New base special 12 march 2014

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NewBase 12 March 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Alstom Smart Grid in Dubai
http://www.emirates247.com/business/alstom-smart-grid-in-dubai-2014-03-11-1.541166
French multinational conglomerate Alstom has opened its first Smart Grid Center in the Middle
East in Dubai which will enable electricity suppliers across Mena region to deploy smart solutions
and improve services to customers.
It’s the third centre of its kind by Alstom in the world. The French giant is operating two similar
smart grid centres in the US and France. The centre’s inauguration was attended by Saeed
Mohamed Al Tayer, Managing Director and CEO of Dubai Electricity and Water Authority (Dewa);
France Ambassador in the UAE Michel Miraillet; Grégoire Poux-Guillaume, Alstom Grid President;
and Saeed Al Mazrouei, CEO of Emirates Aluminium (Emal).
Grégoire Poux-Guillaume said: “The inauguration of Alstom Smart Grid Centre in Dubai is a
cornerstone of the group’s commitment to the development of the Smart Grid in the UAE and
Middle East.
“As Smart Grid technologies are integrated to existing infrastructure, customers in the region will
benefit from the centre’s close link to Alstom’s state-of-the-art Smart Grid Centres in France and
USA, using tools and processes with the latest technologies and ongoing support from Alstom
experts worldwide – in real time,” Grégoire Poux-Guillaume said.
The Middle East region faces increasing demand for electricity, grid reliability, stability and lower
environmental impact, and the introduction of digital equipment and software applications into
existing infrastructures will help power generation and electrical utilities to interconnect existing
assets and optimize network control, making the most of energy available and ultimately working
towards a smarter grid with a lower carbon footprint.
Alstom has been awarded projects in all the Mena countries including Egypt, Lebanon, Syria, Iraq,
Saudi Arabia, Kuwait, Qatar, Pakistan and Yemen. It’s currently working on major projects in
Saudi Arabia and Qatar.
(From right): Michel Miraillet, Saeed Mohamed Al Tayer,
Grégoire Poux-Guillaume and Saeed Al Mazrouei at the
opening of Alstom’s Smart Grid Centre in Dubai (SUPPLIED)

Saudi Aramco says keen to raise natural gas output
By Reuters
Saudi Aramco plans to produce 200 million cubic feet per day (cfd) of unconventional natural gas by 2018
to supply a new phosphate project and a power plant, an industry source said. OPEC member Saudi Arabia
aims to develop shale gas for power generation in order to save more of its crude oil for export.
Aramco is keen to increase gas output as it can fetch $100 per barrel by exporting crude oil versus around
$4 if it sells it to a Saudi power plant. CEO Khalid al-Falih said last year the company was ready to commit
gas for the development of a 1,000 megawatt power plant which will feed a phosphate mining project that
Saudi Arabian Mining Co (Maaden) is developing for the Waad al Shamal Mining City.
"40 million cfd will go to the phosphate project of Waad al Shamal while 160 million cfd will go to Saudi
Electricity Co for a power plant," the industry source said. Oil minister Ali al-Naimi has said Saudi Arabia
has estimated unconventional gas reserves of more than 600 trillion cubic feet, more than double its proven
conventional reserves.
That would put Saudi Arabia fifth in a 32-country shale gas
reserves ranking compiled for the U.S. Energy Information
Administration. Saudi Aramco is exploring and has made
appraisals in the northwest area, the Eastern Province and in
the Empty Quarter. It is drilling in the south of Ghawar, the
northwest and Jafurah which lies between Al Ahsa and
Qatar.One obstacle is finding water needed to release
natural gas from rock, shale or compacted sand formations.
Saudi Arabia aims to use either sea water or liquefied petroleum gas, the latter a technique being developed
by North American companies. "Water is always an issue, it is an issue in North America when they have
much more water than we have here in this region," Amin al-Nasser senior vice president of upstream at
Aramco said at an industry conference in Manama on Sunday. "We are looking at using sea water, we are
working with lots of companies. Schlumberger is one of them in terms of using water fracking. We are
confident that technology will be developed and if we have to use water as I said we are looking at using sea
water," said Nasser. "The focus area for us is unconventional gas....the cost of unconventional is as you
know on the high side and so the question is how do we do it economically," he told the conference.

