new base special 06 march 2014

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NewBase 06 March 2014 Khaled Al Awadi

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UAE to help boost India’s 5.03 MMT strategic crude oil storage By Binsal Abdul Kader, Gulf News Staff Reporter

A UAE move will boost India’s ambitious project of establishing 5.03 million metric tonnes (MMT) strategic crude oil storages, a top Indian diplomat told Gulf News on Wednesday. The UAE’s commitment has come at the right time as the first part of the Rs24 billion (Dh 1.43 billion) project has been completed recently, T. P Seetharam, the Indian Ambassador to the UAE, said.

As Gulf News reported on Tuesday, India and the UAE agreed to cooperate for setting up a strategic petroleum reserve in Asia’s third largest economy, in a bid to further strengthen economic relations. This was discussed at the second meeting of India-UAE High Level Joint Task Force (HJTF) on Investment in Mumbai in India on Monday.

“Discussions were held on supporting the establishment of a strategic petroleum reserve in India in a manner serving the common strategic interests of both countries and based on the principles of long term strategic partnership and cooperation,” said a statement issued after the meeting. About the meeting’s decision to form a joint working group for this purpose, the envoy said both government and private sector representatives are expected to be included in the group.

Already six working groups on various sectors are functioning, which were formed in the first HJTF meeting held in Abu Dhabi in February 2003. Seetharam said India has already ratified Bilateral Investment Promotion and Protection Agreement (BIPPA) that was signed by both nations in December 2013, which serves as a platform for promotion and reciprocal legal protection of investments in both countries. The UAE is expected to ratify it soon.

He said the decision on petroleum reserve in India will benefit both nations’ energy security. India decided to set up the strategic crude oil storages at three locations in South India — Visakhapatnam, Mangalore and Padur (near Udupi) — to ensure energy security.

These strategic storages would be in addition to India’s existing storages of crude oil and petroleum products with the oil companies and would serve as a cushion in response to external supply disruptions, according to Indian Strategic Petroleum Reserves Limited (ISPRL), a Special Purpose Vehicle, owned by India’s Oil Industry Development Board (OIDB).

ISRL manages the construction of the strategic storage facilities, which are in underground rock caverns on the east and west coasts so that they are readily accessible to the refining sector. Underground rock caverns are considered the safest means of storing hydrocarbons .

oil storage - India




The first part of Vishakhapatanam project has been completed recently and the rest will be commissioned soon. Mangalore project is expected to be ready by the end of this year. Padur project will also be completed soon.

About : INDIAN STRATEGIC PETROLEUM RESERVES LTD. (ISPRL).

To ensure energy security, the Government of India has decided to set up 5 million metric tons (MMT) strategic crude oil storages at three locations namely, Visakhapatnam, Mangalore and Padur (near Udupi). These strategic storages would be in addition to the existing storages of crude oil and petroleum products with the oil companies and would serve as a cushion in response to

external supply disruptions. The construction of the proposed strategic storage facilities is being managed by Indian Strategic Petroleum Reserves Limited (ISPRL), a Special Purpose Vehicle, owned by Oil Industry Development Board (OIDB).

The proposed storages would be in underground rock caverns on the east and west coasts so that

they are readily accessible to the refining sector. Underground rock caverns are considered the safest means of storing hydrocarbons. The estimated cost of the project was around Rs.2400 crore at September 2005 prices. This excludes the cost of filling the crude oil in the caverns. Approval for the Revised Cost Estimate (RCE) for the Visakhapatnam project was obtained from the government in June 2011. Approval was also obtained for increase in the capacity at Visakhapatnam to 1.33 MMT and sharing a 0.3 MMT compartment with Hindustan Petroleum Corporation Limited on proportional cost sharing

basis. With this approval, the strategic storage capacity would be 5.03 MMT. Approval for RCE of Mangalore and Padur projects is being obtained. The capital cost of constructing the strategic storage reserve at current prices is

expected to increase by approx 65 to 70% over the 2005 prices. ISPRL will have ownership and control of the crude oil inventories and will coordinate the release and replenishment of Crude Oil Stock during supply disruptions through an Empowered Committee to be constituted by the Government of India .




Mega construction projects in Oman drive demand for cement byA. E. James , Times of Oman

Oman's cement demand is projected to grow at an annual rate of 6 per cent for the next four years, thanks

to a surge in demand for the product driven by mega infrastructure projects and tourism ventures.

The country's long-term plans and initiatives to develop transport infrastructure, tourism facilities and

industrial zones will provide the required stimulus for the continuing growth of the cement industry.

