Dubai plans to reduce energy consumption in buildings by 20% by 2020 through mandatory energy efficiency standards for new buildings. This includes measures like insulation and solar water heating. Dubai Municipality forecasts that the amount of floor space dedicated to green buildings will increase from 54 million sq ft last year to 90 million sq ft in 2016. Separately, Tullow Oil discovered oil and gas condensate at a well off the coast of Mauritania, opening a new oil play in the country. FAR received $5 million from Capricorn Senegal after finalizing a farm-out deal for oil exploration in Senegal.

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NewBase 12 February 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Dubai plans to go greener with 20% reduction in energy consumption
Shereen El Gazzar , www.thenational.ae
Dubai aims to cut energy consumption by 20 per cent by 2020, as it enforces an energy-efficient
building project, a government executive said yesterday.
“Buildings use 70 per cent of the energy that we produce,” said Abdulla Mohammed Rafia, the
assistant director general for engineering and planning at Dubai Municipality. “To get the city
green, you might as well go to the biggest consumer – the buildings, whether residential or
commercial.”
The efficiency programme, called the green building project, was started as an initiative in 2008 by
the Supreme Council of Energy in collaboration with the Dubai Municipality and Dubai Electricity
and Water Authority. In 2011, it became mandatory for all government buildings to adhere to the
programme. However, this year it was extended, requiring all new buildings to be energy-efficient.
“On cost increase it’s only 5 per cent [to have a green building],” said Mr Rafia, adding that in
addition to energy savings, 15 per cent could be cut from water consumption and 20 per cent from
carbon dioxide output. To get a green building certified in Dubai, it has to meet 79 energy-saving
standards. The criteria include measures such as using thermal insulation, using energy-efficient
equipment for air conditioning for instance, and using solar water heaters.
Separately, Mr Rafia said the numbers of green buildings accredited annually in Dubai during the
past five years had fluctuated as the volatile international economic situation affected the
emirate’s property sector. However, Dubai Municipality forecasts the volume and number of
green projects will increase in the future.
“Our forecast shows that in 2016 the permitted area [for green buildings] could reach to 90 million
square feet,” he said. Last year, about 54 million sq ft was earmarked for green buildings.
NewBase comments :-
Unfortunitly the city has forgotten about solar Air Conditioning

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2H Offshore Delivers Tripod Platform Design to Dubai Petroleum
http://www.offshoreenergytoday.com/2h-offshore-delivers-tripod-platform-design-to-dubai-petroleum/
Dubai Petroleum has chosen 2H to deliver an intensive, fast track design of an ultra-
lightweight conductor supported tripod platform.
The tripod platform, known as T-02, has been
successfully installed in the Fateh field, offshore
Dubai in 50m water depth. The platform consists of
a minimal topside and subsea structure and hosts an
exploration well during an upcoming drilling and
well test campaign.
As part of the T-02 platform project, 2H Offshore
investigated a wide range of development options to
facilitate the exploration well for DP before
ultimately proving the conductor supported tripod as
the most economical and technically feasible solution. The tripod is designed for installation from a jack-up
drilling rig, enabling drilling to start directly after installation. Leading the detailed design, 2H Offshore
undertook the structural design of the subsea template, conductors and topside brace structure while liaising
with DP on the access platform and other structural details.
2H’s lead engineer Graham Nicholson said: “We carefully assessed the client’s design brief and developed
a solution that considered the in-service functional requirements as well as the installation constraints. With
the combined knowledge and experience of the DP and 2H teams, we were able to deliver an efficient
design in-line with the client’s demanding fabrication and installation programme.”
Addition by NewBase :-
Dubai's economy that began development on the basis of oil now depends mostly on the non-oil production
that represents over 90 per cent. Dubai's oil reserves, previously expected to run out in 20 years, lie mainly
in four offshore fields. The first oil
field was discovered in 1966 and
the first production was from Fat'h
oilfield in 1969. A second oil field,
Falah, was discovered in 1972 and
production started in 1978. Two
other oilfields — Rashid and
Margham — were discovered in
1973 and 1982 respectively. While
Dubai Petroleum Company is the
main oil operator of these fields,
Dubai Natural Gas Company
processes the emirate's natural gas.
The city imports natural gas from
neighbouring Sharjah to meet the
growing population needs, while
larger resources of Qatar were tapped recently to power industrial projects. Dubai's government signed a 25-
year agreement with Dolphin Energy, a joint venture between UAE and Qatar to import natural gas from the
island-country's massive reserves.