Gazprom approved Shell Sakhalin-2 LNG Expansion Roadmap
http://www.2b1stconsulting.com/gazprom-approved-shell-sakhalin-2-lng-expansion-roadmap/
Gazprom and the Royal-Dutch Shell (Shell) met in Sotchi end of February to approve a
memorandum of understanding (MOU) defining the roadmap to proceed to the Sakhalin II
expansion project with the addition of a third liquefied natural gas (LNG) train at the existing
Prigorodnoye plant at the south of the Sakhalin Island in Far East Russia.
This Sakhalin II third LNG train project was in intensive discussion between Gazprom and its
partners Shell, Mitsui & Co (Mitsui) and Mitsubishi Corporation (Mitsubishi) as each member of the
Sakhalin Energy joint venture had different views regarding such expansion.
The Sakhalin Energy joint venture is operating
Sakhalin II with working interests shared between:
- Gazprom 50% plus one share
- Shell 27.5% less one share
- Mitsui 12.5%
- Mitsubishi 10%
Through the first production sharing agreement
(PSA) signed in Russia in 1994 with the Russian
Federation Government, Sakhalin Energy holds
since then one of the largest oil and gas
production asset in Russia including:
- Three offshore oil and gas production platforms
located along the northeast coast of the Sakhalin
Island
- Onshore processing facilities .
- Booster station
- Oil export terminal
- Two trains LNG Plant
- Onshore pipelines system to connect the
platforms in the north to the export facilities in the
south of the Sakhalin Island
In operation since 2009, Sakhalin II still remains
as one of the largest LNG plant in the world as it
exported to Asia in 2013:
- 10.8 million tonnes of LNG
- 40 million barrels of crude oil

In respect with the existing infrastructures, Shell and its Japanese partners Mitsui and
Mitsubishi are pushing for the addition of a third LNG train that could optimize Sakhalin II
expansion at low cost.
Gazprom and Shell prepare FEED for Third LNG Train
In parallel to Sakhalin, Gazprom is working on ts own on the greenfield Vladivostock LNG project
on the Russia mainland to serve the same markets as Sakhalin Island LNG plants.
In the current race to secure Asia markets for the supply of LNG, Gazprom wanted to give the
priority on its own Vladivostok LNG project before expanding Sakhalin II.
But a solution could be settled these last
weeks as Gazprom obtained from Moscow
to proceed with its three main LNG projects
on the drawing board:-
- Baltic LNG
- Vladivostok LNG
- Sakhalin II Third LNG train
This decision is to support President Putin
target for Russia to address 10% of the
global LNG market by 2020.
Not presuming of Gazprom time frame to
develop its own Baltic LNG and Vladivostok LNG projects, the addition of a third LNG train in
Sakhalin II appears to all partners has the most secured and cost effective solution to contribute to
Russia 2020 LNG production target.
In this context, Gazprom, Shell and their Japanese partners Mitsui and Mitsubishi, are preparing
the call for tender for the front end engineering and design (FEED) work of this Sakhalin II Third
LNG train so that the Sakhalin-2 Expansion project could start first shipment by 2019.
NewBaseComments
With a slew of LNG
projects slated to start
production up to 2020,
Tatiana Mitrova, head
of global energy at
Russia’s SKOLKOVO
business school
Energy Centre, sheds
light on what options
are available in the

The Russian LNG market in 2018: perception and reality
Leigh Elston , http://interfaxenergy.com/
If you believe project developers, 2018 is the year a new wave of liquefaction capacity from North
America, East Africa and Australia will hit the market. But a new report from Interfax Energy, titled
LNG: The 2018 Illusion, argues that few really believe this is what the market will look like in five
years’ time. Soaring
LNG demand in Asia –
a region where imports
increased by 45.1 mt
between 2010 and
2013 – and scant
supply growth have led
to an increasingly tight
market over the past
three years. While the
next three years will
see the supply scarcity
begin to ease – around
66 mt of new capacity
is expected to come
onstream between
2013 and 2017 – 2018
is meant to be the year that delivers the feast.
Going by official project timetables, the world’s liquefaction capacity is set to almost double over
the next five years, from 288 mt in 2013 to 575 mt in 2018. Half of this is expected from North
America, where surging shale gas production has opened record spreads between US and Asian
prices.
However, according to estimates from Natural Gas Daily and Global Gas Analytics, challenges on
the ground – whether rising construction costs in Australia, legislative delays in Mozambique, or
permitting uncertainties in North America – mean not just some, but most new projects are likely
to face delays.
Only a few new projects can realistically be brought online before 2018 – and most of those are
already under construction.
Given it takes around four years to build a world-scale LNG plant, projects that do not take an FID
within the next few weeks – and few are in a position to do so – will not make startup until after Q2
2018. Even then it will, in most cases, be only the first train that will be brought online, with
subsequent trains being added later.
So when 2018 rolls around, any supply spike is likely to be far less dramatic in reality than is
currently expected. While the next five years will certainly see the strain in the market slacken, it
will be a more gradual easing, with no more than a 40% increase in total capacity by
2018.However, in an industry where schedule overruns are common, perhaps the perception of a
supply spike in 2018 could provide enough of an incentive for sponsors, governments, and
financers to speed up project development.
The Grand Elena LNG tanker near the Sakhalin 2 LNG project. (PA)

