alaska LNG Project resources reports
$45 billion Alaska LNG FERC approval in progress
The major companies ExxonMobil from USA, BP from UK, Conoco Phillips from USA and
the midstream specialist TranCanada submitted the first drafts of so called Resources Reports as
part of the environmental and project designed reports to be filed in for the Federal Energy
Regulatory Commission (FERC) approval required for their giant Alaska liquefied natural gas
(LNG) export project from USA.
In a context where most of the international oil companies (IOCs), and especially BP and
Conoco Phillips, are assessing the profitability of their projects, the initiative of the Alaska
LNG project sponsors to go ahead in filing in these Resources Reports first drafts reflect their
confidence in the sustainability of the natural gas market in the long term.
This decision shows how
much such giant project is first
driven by geo-strategic
parameters before daily oil
and gas prices. As many
other LNG export projects
in USA, the main targeted
market is Asia and especially
northeast Asia.
So far these US-based
projects were in competition
to supply Asia markets
with Australia, East Africa and
Russia with some critical
concentration for the renewal
of long term supply
agreement
Around 2018 and 2019.
In this perspective all these
countries were racing to ramp
up multi-billion US dollars
projects to be able to deliver on time. After the hard experiences made in Australia on current
projects, this continent-country put itself off-track of the competition for the time being.
East African countries such as Mozambique and Tanzania are struggling with local content
regulations and political issues to share revenues that have not collected yet, thus delaying all
projects developments in this very promising region.
Russia is stocked by its foreign policy and consecutive financial sanctions with ExxonMobil
and BP being among the first foreign companies to suffer from this situation. Even if a major
agreement was signed between Gazprom and Sinopec to return pipelines to east and supply
China with Russian gas, this giant project will also take time and will never be sufficient to
meet Asia demand opening doors to ExxonMobil, BP, ConocoPhillips and TranCanada to step in
with their Alaska LNG project.

ExxonMobil increases Alaska LNG project capacity , herefore the last twelve months have in fact
removed some of the major rock blocks for ExxonMobil, BP, Conoco Phillips and TranCanada on
their road to develop their Alaska LNG project.
Estimated to require between $45 and $65 billion capital expenditure, this amount may look
provocative in the actual context of restrictions, but if we compare the Alaska LNG project
investment with the sum of the LNG projects capital expenditure which have been frozen or
postponed for the reasons mentioned above, it appears very reasonable in addition with a
minimum of risks.
To be supplied from the Alaska North Slope gas fields operated by ExxonMobil, BP and
Conoco Phillips, the Alaska LNG project includes a 1200 kilometers pipeline to transport
the natural gas to the selected site of Nikiski in the Cook inlet, 100 kilometers southwest of
Anchorage.
With a capacity of 3.5 billion cubic feet per day (cf/d) of gas, this pipeline will supply the Nikiski
LNG plant with a capacity of2.5 billion cf/d considering the gas to be consumed in the
transportation and liquefaction process. At the current pre-front end engineering and design (pre-
FEED) stage, the Alaska LNG plant capacity has been revised upward from the original 15 million
tonne per year (t/y) to 20 million t/y. With a pre-FEED to be completed by 2016,
ExxonMobil, BP, ConocoPhillips and TranCanada are targeting the ship the first gas from
Alaska LNG project to Asia by 2021.

US oil workers’ union expands biggest plant strike since 1980
Bloomberg + NewBase
The United Steelworkers, which represents 30,000 US oil workers, called on four more plants to
join the biggest strike since 1980 as talks with Royal Dutch Shell, negotiating a labour contract for
oil companies, dragged on.
The USW, with members at more than 200 refineries, fuel terminals, pipelines and chemical plants
across the US, asked workers at Motiva Enterprises’ plants in Texas and Louisiana to join a
nationwide walkout. The work stoppage began on February 1 with workers leaving nine plants
from California to Texas, and expanded to two BP refineries in the Midwest a week later. The
union has rejected seven contract offers from Shell, which is representing companies including
Exxon Mobil Corp and Chevron Corp.
An agreement would end a strike at US plants that account for almost 20% of the country’s
refining capacity. It’s the first national walkout of US oil workers since 1980, when a work
stoppage lasted three months. The USW represents workers at plants that together account for
64% of US fuel output.
“The industry’s refusal to meaningfully address safety issues through good faith bargaining gave
us no other option but to expand our work stoppage,” said USW International President Leo W
Gerard in a statement.
The USW has been asking for tougher measures to prevent fatigue and to keep union workers
rather than contract employees on the job, statements posted on the group’s website show. The
union said on Thursday that Shell’s seventh offer failed to address safety concerns “in any sort of
meaningful or enforceable way” and instructed members to prepare to join the strike “if called
upon.”
The union previously called strikes at: Tesoro Corp’s plants in Martinez and Carson, California,
and Anacortes, Washington; Marathon Petroleum Corp’s Catlettsburg complex in Kentucky and
Galveston Bay site in Texas; Shell’s Deer Park complex; LyondellBasell Industries NV’s Houston
facility; and BP’s Whiting and Toledo refineries in the Midwest.
Tesoro said earlier this month that its plants could run for a “very long period” during the walkout.
The San Antonio- based refiner, which owns the most capacity in the western US, halted all fuel
production at its Northern California refinery after workers walked out. United Steelworkers
members operate refinery units, perform maintenance and work in labs at the plants.
The USW and Shell began negotiations on January 21 amid the biggest collapse in oil prices
since 2008, driven largely by surging output from US shale formations that cut oil prices by 49% in
the second half of 2014.