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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 3
Tullow says Mauritania well opens new oil play
Reuters - UK Focus
British explorer Tullow Oil said it found oil and gas-condensate at a key well off the coast of Mauritania, in
a development it described as opening a new oil play in the West African country.
Tullow said on Wednesday
that the Fregate-1 well off
the coast of Mauritania had
encountered up to 30 metres
of gas condensate and oil in
multiple sands.
Analysts had been keenly
awaiting the result of the
well and had said a positive
result would be a major
boost for the company after
a string of disappointing
drilling results last year.
Tullow reported 2013
operating profit of $381
million, a 68 percent fall on
the year before but ahead of
a consensus forecast. The
fall was a result of lower
profits from disposals
compared to 2012 and a
higher exploration write-off,
already flagged in an update
in January.
Tullow has exploration,
development and production
activities across ten offshore
licences. Tullow has significant acreage of over 50,000 sq km extending along 750 km of coastline and
includes the Chinguetti oil field. Chinguetti was the first discovery in Mauritania in 2001 and since then
further discoveries have included Banda in 2002, Pelican and Tiof in 2003, Tevet in 2004 and Faucon in
2005. In January 2011, the successful Cormoran-1 exploration well successfully appraised the Pelican gas
field and discovered two new underlying fields, Cormoran and Petronia.
In October 2011, Tullow announced that it had signed a new exploration PSC, C-10, which replaces the
previous PSC-Area A and B with Tullow taking over operatorship. In June 2012, Tullow signed the new C-
18 exploration licence which covers an area of 13,255 sq km and lies directly west of the existing Block 7
exploration licence that Tullow is a partner in. An exploration campaign commenced in August 2013.
Tullow’s exploration acreage position was further enhanced with the signing of the Production Sharing
Contract (PSC) for the shallow water C3 licence area in April 2013. In 2012, the Banda gas field was
declared commercial and it is planned that the field will supply a power development.

4. Copyright © 2014 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced,
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in this publication. However, no warranty is given to the accuracy of its content . Page 4
FAR Receives $5M for Senegal Farm Out Deal
FAR Ltd has received $5 million from Capricorn Senegal Ltd, a subsidiary of Cairn Energy, in
relation to its Senegal Farm-out deal (following final approvals from the Senegal government).
FAR will be drilling two back to back
wells in Senegal the first of which is
expected to spud in Q1 2014. The receipt of
the US$5 million of cash proceeds
strengthens the Company’s cash position to
AU $29.6 million as at 10 February
2014. FAR announced two major farm-in
agreements in relation to its offshore
Senegal exploration permits with
ConocoPhillips and Cairn Energy (a UK
listed oil and gas company). Both farm-in
agreements have received Senegalese
Ministerial approval.
As a result of the two farm-in deals with ConocoPhillips and Cairn, FAR has secured full funding for its
share of two exploration wells totalling approximately US$200 million (100% basis, FAR estimate) and net
cash payments received of approximately US$10 million. FAR retains a 15% working interest in the
permits. ConocoPhillips and Cairn will hold 35% and 40% respectively. Petrosen, the Senegal National Oil
Company, has a 10% carried interest through this exploration phase.
FAR transferred operatorship of the Senegal blocks to Cairn in August 2013 and well preparations have
progressed satisfactorily. The Transocean owned drilling rig, the Cajun Express, has commenced a multi
joint venture African drilling campaign, operated by Cairn, which includes FAR’s two high impact Senegal
exploration wells. Cairn is currently drilling the second well in the campaign, and FAR’s two Senegal wells
will follow completion of that well.
The two back to back exploration wells, the first of which is expected to start drilling in Q1 2014, will target
approximately 1.5 billion barrels (225 million net to FAR) of unrisked best estimate prospective resources .
With approximately 900 million barrels (135 million net to FAR) to be tested in the deep water ‘fan’ play
and 600 million barrels (90 million net to FAR) to be tested in the ‘shelf play or ‘L’ Prospect.
Both Senegal prospects have significant follow-up drilling potential in the event of a discovery. FAR’s
three contiguous Senegalese blocks – Rufisque, Sangomar and Sangomar Deep – cover 7,490km2. From
2,050km2 of modern 3D seismic data acquired in the blocks, FAR mapped 11 potentially drillable prospects
as well as numerous other leads, many supported by associated seismic amplitude responses in plays
including the ‘fan’ and ‘shelf. FAR has assessed its Senegal blocks to have prospective resources of 3.585
billion barrels of oil (538 million net to FAR)..