Indonesia faces reality check on CBM dream
Robert Sullivan ,Shale and other resources in Indonesia.
Three years on from the first commercial production of CBM in Indonesia, an industry that is
expected to eventually account for as much as 15% of the country’s gas production is no closer to
reaching its target.
With an estimated 13.59 trillion cubic metres of CBM in place, Indonesia’s resource base is
believed to be second only to China. But despite the clear potential, the country is nowhere near
the government’s production target of 15 million cubic metres per day (MMcm/d) by 2015.
For now, Indonesia’s commercial CBM production stands at around 3 MMcm/d, Susilo
Siswoutomo, deputy minister for energy and mineral resources, said at the Indonesia Energy Oil &
Gas 2014 conference in Bali on Tuesday – adding it is well short of the 2015 goal.
Factors to blame
Among the many factors blamed by both the government and industry players for the stalled
progress on CBM development are issues involving access to land and permitting at the local
level. For instance, Indonesia’s upstream oil and gas regulator, SKKMigas, has estimated land
acquisition and permitting issues account for as much as 33% of the delays faced by the oil and
gas industry. “The problem [for CBM] is on the land acquisition,” Siswoutomo said. “The
permitting – that is killing us.”
Ridwan Rusli, director and chief executive of the Indonesian exploration company Samudra
Energy, agreed. “[Land acquisition] is one of the greatest challenges facing unconventional and
CBM, given the fact that they will require many more wells for the same gas volume production,”
he said. “I think many contractors need help from the government – and in this case, the central

government.” A new land acquisition law passed in 2012 is seen as a further source of complications in the
permitting process. The new regulations stipulate land acquisitions for public interest ventures such as oil
and gas projects can only be negotiated by the government, through the National Land Agency.
In addition, contractor delays and rig availability have also been highlighted as barriers to CBM
development.SKKMigas has blamed internal issues related to contractors for as much as 24% of the delays
the oil and gas industry faces.
The Indonesian government has signed 55 production sharing contracts (PSCs) for CBM since it issued
initial regulations for the industry in 2004. But, according to Siswoutomo, not all of the contractors have
fulfilled their commitments.
“Some of the commitments made by the KKKS [PSC contractors] for CBM are not what they proposed or
promised,” he said. Still, acknowledging that rig availability and associated costs cause some delays for the
contractors, he recommended Indonesia build more of its own rigs to encourage more CBM exploration
and production.
“I want to build [thousands] of rigs for CBM, so the rigs for CBM will be available and the cost will be much
cheaper,” Siswoutomo said. He also suggested examining the feasibility of having trading operators for
CBM rigs, who could match up available operators and rigs.
Technical hurdles
CBM production, as well as the development of shale gas, is also being hindered by a lack of local
expertise with the technology-heavy operations. Although there are a number of foreign companies with
experience in unconventional gas development already operating in Indonesia, domestic companies often
do not have the experience or technical experience for the unconventional sector.
This problem could be exacerbated by the
Energy Ministry’s decision in October to
impose restrictions on the employment of
foreigners for certain roles in Indonesia’s
oil and gas sector.
Indonesia’s state-run oil and gas company,
Pertamina – which has signed Indonesia’s
sole PSC for shale gas to date at the
Sumbagut Block in North Sumatra –
currently has only five qualified people
working on the PSC, a geologist with the
company told Interfax on the sidelines of
the event.
He added, however, that Pertamina is
working with American oilfield services
provider Baker Hughes on technology transfer and training for shale gas development, and it has enlisted
the help of Canada’s Talisman Energy for technical assistance related to its wholly owned Sumbagut PSC.
Indonesia’s CBM prospects received another blow late last year, however, when news broke ExxonMobil
was preparing to pull out of its exploration in the Barito Basin, on the island of Kalimantan. Exxon’s partner
in the project, Canada-based CBM Asia, said in December it was still reviewing the major’s draft
termination agreement, and has not provided any updates since.