Oil Price Drop Special Coverage
Oil Falls Sharply After US Crude Inventories Rise
Brent crude oil prices slipped below $59 a barrel on Thursday after another big weekly build
in U.S. crude inventories and a possible rise in Saudi output stoked worries about oversupply.
U.S. crude stocks rose by 14.3 million barrels last week, data from industry group the
American Petroleum Institute (API) showed after Wednesday’s settlement, compared with
analysts’ expectations for an increase of 3.2 million barrels.
If U.S. Energy Information Administration (EIA) data due at 1600 GMT confirms the large
build, it would be the biggest weekly addition in barrels since such data became available in
1982. The API and EIA reports are a day late this week because of a U.S. holiday on
Monday.
At 1112 GMT, benchmark Brent crude futures for April were down $1.52 at $59.01 a barrel,
after touching an intraday low of $58.46 earlier in the session, extending declines from
Tuesday’s two-month high of $63.
U.S. crude for March delivery, which expires on Friday, was down $2.10 at $50.04 a barrel
after dipping as low as $49.73. Trading was quiet in Asian hours as markets in China and
other nations were closed for the Lunar New Year holidays.

“The inventories were the trigger for the sharp correction lower,” Carsten Fritsch, an oil
analyst at Commerzbank in Frankfurt, said. “The focus is again back on the oversupply – the
big question is for how long?”
The market has tended to retreat after swelling U.S. crude inventories, but then rally after
falling U.S. rig-count numbers, which come out every Friday. “A big build of seven to nine
million barrels would be enough to push prices lower,” Fritsch said, looking ahead to the EIA
data. “But tomorrow we could see a recovery in expectation of another sharp drop in the rig
count.”
At the same time, production from the world’s biggest exporter Saudi Arabia may be
increasing to near 10 million barrels per day, consultancy PIRA said on Wednesday. The
estimate suggests the country is cleaving to the strategy of protecting market share rather
than cutting production to boost prices.
Another Big Reason to Think Oil Prices Aren't Going Up Soon
Bloomberg
Oil just had its first weekly decline in a month, breaking a rally in crude prices. A bit of context:
After what's happened over the last year, "rally" seems a bit of an overstatement.
Oil 'Rally'
One big factor that may be driving prices down this week: The U.S. is pumping so much oil
it's running out of places to stash it.
Crude oil in storage in the U.S. has jumped to the highest levels in at least 80 years, according to
a Bloomberg Industries analysis. The EIA this week reported that U.S. inventories rose 7.7 million
barrels to 425.6 million. That's more than 20 percent higher than the five-year average.

U.S. Oil Inventories Reach 80-Year High
The buildup of supply has been "colossal" and is responsible for oil prices falling this week,
Thomas Finlon, director of Energy Analytics Group LLC, told Bloomberg News.
Winter weather and refinery outages have contributed to the supply glut. Even when those
conditions subside, topped-out inventories and continued production growth may continue to
suppress oil prices for the near- and medium-term, according to Bloomberg Industries.
Meanwhile, the U.S. is pumping oil at a faster pace than any time since 1972.
U.S. oil production since 1983. Source: EIA

Lebanese gains and losses from lower oil prices
The Dailly Star +NewBase
The fall of crude oil prices by 50 percent since June is seen to largely benefit oil-importing
economies and to challenge oil exporters. In the case of Lebanon, an energy importer and
aspiring energy exporter, there are mixed effects on its broader economy, and vital lessons
as it works to launch its oil and gas industry.
On the economic front, the World Bank highlighted in a recent report the primary benefit of the oil
price drop to come from a lower fuel bill for the national electricity company, Electricité du Liban.
This is significant given that in the past four years exceptionally high oil prices have cost the
Lebanese government, on average, an astounding 4.7 percent of GDP to maintain electricity
prices constant, by covering any price difference above $23 per barrel.
Another positive impact is the fall of 20 liters of gasoline from LL39,000 to LL22,000, benefiting
consumers. If low prices are sustained, the effects can eventually create an economic boost by
increasing the spending power of cash-strapped consumers. However, some economists are
advocating slightly raising gasoline taxes to help reduce the budget deficit and finance higher
wages for civil servants.