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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 5
Iran to export oil & build refinaries in Indonesia
http://www.upstreamonline.com/live/article1351900.ece Bianca Bartucciotto
Iran is set to invest $3 billion in Indonesia and export oil into the country as part of push by Iran to
overcome economic sanctions lifted late last year. Local news sources reported Iran would invest $3 billion
to build oil refineries in West Java and Banten. Deals were
signed at the Indonesia-Iran Business Forum on Tuesday, the
Jakarta Post said. "The deal will require Iran to supply us with
its crude oil before it sells to other countries,” Radjab
reportedly said.
Indonesia – a former Opec member – is struggling to meet
demand for oil, with this contract securing supply from Iran.
Growth in Indonesian oil production was dramatic, peaking in
1977 with 1.6 million barrels per day produced across the
Archipelago. Production peaked in 1995 and has since been on a steady decline.
In 2013, production dropped below 900,000 barrels of oil per day, according to the US Energy Information
Administration. With sanctions on Iran now eased, the countries are free to do business. The refineries will
be built by Kreasindo Resources Indonesia and Iranian Nakhle Barani Pardis. Kreasindo president director
Rudy Radjab reportedly said the companies were carrying out a feasibility study but construction was set to
start in 2015.
NewBase Addition:-
Energy | Challenges in Indonesia’s Oil and Gas Industry
The greatest challenge facing the oil and gas sector is the lack of logistical infrastructure available to
support distribution and commercial exploration. The main production sites are located in areas situated a
substantial distance from the electricity grid network and the main population centres of Java. The
Indonesia Economic Corridors Master Plan to 2025 aims to address this by positioning refineries and
industrial production sites at the sources of primary energy production but this will only materialise in the
long term. PGN operates more than 3,100 miles of gas distribution pipelines made up of 9 networks across
the country with 4 more being added as part of the Integrated Gas Transportation System that would
connect across all the islands. Construction of some parts of the network is being held back due to lack of
funds such as in East Kalimantan. Transport of LNG between the islands requires costly LNG plants to
liquefy the gas and terminals at the destination point to receive it which is not on the priority list for
national infrastructure. It is the lack of connectivity between the islands and primary energy production
centres that keeps transport costs high and thus results in import of other energy sources to meet domestic
needs.
Exploration and incentivising investment are a further challenge considering oil production is declining by
12% each year according to the National Statistics Agency. This is due to the ageing fields such as Minas
and Duri in Sumatra and the decline in exploration from the end of the 1990s in the lead up to the new oil
and gas law of 2001. In gas too, only a third of known gas basins have been explored meaning that
potential reserves could well be the largest in the region. According to BP Migas, out of the 107 oil and gas