Chevron reaffirms strategies, highlights performance, portfolio and future growth
Source: Chevron
Chevron is continuing to generate industry-leading operational and financial results and advancing key
projects to drive future growth, executives said Tuesday at the company's annual security analyst meeting in
New York. 'World energy demand continues to grow and the outlook for the energy business remains
excellent,' said John Watson, Chevron's chairman and
CEO. Watson added, 'Our strategies are sound, and we're
poised to deliver significant production growth through
the end of the decade. We believe this compelling growth
profile, combined with flattening capital spending levels
these next few years, should serve as a strong catalyst for
value creation for our shareholders in the years ahead.'
George Kirkland, vice chairman and executive vice
president, Upstream, reviewed the performance of
Chevron's upstream business in 2013, marking yet
another year where the company led the industry on
multiple upstream financial metrics including earnings
and cash unit margins, as well as return on capital
employed. He also discussed some of the company's
portfolio management strategies and practices while highlighting key attributes of the portfolio, which
included a special emphasis on the company's Permian basin assets and future growth plans.
'Our upstream portfolio leads the industry in quality, breadth and depth. We have the right strategies, always
adhere to a disciplined investment approach, and are constantly managing the portfolio to extract and
maximize value for our shareholders. Our base business is performing exceptionally well and provides us a
substantial, longer-term competitive advantage, driving continued peer-leading financial and operational
performance.'
Jay Johnson, senior vice president, Upstream, provided an overview of Chevron's queue of projects,
exploration assets, and other long-term opportunities. 'Our plan for production growth is solid and will be
driven by near-term project ramp-ups as well as our larger major capital projects which begin starting up
later this year.' Johnson added, 'These projects are attractive, and when combined with profitable production
growth from our shale and tight resource developments, are expected to add over 800,000 barrels of oil
equivalent per day by 2017. We also have a deep queue of other growth opportunities which should allow us
to continue growing production to the end of the decade.'
Mike Wirth, executive vice president, Downstream and Chemicals, reviewed market fundamentals while
highlighting business performance and future growth plans. 'Our strategy is to deliver competitive returns
and grow earnings, including integration opportunities with our upstream business.' Wirth added, 'We have a
focused refining and marketing portfolio with strategically located and competitive assets. Our
petrochemicals business leads its industry, and we continue to target profitable growth opportunities,
primarily in chemicals and lubricants.'
Pat Yarrington, vice president and chief financial officer, highlighted Chevron's continued financial
strength, capital spending outlook, and asset divestment plans. 'Our objective is to reward our shareholders
through both share price appreciation and higher dividends. We've been able to sustain increasing
shareholder distributions and, at the same time, reinvest for future growth. We believe we've balanced these
objectives well, and that our existing portfolio and new investment projects will support continued value
growth for our shareholders,' Yarrington said. Presentations delivered by Watson, Kirkland, Wirth,
Yarrington and Johnson are available on the Investor Relations website at www.chevron.com.

Chevron Corp. expects the firm's production from Asia Pacific to rise around 45 percent to 1,000 million
barrels of oil equivalent per day (MMboepd) in 2017, compared to 690 MMboepd in 2013, the company
said in its presentation to the Security Analyst Meeting Tuesday.
The Gorgon LNG (liquefied natural gas) project off Western Australia is currently 78 percent completed,
with 20 of 21 LNG Train 1 modules delivered and offshore pipelay completed.
Key milestones for Gorgon project, with 6,000 perople now working on the development in Barrow Island,
this year include completion of the LNG loading jetty structure and LNG Tank 1, startup-up of the first
turbine generator and finishing all 18 well completions before first LNG in mid-2015.
Wheatstone LNG project, another Chevron-operated development in Western Australia, is 30 percent
complete. The company indicated that 3,800 people are working at site and development drilling is now
underway. Chevron disclosed that delivery of the first LNG train module, completion of LNG Tank 1
foundation, installation of offshore steel gravity structure as well as installation of a 44-inch trunkline to
plant are key milestones for the project in 2014. First production from the Wheatstone LNG project is
targeted for 2016.

