New base 588 special 22 April 2015

Copyright © 2015 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced, redistributed,
or otherwise copied without the written permission of the authors. This includes internal distribution. All reasonable endeavours have been used to ensure the accuracy of the information contained in this
publication. However, no warranty is given to the accuracy of its content. Page 1
NewBase 22 April 2015 - Issue No. 588 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
UAE: ADNOC To Invest Over $25bn In Offshore Oilfields
Reuters + NewBase
Abu Dhabi ( ADNOC) plans to invest over $25 billion in the next five years on boosting its oil
production capacity from offshore fields, a senior official of Abu Dhabi National Oil Co said on
Tuesday. The
plan is part of the
United Arab
Emirates’ strategy
of increasing its
crude oil output
potential to 3.5
million barrels per
day by 2017-18.
The UAE’s actual
current production
is around 2.8
million bpd.
“We want to build
capacity from production and from number of wells and infrastructure. Our current plan as
ADNOC (is to reach) 3.5 million bpd and to sustain it,” Qasem al-Kayoumi, manager of
ADNOC’s offshore division of the exploration and production directorate, told reporters.
Speaking at the Middle East Petroleum and Gas conference in Abu Dhabi, he also said the
investment plan for offshore drilling activities was $2.5 billion per year.
ADNOC plans to drill around 160 wells per year in the next couple of years, Kayoumi said. “It
is a considerable increase – the number of rigs has built up considerably in offshore, it could
be more than a 50 percent increase.”
He also said current production for the ADMA-OPCO and ZADCO oil fields was 1.2 million
bpd and “in 2017-18 that figure will go close to, I would say around 1.6 million bpd.”
One of the main UAE fields being developed by Exxon is the giant Upper Zakum, for which
the plan is to boost production capacity to 750,000 bpd by 2017-18; this may be raised further
to 1 million bpd by 2024.
Kayoumi said ADMA-OPCO was in an early phase of preparing for the renewal of its offshore
concession, due to expire in 2018. “We hope that this concession will be renewed with our
(existing) partners and future partners.”

UAE: GASCO enters into a LSTK Agreement with Spanish
Tecnicas Reunidas valued AED 2.51 Billion
( WAM + NewBase) On behalf of Abu Dhabi National Oil Company, ADNOC, Abu Dhabi Gas
Industries, GASCO, have signed a lump sum turnkey, LSTK, agreement for the Engineering,
Procurement, Construction and Commissioning of the Integrated Gas Development Expansion
Project – Phase One, for the Onshore Pipeline and Habshan Modifications, Package 3.
The agreement was signed by GASCO CEO, Abdul Aziz Abdulla Al Ameri, and Arthur Crossley,
CEO Upstream of Tecnicas Reunidas, in the presence of Dr. Saif Sultan Al Nasseri, ADNOC Gas
Processing Director and a number of senior official from both sides, on Monday April 20th, at the
GASCO HQ Offices in the Sheikh Khalifa Energy Complex.
The project aims to process additional onshore and offshore gases to produce 650 MMSCFD of
natural gas to the existing GASCO Network by the middle of 2018.
IGD-E (Package-3) consists of the following new facilities that will be required to handle the
additional offshore Gas; New 42" pipeline with a length of 114 km from Ras Al Qila to Habshan 5
Plant, and New Units required at
Habshan 5 to receive the Gas
from the new 42" IGD-E pipeline.
The new Habshan 5 units will
also be the destination of
additional onshore sour gas from
ADCO’s North East Bab
Development, NEB-III. The EPC
Contract was awarded in
February 2015 to Tecnicas
Reunidas, Spain with a
completion period of 40 months
from the date of the award.
The initial phase of the project

execution, consisting of detailed engineering and procurement, will commence from the
contractors home office in Madrid, Spain, and will later on move to the sites of the onshore
pipelines and Habshan for construction activities.
GASCO will direct its EPC Contractor to maximise the local contents in terms of materials,
equipment and services in these projects.
During the already completed Front End Engineering Design (FEED), GASCO included the
highest quality standards and placed particular emphasis on all aspects of health, safety and
environment (HSE) to minimise environmental and community impacts and ensure compliance
with ADNOC’s HSE Code of Practices.
These projects will also provide excellent opportunities to UAE nationals for training and learning
through exposure and interaction with these experienced engineering companies to enable them
to manage future projects, and operate and maintain the plants after project completion and
handover.
GASCO is executing the construction of the Integrated Gas Development Expansion Project –
Phase One (Package-3) on behalf of ADNOC.

