New base 804 special 09 march 2016

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,
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NewBase 09 March 2016 - Issue No. 804 Edited & Produced by: Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
UAE: Masdar powers up solar PV plants on Vanuatu island
The National - LeAnne Graves
Abu Dhabi’s Masdar has completed its sixth project in the Pacific islands under a US$50 million
initiative. The three solar photovoltaic (PV) plants, totalling 767 kilowatts, were developed in the
Pacific island nation of Vanuatu.
The project forms part of the UAE-Pacific Partnership Fund (UAE-PPF).
Only 27 per cent of Vanuatu’s most populated island, Port Villa, has access to electricity. The
island already generated some renewable energy from solar PV, wind and hydropower, but most
of the power comes from diesel generators – which means a high import bill for an island without
the natural resource.

The latest solar PV additions include 644 kWh ground-mounted and car park structures at the
parliament building as well as a 123 kWh ground-mounted structure at the meteorology
department building. Masdar’s installations will help save the island $378,000 on its diesel bill
alone, based on last year’s prices.
“By helping to alleviate their energy burden, we are enabling these Pacific nations to allocate more
of their resources to accelerating economic growth and maximising the potential of their
inhabitants," said Mohammed Al Ramahi, the acting chief executive of Masdar.
The UAE-PPF initiative finances renewable energy projects across the Pacific with grants from the
Abu Dhabi Fund for Development and projects delivered by Masdar in collaboration with the
Ministry of Foreign Affairs.
The programme has delivered more than 2.8 megawatts of renewable energy capacity, helping to
replace 1.5 million litres of imported diesel fuel.
The combined output of the projects has saved US$2 million per year and also eliminated 4,157
tonnes of carbon dioxide emissions annually, Masdar said.
“The continued success of the UAE-PPF is tangible evidence of Masdar’s ability to develop
workable renewables solutions and deploy them in the service of the UAE’s bilateral partnerships
with countries around the world," said Mr Al Ramahi.
“We have already helped to make a real difference in the six countries we are currently partnering
and we believe this partnership fund could provide a model for similar agreements around the
world."
Projects in Kiribati, Fiji, Tuvalu and Vanuatu are financed by US$50 million UAE-Pacific Partnership
Fund

Bid to recover untapped oil resource in Bahrain
Trade Arabia News Service
Bahrain is considering the launch of a pilot project to recover a huge untapped resource in the
residual oil saturation in the Gas Cap of the Mauddud reservoir, Energy Minister Dr Abdul Hussain
bin Ali Mirza said here at a conference on Monday.
Speaking at the opening of the 12th Middle East Geosciences Conference and Exhibition (GEO
2016), the minister said that efforts are being made to produce the residual oil saturation in the
Gas Cap of the Mauddud reservoir. “For this, currently an expanded pilot project is being
evaluated to determine the best way to recover this huge resource,” he added.
The Bahrain Field, said the minister, was discovered in 1932, the first discovery in the GCC
countries. “We are proud of the fact that although a large percentage of the recoverable reserves
of the Bahrain Field have already been produced over the last 84 years, National Oil and Gas
Authority (Noga), through Tatweer Petroleum, managed during the last few years to arrest, and
reverse the declining oil production, and to increase the daily oil output by more than 50 per cent,
compared with the production level of 2009.
“Additionally, the non-associated gas production capacity was also increased by around 30 per
cent, which enabled us to meet all natural gas demands during the last five years,” added Dr
Mirza.
Energy Minister Dr Abdul Hussain bin Ali Mirza alongwith other speakers at
the opening session of the 12th Middle East Geosciences Conference and
Exh