Kazakhstan: CompactGTL announces 3,000 bpd commercial GTL project in
Source: CompactGTL
Ministry of Oil and Gas of the Republic of Kazakhstan and CompactGTL sign breakthrough memorandum
for development of world’s first small scale GTL plant
CompactGTL has announced that its Chairman Tony Hayward and Uzakbay Karabalin, the Minister of Oil
& Gas of the Republic of Kazakhstan, have signed a Memorandum of Co-operation to support the
development and implementation in Kazakhstan of innovative associated gas processing technologies with
the realisation of the world’s first commercially deployed small scale GTL plant.
In furtherance of the Memorandum of Co-operation, signed at the London Stock Exchange during the
Caspian Corridor Conference, CompactGTL intends to build the world’s first commercially deployed small-
scale gas-to-liquids (GTL) plant in Kazakhstan. The proposed plant is expected to bring with it significant
future commercial and environmental benefits. Up to 820,000 cubic metres of associated gas that might
otherwise be wasted will be fed through the plant every day to produce approximately 3,000 bpd of
synthetic diesel. In a year, the plant is expected to monetise over 300 million cubic metres of gas.
Kazakhstan offers considerable potential for CompactGTL’s proven small-scale GTL technology.
Kazakhstan is a major producer of oil and is also one of the leaders globally in seeking to use new
technology to bring environmental benefits to the country. The new GTL plant will contribute to President
Nazarbayev’s 'Strategy of innovative development of Kazakhstan until 2020' by creating a local high
technology industry that processes associated gas to produce fuels for local consumption. CompactGTL,
together with investors from Kazakhstan, have agreed to finance, design and build the up to 3,000 bpd GTL
plant, using CompactGTL’s proven technology and plant design.
Kanatbek Safinov, Executive Secretary, Ministry of Oil and Gas of the Republic of Kazakhstan said:
'Kazakhstan is very interested in attracting innovative and high technology businesses into its oil and gas
industry in order to implement the decision of the President of Kazakhstan to expedite industrial
development of the country. I believe that this innovative project will both help solve a number of social and
environmental issues in the Republic of Kazakhstan and be mutually commercially beneficial for the
parties.'

Tony Hayward, Chairman of CompactGTL said:
'We are very pleased to be able to announce the decision to build the first small-scale commercial GTL
plant. This is a significant step forward, not just for CompactGTL, but also for the small-scale gas-to-liquids
industry. Kazakhstan has clearly identified the significant economic benefits a small scale GTL plant can
bring. We welcome the support provided by the Kazakhstan Government and the signing of this
Memorandum of Co-operation demonstrates the confidence of the Kazakhstan Government and of the
Kazkhstani investors in CompactGTL’s technology and people.'
CompactGTL expects to have a fully functioning small-scale GTL plant in operation in 2017. It is expected
that initial engineering will take approximately 12 months, followed by a construction period of around two
years, highlighting the relative speed with which such a project can be delivered.
CompactGTL offers a unique end-to-end engineering, manufacturing and project execution capability.
CompactGTL is the only provider of small-scale GTL technology with a fully operable demonstration plant,
which it has built in partnership with Petrobras. The successful operation of the Commercial Demonstration
Plant in Aracaju, Brazil and the continuing operations at its UK Pilot Plant and Training facility in Wilton,
Teesside, have proven the key commercial viability and technical benefits of the technology, including
safety, robustness, operability and reliability.