UAE: Dewa to open tender to build coal-fired power plant
GulfNews + NewBase
Dubai Electricity and Water Authority (Dewa) will open a tender in two weeks to build a coal-fired
plant with a capacity of 1200 Megawatts (MW), Saeed Al Tayer, MD and CEO of Dewa said.
The Hassyan coal-fired power plant is expected to operate on two phases, which are due in 2020
and 2021, he said during Water, Electricity, Energy, Technology and Environment Exhibition
(Wetex),
By 2030 the share of
power generation
from coal-fired will
reach 7 per cent of
energy production, Al
Tayer said.
Dewa also signed a
contract with Siemens
for the construction of
the Jebel Ali M-Station
expansion. The contract
was originally awarded
in February.
The project is worth
Dh1.47 billion ($400
million) and will be
completed by end of
April 2018. DEWA
previously appointed
Mott McDonald as
the project consultant. The new combined-cycle power plant will add a further 700 megawatts
(MW) to the installed generating capacity of M-Station at Jebel Ali, boosting its capacity to
2,760MW when the project is completed in 2018.
The expansion project includes adding two gas turbine generators, two heat recovery steam
turbine generators, and one back-pressure steam turbine. This will increase the plant’s thermal
efficiency from 82.4 per cent to 85.8 per cent, which is considered to be one of the highest
thermal-efficiency rates in the world, he said
M-Station, built at a cost of Dh10 billion, is the newest and largest power production and
desalination plant in the UAE, with a total capacity of 2,060MW of electricity and 140 million
imperial gallons of water per day. The station adopts the highest levels of availability, reliability,
and efficiency, using the most advanced technologies in the world.
Jebel Ali Power Station includes M-Station, which is one of the main pillars that enable DEWA to
provide Dubai with a very reliable, efficient and high quality electricity and water supply.
DEWA works tirelessly to enhance its installed capacity, which is currently 9,656MW of electricity
and 470 million imperial gallons of desalinated water per day. After completing this station,
DEWA’s installed capacity will reach 10,356MW of electricity.

UAE: SolarImpulse2 reached its 6 destination- NANJING (CHINA)
http://www.solarimpulse.com/leg-6-from-Chongqing-to-Nanjing
Solar Impulse took off for its sixth flight from Chongqing to Nanjing, China, on Monday April 20th
at 22:06 UTC (local time: 06:06 on next day) and landed on Tuesday April 21st at 15:28 UTC.
Bertrand Piccard flew the zero-fuel airplane on 1344km (725.7 NM) for 17 hours and 22 minutes.
Leading global provider of elevators, escalators and related services, Schindler established
China’s first industrial joint venture in 1980 and began operating as a Wholly Owned Foreign
Enterprise (WOFE) in 2006. Schindler is pleased to accompany Solar Impulse in China,
presenting the latest clean and green technology to the public, as well as Chinese developers,
architects, urban designers and planners.
The project is aiming to circumnavigate the globe, and it must now prepare for the challenge of
crossing the Pacific. The next 10 days will be spent giving Solar Impulse a thorough servicing.
Meteorologists on the Swiss team, which has its mission control in Monaco, will then look for a
suitable weather window for the ocean flight.
It will be done in two stages, with the first reaching over to Hawaii - a distance from Nanjing of
8,000km. For the slow-moving aircraft, this will entail being airborne continuously for several days
and nights.
In simulations done last year, the weather
opening was found quite quickly, but the team
recognises also that its stay in Nanjing could
be a long one. "I think 10 days is the time we
need to get ready. Then we need to wait for a
good weather window," explained mission
director Raymond Clerc.
"That could be three days; we could have to
wait three weeks - because this leg is really
the most important and is very complex. To go
towards Hawaii could last five days and five nights."
Bertrand Piccard has been sharing the flying duties in the single-seater with his business partner,
Andre Borschberg. And it is Borschberg, the trained engineer, who will take the controls for the leg
to Hawaii.