“Despite all challenges, we are confident, and determined, to develop the non-associated gas
resources of the deep sandstones formations in the Bahrain Field,” he added. According to him,
Noga has managed to reduce
associated gas flaring in the
field, to less than 0.5 per cent.
The associated gas that used
to be flared, he said, is
captured and re-injected in the
producing reservoirs.
A $355 million expansion of
gas processing facilities at the
Bahrain National Gas
Company will increase its
processing capacity by 350
million cubic feet per day. It
will process the additional
associated gas, which resulted
from Tatweer’s increased
production to produce
liquefied petroleum gas.
“The residue gas, will then be
injected in the producing
reservoirs, to maintain
pressure and to cycle the rich
gas,” he added. During his
opening remarks to
conference delegates, Dr
Mirza said the conference
theme ‘Today’s Geoscience,
Tomorrow’s Energy’ truly
reflected the reality of the
petroleum industry.
“Today, we find ourselves in a
price environment, that has
serious implications on the
long-term horizon of the world
we live in, and on the welfare
of nations and citizens. “Many
of the producing nations, have
set their spending budgets, on
certain revenue assumptions, that are multiples of today’s prevailing prices,” he added.
According to him, with the current decline in oil prices from $115 per barrel in April 2011 to an
average price of $32 per barrel in January, and as the upstream business grows increasingly
competitive, coupled with the realisation that most of the easy oil had already been found and
mostly produced, development of new supplies would be more challenging, more expensive to

produce, and also require innovative solutions that are likely to be developed by technical
congregations like conferences.
“Our challenge is to combine technology, business and people in an innovative way, that enables
us to successfully produce the huge oil and gas reserves, in the Arabian Gulf, and deliver them to
the market in a safe, reliable and cost-effective manner,” he said.
According to him, the task will require collaboration between the industry, service providers,
academia and host governments.
“We must continue to develop technology, that accurately locates hydrocarbon reserves and
produce them. Our focus today is on finding new reserves, maximising recovery factors from
discovered assets, optimising cost and developing sustainable supply solutions.”
The key to the future will be the better understanding of the geology, rock mechanisms and
development of new technology that allows industry to provide oil and gas, from the highly
potential resources of unconventional reservoirs, he said.
On the business side, the co-operation between international oil companies and host countries is
more urgent than ever to explore and produce difficult oil and gas resources.
This, he said, will most likely mandate the development of new contracting strategies that address
the concerns of all relevant parties.
The service providers, with their established research and development capabilities, will continue
to play an important role to better image the subsurface, for finding additional reserves, and for
providing the stakeholders with innovative solutions needed to produce the remaining reserves in
mature fields.
On the people side, the oil and gas industry must manage the human side of its resources.
Dramatic demographic shifts are threatening the sectors’ health, like never before, said the
minister.
The associated 6,000 sq m exhibition of oil and gas exploration products and services opened in a
separate ceremony today. More than 4,000 delegates and 120 exhibitors will converge for three
days of unbeatable educational opportunities and networking.

Indonesia: Andalas Energy and Power signs Tuba Obi East gas
project farm-in agreement
Source: Andalas Energy & Power
Andalas Energy and Power, the AIM listed investment company, has conditionally entered into
a farm-in agreement for the Tuba Obi East ('TOE') Technical Assistance Contract ('TAC'),
which is located in the South Sumatran basin approx. 30km north-west of Jambi city in Jambi
province, Sumatra.
Highlights:
• ADL to acquire 30% working interest in TOE TAC via a farm-in;
• TOE is the entry point for Andalas into the profitable Indonesian gas and power sector;
• Any future gas production from the concession may support either:
o Gas export with the project located close to a major export route; or
o Gas-to-power being located in an area where a significant shortfall in power
generation exists;
• Farm-in via execution of a US$1.075 million work programme;
• Work programme comprises technical studies and the drilling and testing of one well
which would be put into production on success;
• Work programme is being jointly operated by Andalas;
• Planning and preparations for drilling are advancing rapidly;
• Subject to well results, further gas and power development studies will be undertaken;
• Gaffney Cline and Associates is in the final stages of completing a Competent Person’s
Report ('CPR') assessing the gas resources within the TAC; and
• Farm-in constitutes a reverse takeover pursuant to the AIM Rules and, accordingly, the
farm-in agreement is subject to the approval of Andalas’ shareholders in general meeting.
• An admission document which will include notice of a general meeting seeking
shareholder approval will be published in due course.
Andalas CEO, David Whitby, said 'The signing of this agreement follows the Letter of Intent
announced on 3 February 2016 and secures ADL’s foundation gas asset. We are keen to take
full advantage of the opportunity Tuba Obi East now affords Andalas, and we
regard it as the base upon which a profitable Indonesian gas and power
business can be built.
'TOE has all the essential features to be a successful first asset for the
Company. It has gas proven by two wells into the reservoir zone that has
been defined on 3D seismic and confirmed by well logs, all whilst located in a
prolific hydrocarbon basin. In addition, the field is close to both gas and
power infrastructure and has easy access to Indonesia’s burgeoning energy
market which is generating high prices for producers. It represents an
unrivalled opportunity for a new Indonesian gas and power market entrant like ADL.'
Farm-in Summary