"Hence according to industry sources, cement demand in Oman is expected to rise in line with that in the

region, at an average annual rate of six per cent through 2016," said a research report released by Al Maha

Financial Service here

The value of contracts awarded across the sectors is expected to double from an estimated OMR2.6 billion

last year to about OMR4.88 billion in 2014, according to industry reports. With a rise in the number and

scale of construction projects in the Sultanate and the region, demand for cement is expected to grow at

the same pace .

7.2m tonne capacity

A bulk of the cement demand is met by the two major local players — Raysut Cement Company and Oman

Cement Company — which have a combined annual clinker production capacity of six million tonnes and

cement production capacity of 7.2 million tonnes. Besides the local companies, a chunk of the domestic

demand is met by foreign players which currently account for nearly two million tonnes of cement sales in

Oman.The two companies last year recorded a combined sales volume of 5.8 million tonnes at an average

realisation of OMR24.99 per tonne

Al Maha said that the local cement producers have been operating at optimum capacities to meet the local

cement demand and achieve maximum efficiency in order to compete with the foreign producers. "The

two companies operate at a utilisation of 80 per cent of their total 7.2 million tonne annual capacity,

producing 5.8 million tonnes of cement last year," noted the report

In 2011, the cement capacity almost doubled as the two companies added additional capacities and also as

Raysut Cement acquired Pioneer Cement in the UAE. However, due to the planned up-gradation and

modernisation efforts as well as some temporary shutdowns, the combined utilisation of the two

companies stood at 69 per cent in 2011. "As the cement demand improves and the plant up-gradation and




ExxonMobil to start production at new oil and gas projects in 2014 Source: ExxonMobil

ExxonMobil expects to start production at a record 10 major projects in 2014, adding new capacity of approximately 300,000 net oil equivalent barrels per day and contributing to profitable production growth, Rex W. Tillerson, chairman and chief executive officer, said Wednesday.

'These projects exemplify our focus on maintaining a diversified portfolio and highlight our ability to grow profitable volumes,' Tillerson said at the company’s annual investment analyst meeting at the New York Stock Exchange. 'We are adding new volumes that improve our profitability mix with higher liquids and liquids linked natural gas volumes. We’re also driving increased unit profitability

through better fiscal terms and reducing low-margin barrel production.'

ExxonMobil’s capital spending will decline to $39.8 billion this year from a peak of $42.5 billion in 2013, Tillerson said. Excluding potential acquisitions, capital expenditures are expected to average less than $37 billion per year from 2015 to 2017.

'We have financial flexibility to pursue potential strategic opportunities and maintain a disciplined and selective approach to capital that ensures any new investment will contribute to robust cash flow growth,' Tillerson said.

A liquefied natural gas project in Papua New Guinea and the largest offshore oil and gas platform in Russia are among significant projects scheduled for startup this year. Others include a heavy oil expansion project in Canada and deepwater projects in the Gulf of Mexico.

ExxonMobil anticipates additional project startups in the next few years in several countries, including Australia, Indonesia, Canada, Nigeria and the United States. All of these projects are expected to add about 1 million net oil equivalent barrels per day by 2017. In North America, ExxonMobil’s near-term production outlook is made up of significant high-margin, low-risk liquids growth. The company’s production outlook also reflects strategic choices made to improve unit profitability while maintaining disciplined capital allocation. 'We have a balanced and diversified portfolio that gives us a fundamental competitive advantage,' Tillerson said. 'Resource and geographic diversity across the portfolio enables us to mitigate risks in a dynamic market environment and maximize profitability through changing business cycles.'

Papua New Guinea LNG Project For ExxonMobil Sakhalin II , Russia




The company is pursuing more than 120 high-quality projects to develop about 24 billion oil equivalent barrels of oil and natural gas.

ExxonMobil’s Downstream and Chemical businesses are focused on strengthening the portfolio and delivering sustained, industry-leading financial performance across the business cycle. Midstream investments in North America will expand ExxonMobil’s logistics capabilities to transport crude oil and finished products. Other advantaged projects will increase production of high-value products.

'In the Downstream and Chemical segments, we are diversifying feedstocks through our flexible and integrated system, continuously pursuing operating efficiencies and maximizing sales of higher-margin lubes, diesel and chemical products,' Tillerson said.

During the meeting, ExxonMobil reviewed its 2013 performance and outlined future plans. Highlights include:

• For the 20th-consecutive year, ExxonMobil replaced more than 100 percent of production. In 2013, the

company added proved oil and gas reserves totaling 1.6 billion oil-equivalent barrels, including a 153

percent replacement ratio for crude oil and other liquids. At yearend 2013, proved reserves totaled 25.2

billion oil equivalent barrels, comprised of 53 percent liquids and 47 percent natural gas.