Morocco: Chariot Oil & Gas provides update on Moroccan
Source: Chariot Oil & Gas
AIM-listed Chariot Oil & Gas, the Atlantic margins focused oil and gas exploration company, has
provided an update on itsRabat Deep, Loukos and Mohammedia permits, offshore Morocco.
Rabat Deep (Chariot (50% Operator), Woodside (25%), the Office National des
Hydrocarbures et des Mines ("ONHYM") (25% carried)):
• Woodside has not exercised its option to take operatorship and fund well costs for a
further 25% equity stake; it will remain a partner on the licence with a 25% working interest
• Drilling is now anticipated to be in 2016/2017, subject to securing an additional partner
Loukos and Mohammedia (Chariot (75% Operator), ONHYM (25% carried)):
• Material potential oil prospects identified in both the proven Jurassic and Neogene plays
• Dataroom to open following completion of 3D interpretation
Chariot's Rabat Deep, Loukos and Mohammedia permits, offshore Morocco
Rabat Deep
Chariot announces that its partner in the Rabat Deep Offshore permit, Woodside, has not
elected to take operatorship and fund the drilling of an exploration well in return for an additional
25% equity stake. As a result, Chariot will remain operator with a 50% equity interest, with
Woodside retaining a 25% equity interest and ONHYM a 25% carried interest.

As part of its two-tier partnering process, Chariot is currently at near zero cost in its Moroccan
acreage and will seek an additional partner to participate in drilling on the Rabat Deep permits.
As previously announced JP-1 is the focus prospect and contains 618mmbbls of gross mean
prospective resources as estimated by Netherland Sewell and Associates on the 2D seismic
data. This prospect remains technically robust on the 3D seismic and a Competent Person
Report will be undertaken following the interpretation of the recently received pre-stack depth
migrated data.
Whilst market conditions are challenging, the large scale of the prospects in Chariot's portfolio
means that drilling success would create transformational value even at current oil prices. A
dataroom for Rabat Deep will open in due course and, subject to securing a partner, drilling of
this prospect is now anticipated to occur in late 2016/2017.
Loukos and Mohammedia
The interpretation of the pre-stack time migrated 3D data acquired in the 2014 seismic campaign
has also generated several material prospects within the Loukos and Mohammedia licences,
including the JP-2 prospect in the Jurassic play. Recent work has also identified further oil-prone
prospectivity within the Neogene.
In line with Chariot's focus on risk management, partners will be sought for these licences to
either participate in the drilling of the prospects already located, or to further the 3D seismic
campaign across the permits.
A dataroom will be opened once the Chariot team is satisfied that it has a full description of the
prospectivity within the licences to maximise the understanding of the value proposition for
potential farminees.
An independent audit of the prospective resources associated with the 1,700km2 3D seismic
campaign on these permits will also be carried out once Chariot has completed its internal
evaluation of the pre-stack depth migrated data.

Oman: Take gas flaring issue seriously, Ministry tells companies
Oman Times + NewBase
The Ministry of Oil and Gas says the country has made progress in reducing the amount of the
natural gas that is flared as a by-product of operations but acknowledges that there are certain
challenges which have been hampering these efforts.
"Gas flaring has reduced because we are mandating the companies to take gas flaring very
seriously and reduce it as much as possible by proposing different solutions," Salim bin Nasser
Al Aufi, Undersecretary at the Ministry of Oil and Gas, told Times of Oman.
He was speaking on the sidelines of the first Middle East Oilfield Produced Water Management
Conference, which opened at Golden Tulip Seeb Hotel on Monday and concludes on
Wednesday.
Al Aufi said that conversion into LNG or compressing the gas and using it again for power
generation are some of the options to utilise the wastefully burned gas for beneficial use.
"However, it has a higher cost. The cost is always a challenge with reducing gas flaring," the
official added.
Top 20 flaring states
According to the satellite data on global flaring, Oman is among the top 20 countries with the
highest volume of flared gas for the period 2007 to 2011.
The report prepared by the National Oceanic and Atmospheric Administration (NOOA) in
cooperation with the World Bank-led Global Gas Flaring Reduction Partnership, places the
Sultanate in the 19th position, with an estimated flared volume of 1.6 billion cubic metres (bcm) in