As previously announced, under the terms of the proposed farm in, Andalas will acquire a 30%
direct working interest in the concession through the execution of a single well work programme.
The work programme includes the completion of a geological, geophysical and reservoir
(‘GG&R’) study along with the drilling and flow testing of a single well to assess the deliverability,
recoverable volumes, and gas quality in the Air Benakat formation.
Block operator PT Akar Golindo and Andalas will jointly operate the well work programme, which
is expected to cost around US$1.075 million. Andalas has also agreed to pay a further sum of
US$500,000 to PT Akar Golindo if the concession is renewed beyond its expiry date of 15 May
2017.
Pursuant to Rule 14 of the AIM Rules for Companies this farm-in constitutes a reverse takeover
and, accordingly, the farm-in agreement is subject to the approval of Andalas’ shareholders in
general meeting.
Work Progress
Under the terms of the agreement the Company will be the technical operator for the Tuba Obi
East well work programme. Accordingly, ADL’s in-country team has expedited the design,
planning and site preparations for the farm-in well (provisionally called TOE-2). The concession
operator, PT Akar Golindo, has also been supporting this work.
Two well locations (a preferred location and an alternate) have now been selected and site
surveys have been completed, along with the inspection of potential drilling rigs, during the week
commencing 22 February 2016. The drilling team is now progressing the rig selection process
whilst services contracting continues apace, with the preparation of critical tender documents.
As part of the reverse takeover process, representatives from the Company’s nominated adviser,
Cantor Fitzgerald (Europe), have visited the field. Gaffney Cline and Associates in Singapore
has almost completed its CPR assessing the gas resources within the concession. The results
of their analysis are expected shortly. Andalas will publish the Admission Document in due
course.
Tuba Obi East Gas
Tuba Obi East is located in the South Sumatran basin approx. 30km north-west of Jambi city.
The wells previously drilling in the concession have tested gas in the key South Sumatra
hydrocarbon bearing formations, namely, the Air Benakat Formation (‘ABF’) and the Talang Akar
Formation (‘TAF’). A total of six wells (three wells within the concession and a further three just
outside) have been drilled through these zones, with a number having been logged across the
ABF and TAF. Several have also flowed gas to surface.
Crucially, the ABF has flowed gas outside the TAC at commercial rates, but only limited data
from this formation has been gathered within the concession area. Andalas’ technical analysis
indicates that this reservoir zone contains potentially substantial gas resources that can be
proven via the drilling and flow testing of the proposed TOE-2 well. If the work programme
proves successful, the TOE-2 may be completed as a future production well.
Further GG&R and development studies will be undertaken following the analysis of test results
from the well. This work will be conducted in parallel with development planning and a proactive
approach to the renewal and extension of the concession contract. Preliminary discussions will
also be held with targeted gas and power consumers.

Malaysia's Reach Energy Acquires 60% Stake in Kazakhstan Block for $155M
RigZon - Chee Yew
Malaysia's Reach Energy Berhad entered into a tripartite conditional Sale and Purchase
Agreement March 5 with Palaeontol Cooperatief U.A. and MIE Holdings Corp. to acquire a 60
percent stake in Palaeontol B.V., the company announced Monday on local exhange Bursa
Malaysia.
Palaeontol B.V., a unit of MIE Holdings' subsidiary Palaeontol Cooperatief, is the exclusive owner
of Emir-Oil LLP which holds full working interest in an onshore block in Mangistau Oblast in
southwest Kazakhstan.
The 328.3 square mile (850.3 square kilometer) block, located around 24.9 miles (40 kilometers)
northeast of Aktau -- Kazakhstan's largest port in the Caspian Sea coast, comprises four existing
oil and gas producing fields. They are the Aksaz, Dolinnoe, Emir and Kariman fields, occupying
around 17.6 square miles (45.5 square kilometers) in the block.
Reach Energy revealed that exploration, development and production of hydrocarbons will
continue in the remaining 349.3 square miles (804.8 square kilometers) of the block, including
two discovered fields and six drillable prospects.
RPS Energy Consultants Ltd., the independent technical and asset valuation expert appointed by
Reach Energy, estimated that the indicative gross proved plus probable (2P) reserves of the
producing fields and development fields in the block at around 72.1 million stock tank barrels
(MMstb) of oil and 102.4 billion standard cubic feet (Bscf) of gas as at Jan. 1.
The net 2P reserves attributable to the firm upon completion of the proposed acquisition are
around 43.3 MMstb of oil and 61.4 Bscf of gas, equivalent to total net 2P reserves due to Reach
Energy of 53.5 million barrels of oil equivalent.
The firm, a special purpose acquisition company, will pay $154.9 million (MYR 638.2 million) for
the stake in Palaeontol B.V., which upon completion will give Reach Energy majority ownership
and control over the Emir-Oil fields.