• ExxonMobil continues to outpace competitors in return on average capital employed at 17.2 percent in

2013, about three-and-a-half percentage points higher than its nearest competitor.

• Liquids production is expected to grow 2 percent in 2014 and 4 percent annually from 2015 to 2017,

representing the majority of ExxonMobil’s total production increase.

• Liquids and liquids linked natural gas are projected to account for 69 percent of the company’s total

production by 2017, improving the profitability mix of the portfolio.

• ExxonMobil is pursuing investment opportunities to expand its Chemical business and serve major growth

markets. These projects build on unmatched integration with the Upstream and Downstream operations

and employ proprietary technologies to increase high-value product sales.




UK: TAQA restarts production at North Sea Harding platform Source: TAQA / energy-pedia

TAQA has confirmed that production has now been restarted at the TAQA-operated Harding platform, located 320 kms north-east of Aberdeen in the UK North Sea. The platform is being up-manned for routine

operations. The platform was shut down on Feb 27 after a 62-year old man fell to his death during maintenance work. The man was rescued and airlifted to hospital where he later died.

TAQA owns a 70 percent stake in the Harding platform, whilst Maersk holds 30 percent. Crude oil retrieved via the platform is

transported from a submerged loading facility, unlike some other platforms which are directly connected to the mainland via pipeline. The platform started operating in 1996 and has a daily production rate of 12,000 barrels of oil equivalent.




Chad: Caracal Energy provides update on operations in Chad Source: Caracal Energy

Caracal Energy has provided an update of exploration, development and production operations in the Republic of Chad.

Highlights include:

• Current production increased to 14,200 gross barrels oil per day ('bopd'), from 12,000 bopd as reported on

January 20, 2014;

• Production at the Badila field is continuing from the original three wells with a 15-20% water-cut, in line with

expectations;

• Badila-7 is currently drilling at 1,260 meters and Badila-9 is expected to spud over the next 7 days. Both of

these wells are expected to provide additional production rate capacity;

• Mangara-6 has been completed and testing of the Cretaceous E sands is underway. The comprehensive

completion program is also testing the Cretaceous D and C sands. Mangara-6 is expected to be on

production later this year when the Mangara field is brought on stream;

• Mangara-4 has been successfully side-tracked and cased as a Cretaceous E sands producer;

• The first of the four new drilling rigs contracted in 2014 has arrived at the port in Cameroon, on schedule,

and should be on site in Q2;

• The 2014 exploration program is underway in the Kibea - Beche area, where 3D seismic is nearing

completion; and

• The Company's first oil sales tanker lifting is now expected before the end of March 2014.

Gary Guidry, Chief Executive Officer, said:

'We are making good progress maximizing throughput at our Badila production facilities, and we are on schedule to expand the fluid handling capacity at Badlia later this summer. In addition, we are nearing completion of the production facilities at Mangara and the pipeline connecting Mangara to Badila, and we are looking forward to having the Mangara field on stream later this year.

'An exciting milestone will be moving a drilling rig to the Kibea - Beche area in the next two months, kicking off our 2014 high impact exploration program where we plan to test approximately one billion barrels in gross unrisked 'Prospective Resources.'

Caracal Energy's Chad assets




Production

With Badila-6 now on stream, current production is 14,200 bopd, up from 12,000 bopd in January and in line with the Company's expectations for the period and the Company's guidance of 22,000 to 26,000 bopd annual average 2014 production. Production from the Badila field has been stable since the commissioning of the facilities was completed in December 2013, with oil production, water production and well pressure consistent with forecasts.

Badila processing capacity, previously constrained to 14,000 barrels of fluid per day (bfpd) has now been expanded to 25,000 bfpd with the completion of the southern processing terminal (SPT). The SPT will

handle excess Badila production until expansion of the Badila facilities is completed, which is expected during the third quarter of 2014. Water rates, relative to total fluid from the Badila field, are stable between 15 and 20%, in line with expectations. Production from the Badila field has been increasing since the commissioning of these facilities was completed in December 2013.

Operations at Badila currently include the drilling of Badila-7 with rig GWD-96, and preparations to spud Badila-9 with rig GWD-158. The GWD-158 rig is capable of deep drilling and once Badila-9 drilling is finished, will be move it to the Kibea - Beche area for a continuous spring/summer exploration drilling program. GWD-96 will continue in the Badila field, drilling Badila wells for additional production rate capacity.