2011, down from 2 bcm in 2007. Russia, Nigeria, Iran, Iraq and the United States topped the list.
Saudi Arabia and Qatar are also among the 20 countries with the highest volume of flared gas
based on the satellite data.
Initiatives
Oman's Ministry of Oil and Gas has taken several initiatives to reduce gas flaring in the face of
ever-increasing energy demand, and its efforts are supported by several companies, including the
state-owned Oman Oil Refineries and Petroleum Industries Company (Orpic), which recently
announced investment plans for a flare gas recovery system at its refinery in Sohar.
Global commitment
As Oman is seeking to contribute to global flaring reduction efforts, chief executives from major oil
companies and senior government officials from several oil-producing countries met at the
headquarters of the World Bank in Washington on April 17 to launch the 'Zero Routine Flaring by
2030' initiative.
The initiative, which has already been endorsed by nine countries, 10 oil companies and six
development institutions, was launched by United Nations Secretary General Ban Ki-moon and
World Bank Group President Jim Yong Kim.
The governments which have endorsed the initiative to end the practice of routine gas flaring at oil
production sites by 2030 include Norway, Cameroon, Russia, Kazakhstan, Gabon, Uzbekistan,
Republic of Congo, Angola and France. According to the World Bank, endorsers collectively
represent more than 40 percent of global gas flaring.
140 bcm every year
It says that every year, around 140 bcm of natural gas produced together with oil is flared at
thousands of oil fields around the world. "This results in more than 300 million tons of CO2 being
emitted to the atmosphere - equivalent to emissions from approximately 77 million cars.
If this amount of associated gas were used for power generation, it could provide more electricity
(750bn kWh) than the entire African continent is consuming today. But currently, the gas is flared
for a variety of technical, regulatory, and economic reasons, or because its use is not given high
priority," says the World Bank.

Oman Tethys Oil's new oil field enters production
© Oman Daily Observer 2015 + NewBase
The commerciali-sation of a new oil field in Blocks 3 & 4 onshore Oman has buoyed hopes
that the massive acreage in the eastern part of the Sultanate will yield up more of its
hydrocarbon potential, according to international oil and gas firm Tethys Oil.
The Swedish upstream energy company
owns a 30 per cent interest in the two
adjoining blocks, with Mitsui (20 per cent) and
CC Energy Development SAL Oman Branch
(50 per cent) as partners. CC Energy
Development is also the operator of the two
blocks.
Previously called the 'Lower Buah Exploration
Area', the field was formally named 'Shahd'
after exploration and appraisal work revealed
that it had the hallmarks of a new oil field.
Discovered in March 2013, Shahd has since
turned into a major producing area, alongside
the producing Farha South and Saiwan East
oilfields of the two blocks.
According to Tethys Oil Managing Director
Magnus Nordin, the new oil field has since
delivered the majority of the increase in the
company's total reserves of the past two
years. "The Shahd oil field is Tethys' third field
on Blocks 3 and 4 in Oman, but most likely not
the last," said Nordin. "New leads in the Shahd
oil field continue to be identified as seismic interpretation goes on and the geological
understanding of the area increases. One rig is expected to be employed full- time during all of
2015 in this area," the executive stated in the company's 2014 Annual Report issued yesterday.
Tethys Oil, he said, will continue to invest in Blocks 3 & 4, output from which rose to a new
company record averaging more than 9,000 barrels per day during March this year. Average daily
production has been up by 14 per cent so far this year, compared to average daily production in
2014, he added. Blocks 3 & 4 "showed their true potential" during 2014, said Nordin. The Farha
South oil field in Block 3 continued its strong performance driven by continued development and
implementation of the water injection programme.
Tethys Oil also pledged to continue exploration efforts in several parts of the 36,410 square
kilometre blocks, both adjacent to current production and in other areas. In 2014 some 1,200
square kilometres of new 3D seismic was shot, which will be continually evaluated.
Blocks 3&4 represent Tethys Oil's most significant asset in Oman. Oil production from the two
blocks amounted to over 2.8 million barrels in 2014, representing a 64 per cent jump over 2013.
Tethys Oil has also interest in Block 15 in the northwestern part of central Oman. The licence
terms for Block 15 expired in 2014. Discussions regarding the future of the block are ongoing, the
company added.