On the negative side, the flow of remittances from Lebanese emigrants could be at risk. In 2014,
Lebanese expatriates sent a significant $7.7 billion to support families back home – which
constitutes more than 16 percent of Lebanon’s GDP. As 60 percent of these financial flows come
from Gulf countries, they could be at risk due to lower oil price leading to project delays, budget
cuts and may ultimately impact the employment and income of Lebanese working in the Gulf
Cooperation Council states.
This has caused Central Bank Governor Riad Salameh to find falling oil prices the biggest
economic challenge facing the country in 2015.
Other sectors are also likely to be impacted, including energy-intensive industries such as
Lebanese manufacturers. Lower fuel bills can decrease their production costs, enhancing their
competitiveness.
On the political front, the flow of political funding from neighboring countries could possibly decline
and influence domestic politics as well as regional conflicts in Syria and Iraq.
When it comes to Lebanon’s embryonic oil and gas sector, the sharp energy price drop offers a
significant cautionary tale as the country prepares to launch its first licensing round.
As Lebanese witness the extreme volatility of energy markets, this serves as a reminder of the
painful repercussions on the economies and citizens of countries highly reliant on commodity
exports. This is why proper planning will be crucial early on. For example, a stabilization fund must
be set up to cushion the economy. Countries with poor planning such as Venezuela and Yemen,
for example, are expected to face deficits of 17 and 9.5 percent of GDP respectively and will have
to borrow internationally to maintain their current spending.
This can also be an opportunity to persuade the Lebanese to diversify the economy away from the
oil sector. Future oil revenues will have to be invested to develop other industries, and saved for
future generations.
The new reality of cheaper oil also has unclear effects on investments in new oil exploration and
development. Several dynamics could pose serious risks for Lebanon as it works to launch its first
licensing round. It can however be turned into an opportunity if decision-makers devise a
thoughtful strategy to attract investors.
Energy companies are widely reported to be tightening their budgets and have a reduced appetite
to explore new basins. A striking Goldman Sachs analysis found that almost $1 trillion in future oil
project investments across the world will no longer be economically viable with Brent crude at $70.
Countries, such as Lebanon, seeking to attract new investments must now compete more
seriously with other countries that could slash royalties and taxes to maintain the interest of
companies.
On the flip side, the situation today might be an opportunity to start new exploration projects.
Some analysts anticipate that energy prices will rebound in the long run and believe that now is
the right time to advance offshore exploration – which would start production in five to eight years,
making the most out of future oil price booms. Such projects could be economically viable given
the decline in drilling equipment costs which make up to 40 percent of the total cost of offshore
projects.
These are timely insights as the Cabinet reviews decrees outlining how best to attract international
oil companies while maximizing Lebanon’s share of profits, and the best timing to launch the
licensing round.

Oman Oil, Orpic key global oil and gas event
The first international downstream exhibition and conference, Oman Refining and Petrochemicals
Exhibition and Conference (ORPEC), organised by Omanexpo and global organisation World
Refining Association, is set from March 16 to 18 at the Oman International Exhibition Centre.
The event is spearheaded by Oman Oil Company (OOC) and Oman Oil Refineries and Petroleum
Industries Company (Orpic), the biggest entities in the Middle East's refining and petrochemical
sector.
The oil and gas industry in Oman has always been the key driver of the country's economy. While
exploration and enhanced oil recovery (EOR) activities continue to take centre stage, the
government is placing equal attention on the refining and processing of petrochemicals and crude
oil and distribution of its by-products, creating investment and employment opportunities for
downstream industries, and boosting downstream facilities. It has also invested in multi-million
projects such as the Duqm Refinery, Muscat-Sohar Pipeline Project and Liwa Plastics Project.
Government-owned Oman Oil Company, the national flagship company, plays a significant role in
seeking areas of investment within Oman and outside of Oman, the development of oil and gas-
based industries and other energy and energy-related projects in cooperation with global industry
players.
Speakership roles will be taken by Orpic's Henk Pauw, general manager, Liwa Plastics Project,
who will provide insight on the $3-billion project; Nofal Al Saidi, general manager, Human
Resource Services, will speak about talent development in the downstream workforce; logistics
general manager Andres Suarez will share an overview of the $200-million Muscat-Sohar Pipeline
Project (MSPP), showcasing Oman's potential to become a logistics hub

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
sponsored by Hawk Energy Service – Dubai, UAE.
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 22 February 2015 K. Al Awadi

New base 545 special 22 february 2015

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