"The Proposed Acquisition represents Reach Energy’s qualifying acquisition as stipulated under
the Equity Guidelines issued by the Securities Commission Malaysia and will transform Reach
Energy into an independent Malaysia-based E&P (exploration and production) company with its
maiden operation in Kazakhstan," the firm said in a press release.
“Reach Energy entered into this Proposed Acquisition after identification and evaluation of some
40 candidates. The Producing Fields and Exploration Area (collectively known as Emir-Oil Fields)
provide a unique opportunity for Reach Energy for investing and operating a balanced portfolio of
O&G (oil and gas) fields covering the wider spectrum of upstream O&G production, development
and further exploration activities," Reach Energy's Managing Director Shahul Hamid Bin Mohd
Ismail commented in the press release.
"We are confident that we can deliver much value to our shareholders from this asset with the co-
operation of our partner, MIEH, who is an established independent E&P company with
operations in China, Kazakhstan and the U.S. The Producing Fields are in their early and prime
stage of production and the Development Fields are currently under pilot production. We believe
that there is significant upside potential through further planned efforts, techniques and
schemes,” he added.
The proposed acquisition of the onshore Kazakhstan block meant that Reach Energy had
dropped a plan to purchase an upstream target in the Asia Pacific.

South Africa to Start Shale Gas Exploration Next Financial Year
Reuters + NewBase
Shale gas exploration in South Africa is expected to commence in the next financial year (Apr-
Mar). “One area of real opportunity for South Africa is the exploitation of shale gas. Shale gas
regulations were published in the second quarter of 2015-16. Exploration activities are scheduled
to commence in the next financial year.
This will lead to excellent prospects for beneficiation and add value to our mineral wealth, the
South African government said in a statement published on its website Tuesday. In January,
Minister for Mineral Resources, Mosebenzi Zwane stated that South Africa has world’s 5th largest
shale gas reserves.
“Currently South Africa is a net importer of energy sources such as crude oil, refined petroleum
products and natural gas. It is estimated that the Karoo shale gas resources would mean South
Africa has the 5th largest reserves, estimated at 485 trillion cubic feet (Tcf),” Zwane said in
January.
“We however take a conservative view of a 30 Tcf economically recoverable resource, which is
equivalent to 30 times the size of the Mossgas plants.”
Regulatory hurdles have resulted in delay in start of shale gas exploration in the country. Energy
major Shell last year exited the shale gas exploration space due to repeated delays in issuance of
licences.
The Karoo Basins
The southern Main Karoo Basin is considered to be the most prospective area for shale gas in
South Africa, due to the presence of deeply buried, thermally mature black shales. To date,

exploration right applications have been received from Shell International, Falcon Oil and Gas in
partnership with Chevron, and Bundu Gas.
Natural gas and oil shows across the Main Karoo Basin indicate an active petroleum system with
multi-play potential. The widespread occurrence of pyrobitumen (pseudo-coal) in the southern part
of the basin indicates an originally oil-prone source rock.
In 1968, exploration well CR1/68 in the southern Main Basin yielded a gas flow rate of 1.83
mmscf/day for 23 hours from the fractured Fort Brown shale. The Fort Brown was thought to be
self-sourcing (i.e. a gas shale), but may also have been charged by the underlying Whitehill
Formation.
The volume of gas in place in the Main Karoo Basin is highly uncertain, but possible scenarios
suggest that technically recoverable volumes may range from 30 Tcf to 500 Tcf. A key uncertainty
is the gas content of the various Karoo shale formations – this may be limited where diagenesis is
particularly high.
The Permian Whitehill Formation is considered to be the most promising shale gas target in the
Karoo, due to its high organic carbon content (TOC = 5 % average), high thermal maturity (Ro =
1-4 %), high quartz content (50 %), thickness (30 m average) and regional continuity (200 000
km2). However, a major exploration risk factor is the existence of dolerite intrusions, which occur
in much of the Karoo Basin.
Karoo shale gas is considered to be only a prospective resource at present, and will remain
undiscovered until a hydraulically fractured test well produces enough gas to be of commercial
interest. The economic value of Karoo shale, in turn, will only be known once a statistically
significant number of well flow rates have been measured. The long term market for gas in South
Africa is likely to be strong as the country's energy needs continue to grow. However, a significant
investment in infrastructure will be required before South Africa becomes a major shale gas
producer.