US:Increasing domestic production of crude oil reduces net oil imports
Source: U.S. Energy Information Administration, Annual Energy Outlook 2015
In its recently released Annual Energy Outlook 2015 (AEO2015) Reference case, EIA expects
U.S. crude oil production to rise through 2020 as oil prices recover from their steep decline,
reducing net petroleum (crude oil and petroleum products) imports. AEO 2015 explores the effects
of domestic crude oil production under various assumptions about world oil prices and domestic
resource availability.
In all AEO2015 scenarios, the United States remains a net importer of crude oil (despite increased
domestic production) and a net exporter of petroleum products. As always with EIA base-case
outlooks, AEO2015 assumes no changes in current laws and regulations. Thus, all cases in the
AEO2015 assume that current restrictions on U.S. crude oil exports remain in place.
Increasing levels of domestic crude oil production through 2020 have two effects: lower crude oil
imports and higher throughput at U.S. refineries. Higher refinery throughput increases production
and net exports of refined petroleum products like motor gasoline and diesel fuel.
Together, lower crude oil imports and higher product exports reduce net imports of petroleum and
other liquids, which in 2013 provided 33% of total U.S. consumption (product supplied). In the
AEO2015 Reference case, this percentage falls to 14% in 2020, when domestic crude oil
production reaches 10.6 million barrels per day. Domestic crude oil production then begins to
decline, and the net import share of product supplied increases to 17% by 2040.
The United States also remains a net petroleum importer through 2040 in the Low Oil Price case.
Low world oil and petroleum product prices result in an increase in domestic petroleum product

consumption, which leads to significantly lower net petroleum product exports than in the
Reference case.
In two other cases, the United States becomes a net petroleum exporter after 2020, as net
petroleum product exports surpass net crude oil imports. In the High Oil and Gas Resource case,
increased domestic crude oil production growth is driven by production from tight oil formations.
This higher production is a result of more optimistic production assumptions compared with the
Reference case, such as higher estimated ultimate recovery (EUR), more significant technology
improvements, closer well spacing, and development of new tight oil formations or additional
layers within known tight oil formations.
With more domestic crude oil supply, the High Oil and Gas Resource case has both the greatest
decrease in net crude oil imports and the greatest increase in net petroleum product exports
through 2040 of all cases in the AEO2015 analysis.
In the High Oil Price case, higher world oil prices spur domestic crude oil production and reduce
domestic petroleum product consumption, leading to a significant increase in net petroleum
product exports through 2040.
However, because the High Oil Price case contains the same resource assumptions as the
Reference case, drilling moves into less-productive areas, resulting in a decrease in domestic
crude oil production in the later years of the projection. However, high oil prices continue to hold
domestic use of petroleum products below the Reference case level, keeping the United States a
net petroleum exporter through 2040.

Oil Price Drop Special Coverage
Oil prices drop as Middle East tension eases
Oil prices extended declines on Wednesday as Middle East tension eased after Saudi Arabia
ended a military campaign in Yemen, while industry data showed that a larger-than-expected build
in US oil inventories.
Saudi Arabia announced on Tuesday it was ending a month-long campaign of air strikes against
the Houthi rebels who seized large areas of Yemen, easing geopolitical tension in the key oil
producing region.
Oil prices have risen nearly $10 a barrel so far this month, on tension in the Middle East and
concerns over slowing output growth in the United States. Prices could weaken again but they are
unlikely to plumb new depths this year, leading commodity traders said on Tuesday, citing
strengthening demand.
"We will probably see one more dip in the second quarter but prices probably won't go below this
year's lows," Ian Taylor, head of the world's largest oil trader, Vitol, said. Brent crude for June
delivery was down 28 cents at $61.82 a barrel by 0142 GMT, after settling $1.27 lower.
US crude for June delivery was 38 cents lower at $56.22 a barrel. The May contract, which
expired on Tuesday, ended down $1.12. "Short-term momentum is starting to swing against