Oil Sales

The Company's line fill contribution was completed in January 2014 and additional production accumulated as inventory. The sale of the Company's inaugural cargo from the Kribi sales terminal is committed, with the lifting scheduled for the latter part of March 2014. Tanker liftings are typically between 900,000 and 1,000,000 barrels of oil. The Company will jointly lift with its partner, GlencoreXstrata (therefore, approx. 560,000 barrels of oil will be net to the Company).

The Kribi Seaport on the

coast of southern Cameroon

is destined to become a

mega harbour to serve all of

Central Africa.




Exploration and Development: Drilling Operations

The Company has commenced the mobilization process of an additional four drilling rigs, which will bring the total rig count to six drilling rigs by the end of 2014. In addition, two completion rigs will be mobilized into country during 2014, to bring the total completion rig count to three. One of these new completion rigs also has the ability to drill medium depth wells.

The first of the four additional drilling rigs has arrived in the port of Douala, Cameroon. It is scheduled to arrive in Chad and commence drilling during the second quarter of 2014.

Bitanda: Exploration Well

The Company has plans to test the Bitanda exploration well in the coming months. Currently, the workover/completions rig remains in Mangara, testing and completing Mangara-6.

Kibea and Beche: Seismic Acquisition and Drilling

The Company has mobilized a seismic contractor to shoot 2D and 3D seismic throughout its asset base in Chad. Much of the planned 1,500 line-kms of 2D seismic is completed and was focused on well placement for structures to be drilled in the 2014-2016 exploration programs as well as further evaluation of additional prospects currently not included in the Company's estimates.

Of the 700 sq km planned for 2014, 450 Km2 will be focused on the Kibea discovery and nearby Beche

exploration area, which includes three prospects with similar structures to the discovery at Kibea. Currently, the seismic has been shot over the Kibea field and nearly competed over the Beche area. Preliminary processing indicates that the seismic acquired is of excellent quality. The three prospects in the Beche exploration area are assessed 420 million barrels of Pmean unrisked gross recoverable Prospective Resource in aggregate, according to the McDaniel Resource Report.1 Kibea is a light oil discovery (33 - 35 degrees API) with 45.9 million barrels of gross 2P reserves, and 105.0 million barrels of gross 3P reserves according to the McDaniel Reserves Report.

The first well, Kibea-2, scheduled for the second quarter of 2014, in the Kibea - Beche trend will be an appraisal and deep test on the Kibea structure. The Kibea-2 well will provide a test of deep Cretaceous potential identified on prior 2D well data acquired on Kibea-1 and the new 3D seismic. According to the McDaniel Resource Report, gross unrisked prospective resources below in the Kibea discovery are 40.1-76.9 million barrels on Pmean and P10 basis, respectively. In addition, oil samples to be acquired during testing of existing discovered reservoirs in Kibea-2 will provide development and pipeline design information. Drilling two of the three Beche exploration prospects is expected to commence in Q3 2014, once Kibea-2 is tested.




UMW Petrodril to Supply Hydraulic Workover Unit Rig to Petronas Carigali by Rigzone Staff

UMW Oil & Gas Corporation Berhad (UMWOG) reported Tuesday that UMW Petrodril (Malaysia) Sdn Bhd (UPD) a wholly owned unit of UMW Malaysian Ventures Sdn Bhd has won a contract to supply a Hydraulic Workover Unit (HWU) Rig to Petronas Carigali Sdn Bhd in Malaysia, the firm said in an announcement on Bursa Malaysia.

The contract, valued at $45.2 million (MYR 148 million), also includes the provision of an Accommodation Work Barge and a Portable Crane for an initial period of two years.

The contract with UPD, in which Petronas Carigali has the option of extending for a further year, is intended to support the Malaysian upstream company's Workover Programme. UMW Malaysian Ventures is a wholly owned subsidiary of UMWOG.

About Petronas Carigali Sdn Bhd in Malaysia :-

A subsidiary PETRONAS exploration and production (E&P), PETRONAS Carigali Sdn Bhd,

have developed capability as a hands-on operator with a track record of successful oil and

gas developments. PETRONAS Carigali works alongside

a number of petroleum multinational corporations

through production sharing contracts (PSCs) to

explore, develop and produce oil and gas in Malaysia.

Abroad, we continue to strengthen our position by

securing new acreages while undertaking various

development projects. The Petroleum Management

Unit (PMU) of PETRONAS acts as resource owner and

manager of Malaysia’s domestic oil and gas assets. It

manages the optimal exploitation of hydrocarbon resources and enhances the prospectivity of

domestic acreages to attract investment and protect the national interest. One of the key

drivers of our business growth is deepwater E&P, with many positive prospects emerging in

Malaysian acreagesWe continue to harness and develop new technologies to maximise

opportunities and further strengthen our capabilities in our efforts to become a leading global

E&P .