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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 6
blocks offered from 2002 to 2008; 77 have yet to begin exploration as per May 2011. While there have been
some new oil discoveries in the past decade in the western part of the country; it is the eastern part of the
country that holds huge potential in deep sea reserves of oil and gas that are costly to explore. Energy
companies face regulatory hurdles, stalled coordination between ministries and local government as well
as an unconducive environment for taking on risky exploration. Difficulties in land acquisition and lack of
government assistance in the process stall energy companies’ plans to move forward with projects, while
land prices continue to increase.
New regulations introduced at the end of 2010 were designed to encourage more investment into the
sector, but provided a mix of both new benefits and disadvantages. Ministerial Regulation No. 6/2010
introduced a 5% tax on transfers of contracts during the exploratory stage thereby penalising companies
trying to share the risk. The ring fencing principle whereby only one Production Sharing Contract may be
issued per business entity is a further hindrance that requires the set up of separate commercial bodies to
take on new blocks. There have been some improvements made to the investment climate such as the
decision to introduce direct bidding as opposed to tendering blocks and the increase in production splits
for companies to 25% for oil and 40% for gas. The abandonment of the proposed $12 billion USD cap on
cost recovery that could be claimed by companies in the exploratory stage was another welcome move by
energy companies looking to bid on new blocks. Uncertainty remains over regulations as discussions by
the House of Representatives were underway in mid 2011 on changes to the Oil and Gas Law No. 22/2001.
Articles undergoing debate include Article 22 Paragraph 1 on the domestic market obligation of 25% of
production as well as Article 12 Paragraph 3 on the term ‘provided with authorisation’ in relation to
working areas given
the current overlap
between the Ministry
of Energy and
Mineral Resources
and other bodies.
Fuel subsidies
continue to plague
the commercial
viability of new
projects for
independent power
producers; such
subsidies cost the
government $5.9 billion in 2010. Investors are therefore required to propose a price that is affordable for
the domestic market for purchase by PLN, which is often an impossible task and renders the project
unworkable due to costs for not only exploration but infrastructure to support exploitation. While the
government aims to remove such subsidies by 2014, it is highly unlikely to happen within that time period
and caveats regarding certain subsidies have already been stated. Revisions to the pricing system and a
braver approach by the government towards the cost of energy for the domestic market are needed to
unleash the potential of unexplored blocks.
Indonesia Oil and Condensate Production Forecast

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in this publication. However, no warranty is given to the accuracy of its content . Page 7
Source: BP World Energy Statistics 2011
Laws & Regulations on Oil and Gas
• Article 33 of the Indonesian Constitution which states that all natural resources must be used for the
welfare and benefit of the Indonesian people. This translates into the government taking a stake in
all oil and gas related activities through Production Sharing Contracts.
• Law No. 22/2001 governs the activities of the oil and gas sector in Indonesia as well as Law 22/2001
that states that BP Migas is the regulatory body for upstream activities in oil and gas such as
exploration and exploitation through Production Sharing Contracts between BP Migas and the
company involved which may be state owned, branch of a foreign company or private local
company. BPH Migas covers the downstream sector such as processing transport and storage
through joint cooperation contracts which are normally PSCs. Foreign companies with a
representative office in the country may engage in both upstream or downstream but cannot be
involved in both areas. The law also states the preference for use of local manpower and expertise in
execution of projects as well as environmental standards that must be met by companies.
Law No. 22/2001
• Energy Law No. 30/2007 requires that the country maintains ‘energy stockpiles’ to mitigate against
shortages and heighten energy security. The law also marked a shift in the country’s attitude

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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 8
towards energy reserves by establishing the National Energy Council aimed at furthering the
exploitation of renewable energy sources and reduce reliance on fossil fuels by 2025.
• Investment Law No 25/2007 and Company Law 40/2007. Companies engaging in oil and gas
activities must be set up as a Permanent Entity and branch of a foreign company. Set up as a
company domiciled in Indonesia is only available for Indonesian companies and investors. As per
the ring fencing principal, business entities may only enter into one PSC and must therefore set up
separate bodies to take on further PSCs. The law also details how dividends may be taken by
business entities by allowing the transfer and repatriation of profits. Capital goods imports of
machinery and equipment for production needs, are subject to exemption of VAT while goods for
production are subject to exemption or postponement of VAT.

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in this publication. However, no warranty is given to the accuracy of its content . Page 9
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 &Oil &Oil &Oil & Gas sector. Currently working asGas sector. Currently working asGas sector. Currently working asGas sector. Currently working as
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Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developedhas developedhas developedhas developed
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