commodities," analysts at ANZ said in a note, noting that Brent has failed to hold and retreated
from key levels around $62-$63 a barrel in recent days.
US crude oil storage has reached the highest levels since 2011, with tanks in the Cushing,
Oklahoma hub running nearly 80 per cent full, according to energy markets intelligence firm
Genscape.
A Reuters survey showed US crude inventories likely rose for the 15th straight week, adding
nearly 3 million barrels last week, less than a reading by industry group American Petroleum
Institute showing a stock build of 5.5 million barrels.
Official stockpile data will be issued by the government's Energy Information Administration at
1430 GMT on Wednesday. While futures prices have been mostly driven by supply issues in
recent months, Vitol's Taylor said demand is strong and should provide support to oil prices.
"Gasoline is coming back with a vengeance. Refining margins are not as bad as we had feared,"
he said. Growth in demand outside the United States was impressive in India, South Africa and
even Europe, he added. –
Exxon’s Chief Tillerson Says OPEC Not Waging War on U.S. Shale Rivals
Rex Tillerson, chief executive officer of Exxon Mobil Corp., said he doesn’t think OPEC
is at war with U.S. shale.
OPEC’s refusal to curb output in response to the collapse in crude prices is an attempt to find the
most economic price for oil, not an attack on U.S. shale drillers, said Exxon Mobil Corp. Chief
Executive Officer Rex Tillerson.
The Organization of Petroleum Exporting
Countries is engaged in “a classic price-
discovery exercise” after the revolution in
shale-oil production turned global crude
markets topsy turvy, Tillerson said during
the IHS CERAWeek conference in
Houston on Tuesday.
The 10-month, 48-percent cascade in U.S.
oil prices has crushed stock prices,
eroded drilling budgets and cost tens of
thousands of workers their jobs.
“I don’t take the view that they are in any way trying to threaten other suppliers,” Tillerson said. “I
think they’re really kind of on a classic price-discovery exercise, which is important for all of us as
investors to know.”
Its “price discovery” is OPEC’s effort to find the highest price at which it will no longer have to
compete with supplies from higher cost producers.

Although painful to endure, the market correction will be good for the industry in the long run as
the lower oil price strips out excessive costs and forces producers to operate more efficiently, said
Tillerson, a 40-year veteran of the oil patch. Shale drillers in particular will have little choice but to
take more disciplined investment decisions and find opportunities to collaborate with rivals to
lower their risks, he said.
“I think it’s going to be very useful to the industry to have a clearer understanding of the resilience
of these resources, how robust these resources are, and how they are able to withstand different
price environments,” he said.
Boom And Bust
West Texas Intermediate crude, the U.S. benchmark, has averaged about $49 a barrel this year,
down 47 percent from last year and an annual average not seen since Tillerson took the helm at
Exxon in 2006. Excluding the 2009 oil slump that was “over before we realized it,” Tillerson said
he’s lived through three major boom-and-bust cycles since joining Exxon in 1975.
“My expectation is this is going to be with us for a while,” he said. “We’ll have some false signals,
we’ll have some false responses, where we get a little bump this way or that but I do think people
need to settle down for us to be in a different price environment for at least the next couple of
years and then we’ll see how things respond.”
His pessimistic outlook for crude prices was echoed by Patrick Pouyanne, CEO of Total SA,
Europe’s third-largest oil company by market value. Pouyanne, who succeeded the late
Christophe de Margerie after a fatal plane crash on a Moscow runway in October, also sees
opportunities to correct sloppy spending habits the industry developed when prices were sky high.
Lost Control
“This is an opportunity to clean up the oil industry,” Pouyanne said in remarks to the IHS
CERAWeek conference on Tuesday. “We lost some control over the way we spend the money.”
Tillerson, who oversees the largest U.S. shale operator, also said crude output from shale fields
may not abate, even as explorers slash spending, dismantle drilling rigs and scale back expansion
plans. A similar slump in natural gas prices five years ago that failed to slow supply growth may
hold a lesson for the energy industry, he said.
“Understanding how the resource really behaves in a reduced level of investment is something I
think we will all learn in this downturn,” Tillerson said. “Clearly a significant decline in rig activity
did not diminish the continued growth of natural gas capacity even in a very difficult price
environment. Is that analagous to the tight oil? I think that’s what we’re all going to learn.”

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 09 April 2015 K. Al Awadi

New base 588 special 22 April 2015

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