NewBase Comments & Research “ About GTL Technologies “
Compact GTL has developed a small, modular gas-to-liquids (GTL) system that converts associated
natural gas into synthetic crude oil (syncrude). The technology, which shares its trade name with that of the
company, features both stages of the GTL process. First, the unit feeds associated gas through a steam
methane reformer to produce synthetic natural gas (syngas). Next, the syngas runs through a Fischer-
Tropsch (FT) reactor that converts the feedstock into synthetic crude oil, water and a "tail gas" comprising
hydrogen, carbon monoxide and light hydrocarbon gases.
Compact GTL
"The technology effectively provides a disposal route for problematic associated gas that has no value to
the operator and may even have a negative value in some scenarios," . "Importantly, because the gas is
converted to syncrude the solution also provides for an immediate increase in project net present value
(NPV) because the gas can now be booked as liquid reserves."
CompactGTL estimates the unit could produce as much as 5,000 barrels of syncrude per day from
associated gas. Moreover, the company contends the elimination of flaring would yield a direct positive
impact on a development's environmental footprint. Also, the technology could serve as an antidote to
stricter governmental regulations.
"For currently producing oilfields where regulatory changes such as introduction of flaring constraints are
limiting production, it gives the operator a solution that can yield additional commercial benefits,"
A Different GTL Focus
GTL is certainly not a new concept. Shell and Qatar Petroleum (QP) have built the Pearl GTL facility in
Qatar. The plant, which happens to be the world's largest GTL facility, can produce 120,000 barrels of oil
equivalent per day of natural gas liquids and ethane. Shell also has confirmed that it is exploring possible
GTL projects in the U.S.
Another company that has been a leader in advancing GTL projects is Sasol. The South African company,
in a joint venture with QP, has built the ORYX GTL facility in Qatar. In addition, Sasol and Petronas are

collaborating with Uzbekneftegaz to build a GTL plant in Uzbekistan. In North America, Sasol is
considering building a GTL facility in Lake Charles, La. Also, Chevron and Nigerian National
Petroleum Corp. have been collaborating on the Escravos GTL project to mitigate flaring in
Nigeria.
What the above GTL projects have in common is that they are designed to monetize natural gas
resources by producing high-end petroleum distillate products and directly marketing them to fuel
retailers, refineries and petrochemical complexes. Moreover, conventional GTL plants are large
industrial facilities. CompactGTL is trying to carve out a niche for itself to meet a separate industry
need that conventional GTL installations cannot satisfy.
World-scale GTL technology is long established on a commercial footing. However, the
current plant design and economic basis is severely limited and impossible to replicate
where gas volumes are small, in offshore environments and in remote locations. This is
where the modular CompactGTL solution comes into its own, being flexible enough to
deploy in these challenging environments but also economically robust when subjected to
oilfield development economic appraisal.
It is a solution that enables the development of oilfields that may not otherwise be economically
viable due to the presence of problematic associated gas, continued Saul. "In this perspective it is
radically different from conventional GTL technology which seeks to derive economies of scale
from the exploitation of natural gas reserves and then adds value."
The modular design of the GTL units is key to complementing the typical production of an oilfield
and providing the necessary adaptability for remote and offshore environments.
"This is one aspect that differentiates CompactGTL in the marketplace," "Over time, the
associated gas production will decline along with the oil production. The modular nature of the
CompactGTL plant gives the flexibility to scale down the reactor modules in response to the
production decline."
Interest in GTL has increased in recent years, especially in the wake of the American shale
revolution which has led to a huge increase in US gas output. GTL has been seen as a way of
harnessing cheap, plentiful supplies of gas and turning it into much more valuable oil.
But there is also interest in small modular plants able to exploit the unwanted gas which is a
byproduct of oil extraction and which is normally flared or burnt off into the atmosphere.
CompactGTL is developing such small units, which can be incorporated into existing onshore and
offshore oil operations or deployed in remote locations where a large-scale conversion plant would
be impracticable.
It is working with Petrobras, the Brazilian oil major, on the world’s first fully integrated small-scale
GTL facility, which will have capacity of some 200,000 barrels a day. But the company still has no
revenues. Other big names are being drawn into the GTL sector. Roman Abramovich, the
billionaire owner of Chelsea Football Club, last year invested £5m in another pioneering GTL
company, Velocys.