NewBase 09 March 2016 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Oil prices dip on stronger dollar, demand concerns
Reuters + NewBase
Oil prices dipped on Wednesday, weighed down by a strengthening U.S.-dollar and concerns over
slowing demand, although falling U.S. production lent crude markets some support.
U.S. crude futures were trading at $36.46 per barrel at 0219 GMT, down 4 cents from their last
settlement, but still almost 40 percent above February's 2016 and multi-year low.
International Brent crude futures were at $39.54 per barrel, down 11 cents from their last close,
but still some 40 percent above their January lows for this year.
The dips came as the dollar reversed recent losses against a basket of leading currencies
overnight, potentially hampering oil demand as imports of dollar-traded crude get more expensive.
But analysts said the main reason for the dip in prices and at least temporary end to the rally was
concern over faltering demand in China, where the economy is growing at its slowest pace in a
generation.
"The recent oil rally is looking overextended ... China's export data was horrendous," Matt Smith of
Clipper Data said in a daily report.
China's February trade performance was far worse than economists had expected, with exports
tumbling the most in over six years.
Oil price special
coverage

Although China imported record crude volumes of 8 million barrels per day (bpd) in February,
analysts expect this figure to fall as the government scales back purchases of strategic reserves,
and car sales begin to fall as the sharpest economic slowdown in a generation starts to show
results.
The price dips at least temporarily halted a price rally that started in mid-February on hopes that a
coordinated freeze in production would stop growth in a global supply glut of at least 1 billion bpd
above consumption that helped pull prices down as much as 70 percent since 2014.
But OPEC-member Kuwait, this week poured cold water on hopes of such a freeze by stating that
it would only cap output if all major producers participate, including Iran, which has balked at the
plan.
One key factor in determining the oil market balance will be U.S. output, which the government
said would be 8.19 million bpd in 2017, down from over 9 million bpd currently.
But with demand growth also slowing, many analysts including influential bank Goldman Sachs,
say that it will take time for markets to fully rebalance.
Energy consultancy Wood Mackenzie said that it expects "the annual average (oil) price for 2016
being lower than 2015 and then recovering in 2017, reflecting large oversupply and high stock
levels during the first half of 2016".
It added that the main risks to its forecast were changes in demand in China and the extent to
which Iran manages to increase oil exports after sanctions against it were lifted in January.

An oil output freeze would have a limited impact
Asiya Investment - Camille Accad
The Russian energy minister announced on Tuesday that over 15 countries had already
announced their intention to join the agreement. According to the Russian energy minister, that
would be equivalent to 73% of global oil supply, a substantial success. That number seems to be
exaggerated or inaccurate. Assuming that the United States, Canada, China and Iran are not in
the agreement (they account for 26% of global production), it would imply that all other oil
producers in the world have agreed to the freeze.
A coordinated oil output freeze will have little impact on global supply since the group of countries
in the agreement will freeze production at record-high levels. OPEC members and Russia are
already producing around record highs with little room to produce more.
Thus, a freeze would only succeed at controlling a small part of the potential increase in future oil
output. Exceptions are (a) Iran and Iraq, which will most likely be given an output allowance since
both countries are producing much less than their full capacity and will not accept any cap at
current levels, and (b) Libya, which despite producing much less than full capacity remains
severely handicapped by a disrupting civil war.
Despite having little effect on actual oil production, the agreement would produce important
benefits for oil exporters. First, the deal would create a wider-than-OPEC framework for decision-
making. Second, it creates a mechanism for producers to track each others’ production levels –
the details are already under discussion.
Transparency has been a recurrent problem for OPEC members and steps on this direction will
improve the effectiveness of future decisions. Finally, a production freeze is a prerequisite to

potential coordinated output cuts. Although production cuts remain unlikely for this year, an
agreement would open the door for such a possibility.
In spite of the potential agreement, the clearing of the supply glut is underway, because US
output, the main source of production increase in the last decade, has already started to adjust.
Between January 2012 and December 2014, global oil supply rose from around 76.5 million
barrels per day to around 80 million bpd.
The main contributor was the US, whose production surged by 3.5 million bpd. US crude oil output
peaked in May 2015 at 9.6 million bpd, and has since fallen by around 500,000 bpd, because of
the high cost of extracting shale in a low oil price environment. Saudi Arabia’s decision to ramp up
production in 2015 in a bid to fight for market share led to the sharper decline in oil prices in the
second half of last year.
With US production already falling and global output peaking, an agreement between the major
oil producers is not necessary to clear the supply glut, especially if Iran would not have to
immediately comply to the freeze. Moreover, tensions in the Middle East – marked by a bruised
relationship between Iran and Saudi Arabia, and Russia and Arab states – further suggests that
such a deal would have to come out of necessity.

NewBase Special Coverage
News Agencies News Release 09 March 2016
Global oil Slump Brings These Two Rivals Together
Bloomberg - Rene Vollgraaff
Misery loves company. Africa's two biggest economic rivals — South Africa and Nigeria — are
turning to each other as they fall on tough times.
South Africa's economy is threatened with recession as demand from China, its main trading
partner, weakens and commodity prices plunge, while Nigeria has been hit by a collapse in oil
revenue. To weather the global storm, the two countries are seeking closer trade and investment
ties when South African President Jacob Zuma leads a high-level delegation of ministers and
business executives to Nigeria on Tuesday. In the process, he may rebuild a relationship that's
come under diplomatic strain in the past.
Nigeria may be Africa's largest economy — having overtaken South Africa in 2014 after the data
was overhauled — but South Africa still dominates because of better power and transport
infrastructure, a sophisticated financial services industry and a more diversified economy. Both
economies are now under pressure, with growth slowing to 1.3 percent in South Africa last year
and reaching a 16-year low of 3.3 percent in Nigeria, according to the World Bank.
South Africa is the biggest buyer of Nigerian oil in Africa, shipments of which have more than
doubled between 2008 and 2014, according to data from the International Monetary Fund.
However, Nigeria doesn't even feature in the top 20 of South Africa's export markets.

"There is scope for the two countries to expand trade ties, particularly in non-commodity
products," said William Jackson, a senior emerging markets economist at Capital Economics Ltd.
in London. There could "be greater benefits over the medium term, as rising trade in non-
commodity goods tends to come alongside faster productivity growth and more rapid rises in
incomes," he said.
The one thing standing in the way of stronger trade ties is the Nigerian currency. The central bank
has effectively pegged the naira at 197 to 199 per dollar for a year by banning imports of
everything from glass to wheelbarrows and restricting foreign-currency supply. The currency

controls are deterring investors, like Johannesburg-based Truworths International Ltd., which shut
its two remaining stores in Nigeria in January.
In his first state visit since Muhammadu Buhari was elected Nigeria's president last year, Zuma
may also seek to resolve a dispute that threatens the Nigerian operations of one of South Africa's
biggest companies, MTN Group Ltd. Nigeria's telecommunication regulator imposed a record $3.9
billion fine on MTN last year for failing to meet a deadline to disconnect unregistered mobile-
phone subscribers.
Even before that, diplomatic relations between the two countries were strained by xenophobic
violence in South Africa last April, in which Nigerian businesses were attacked. Nigeria temporarily
withdrew its two most senior diplomats from South Africa at the time.
"These two countries need this competitive kind of relationship, where they cooperate even
though they are competing," said Azwimpheleli Langalanga, a visiting research fellow in the
economic diplomacy department at the Johannesburg-based South African Institute of
International Affairs. Nigeria wants "to be taken seriously because they are a serious player on the
African continent," he 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
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 March 2016 K. Al Awadi

New base 804 special 09 march 2016

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