Energean JV awarded Katakolon Block in Greece's Open Door bid round
Source: Energean Oil & Gas
Hellenic Hydrocarbons Management Committee successfully completed its work regarding the evaluation
of the bids for the exploration and exploitation of hydrocarbons for the Katakolon Block. Katakolon was the
third region in Western Greece included in the Open Door bid round, launched by the Greek Ministry of
Energy, Environment and Climate Change on January 2nd, 2012. According to the Committee’s
recommendation to Minister Yiannis Maniatis, the consortium of Energean Oil& Gas / Trajan Oil & Gas /
Schlumberger is awarded the offshore block of Katakolon.
The Commission further
negotiated with the prospect
contractors on the improvement
of the initially submitted work
program and on the complete
exploration of the area, the
acquisition of upgraded data,
the identification and
development of all possible
targets of interest, as well as the
improvement of all financial
terms (except taxation) included
in the bid offer that contribute
to the benefit of the Greek state,
such as royalties and fees for
the Greek state, signature bonus
and annual expenses for
personnel training.
About Enregean Oil & Gas :-
Energean is the only operator of Oil and Gas in Greece
operating the development areas of Prinos and South
Kavala, where it holds a 100% interest. The
Company’s oil and gas assets have been in production
since 1977 through a system of three offshore oil
platforms, one gas platform and a comprehensive
onshore plant with 500,000 bbls of crude oil storage
capacity, offshore loading facilities, de-sulphurisation
and 17 MW power generation facilities.
Through its subsidiary in Egypt (Aegean Energy (Egypt)
Limited) Energean Oil & Gas holds two exploration
licenses (PSA) and operates two blocks in the Gulf of
Suez and in Upper Egypt. The company has a 6 year
off take agreement with BP, while Third Point LLC is
Energean’s strategic financial partner and largest
shareholder, controlling 44.5% of the issued share
capital of Energean Group. Third Point is a US fund
with more than $12 billion under management.
Mathios RigasChairman & CEO – Director .

Repsol Restarts Production at Libyan Oil Field
by Reuters
Spanish oil major Repsol said on Tuesday it had restarted production at its Libyan oil field after the
complex was shut down around a month ago due to clashes with protestors. "Production restarted on
Sunday, although it's still not back to full capacity," said a Repsol spokesman.
Libya's 340,000 barrels-per-day El Sharara oil field, owned and operated by Repsol, located in the remote
south of the country, has been repeatedly closed by armed groups and protestors as a way to pressure
Libya's weak central government into political and financial demands.
Disruption in Libya contributed to Repsol posting a loss last month in its results for the past year. The
country accounts for around 12 percent of Repsol's total output. Analysts estimate the shutdown of the oil
field cost Repsol some 30 million euros ($42 million), or 1 million euros per day in net profit.
Three years of turmoil since the overthrow of Muammar Gaddafi and tough contract terms have prompted
some oil companies to reassess their positions in Libya and several have said they would postpone
projects or scrap them altogether.

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Your partner in Energy Services
Khaled Malallah Al Awadi,
MSc. & BSc. Mechanical Engineering (HON), USA
ASME member since 1995
Emarat member since 1990
Energy Services & Consultants
Mobile : +97150-4822502
khalid_malallah@emarat.ae
khdmohd@hotmail.com
Khaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 yearsKhaled Al Awadi is a UAE National with a total of 24 years of experience in theof experience in theof experience in theof experience in the Oil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working as
Technical Affairs Specialist for Emirates General PTechnical Affairs Specialist for Emirates General PTechnical Affairs Specialist for Emirates General PTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation foretroleum Corp. “Emarat“ with external voluntary Energy consultation foretroleum Corp. “Emarat“ with external voluntary Energy consultation foretroleum 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 Operationsthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operationsthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operationsthe 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 NManager in Emarat , responsible for Emarat Gas Pipeline NManager in Emarat , responsible for Emarat Gas Pipeline NManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developedetwork Facility & gas compressor stations . Through the years , he has developedetwork Facility & gas compressor stations . Through the years , he has developedetwork Facility & gas compressor stations . Through the years , he has developed
great experiences in the designing & constructinggreat experiences in the designing & constructinggreat experiences in the designing & constructinggreat experiences in the designing & constructing of gas pipelines, gas metering & regulating stations and in the engineering of supplyof gas pipelines, gas metering & regulating stations and in the engineering of supplyof gas pipelines, gas metering & regulating stations and in the engineering of supplyof gas pipelines, gas metering & regulating stations and in the engineering of supply
routes. Many years were spent draftinroutes. Many years were spent draftinroutes. Many years were spent draftinroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs forg, & compiling gas transportation , operation & maintenance agreements along with many MOUs forg, & compiling gas transportation , operation & maintenance agreements along with many MOUs forg, & 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 andthe local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andthe local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andthe local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcastedEnergy program broadcastedEnergy program broadcastedEnergy program broadcasted
internationally , viainternationally , viainternationally , viainternationally , via GCC leading satelliteGCC leading satelliteGCC leading satelliteGCC leading satellite ChannelsChannelsChannelsChannels ....
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NewBase 12 March 2014 K. Al Awadi

New base special 12 march 2014

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New base special 12 march 2014