Saudi Aramco hires McDermott for subsea cable installation http://www.offshoreenergytoday.com/saudi-aramco-hires-mcdermott-for-subsea-cable-installation/

McDermott International, Inc. has been awarded a substantial contract to provide the electrical power supply system for Saudi Aramco in the Abu Ali and Khursaniyah fields in the Arabian Gulf. This contract is included in McDermott’s fourth quarter 2013 backlog. The project includes the procurement, construction,

and installation of two 20-kilometer 230 kV subsea circuits routed offshore to connect land based facilities. The cables weigh approximately 95 kilograms per meter

“The subsea cables for

this project are some of

the largest ever

transported and

installed in the Arabian

Gulf,” said David Dickson, President and Chief Executive Officer. “We successfully completed another

similar 230-kV cable installation project in similar conditions earlier this year. This gave us a unique

insight into the project execution requirements

for such complex installation work, and we are

pleased that Saudi Aramco has shown repeat

confidence in us with this award.”

According to a press release issued by McDermott, installing cables of such magnitude in extremely shallow water presents a variety of complex challenges. Technical modifications to an installation barge in the McDermott fleet enable it to lay the cable in extremely shallow water. Project completion, including hookup and commissioning, is expected to be in the third quarter of 2015.

About Submarine cables up to 320 kV DC

HVDC extruded submarine cables are among the fastest growing product lines in ABB`s high-voltage

cable portfolio. HVDC extruded submarine cables have a compact conductor made of copper or

aluminum, depending on electrical and/or mechanical requirements. The first-

choice insulation material for submarine cables is cross-linked polyethylene

(XLPE). In addition, a sheathed and armored layer is needed to meet the exacting

requirements of harsh offshore installation and service. ABB high-voltage cables

are single-armored for moderate depths, and double-armored for extreme depths.

These single-core cables can be installed either separately or in a bundled

configuration.




Watson: US Should Move Forward with LNG, Crude Exports by Karen Boman , Rigzone Staff

Chevron CEO John Watson says US should move forward with exporting oil and LNG, noting that

debate on free trade benefits won "long ago".

Chevron Corp. Chairman and CEO John Watson said the United States should get on with exporting oil and liquefied natural gas, saying that U.S. consumers and allies of the United States would benefit.

“The debate over the benefits of free trade was won a long time ago,” Watson told attendees at the IHS CERAWeek conference Tuesday in Houston, noting the role that free trade has played in facilitating economic growth. The benefits of export and free trade pose a “very straightforward, economic argument for consumers and the nation,” Watson commented.

While the controversy over exports of liquefied natural gas (LNG) from the United States has subsided from a year ago, the timing of U.S. and Canadian LNG export projects moving forward remains to be seen. Watson expects to see significant growth of LNG projects from the U.S. Gulf Coast and Canada’s West Coast.

“There’s no question that sufficient gas exists in the U.S. and Canada to export globally,” Watson said, noting that he sees a good market ahead for LNG demand past the 2020 to 2025 timeframe.

Watson sees the resources and desire by the Canadian government to move LNG projects forward. Watson also sees brownfield LNG export facilities moving forward quickly, but full-site development of greenfield LNG projects will be more expensive. While Watson sees demand for these projects and other opportunities around the world, robust pricing will be needed for projects to work.

“We need a meeting of minds for LNG project development,” Watson commented.

Hiring and retaining talent will pose an issue as a generation of workers who cut their teeth in the 1970s and 1980s retire and the industry accelerates training and development to cope with the talent shortfall. Watson sees the demand for jobs in the industry as a “wonderful chance” for the United States, where people are still in need of jobs.

The United States’ potential role as an energy exporter comes as the oil and gas industry, world governments, energy industry partners and global consumers face the dawn of a new energy reality brought on by global economic growth, Watson told attendees. Over the past decade, the world added another United States in terms of gross domestic product growth, with much of that growth occurring in the developing world. This growth has allowed more people to move into the middle class, and increased demand for goods, services and energy, Watson said.

“$100 a barrel is the new $20 in our business,” Watson said of that new reality.

While investment in oil and gas exploration and production has increased to meet this global demand, upstream costs have more than doubled over the past decade. Higher energy demand, investment and costs are part of the new “energy reality” that energy companies, governments,




service partners and consumers face.

“If companies are saying no to development projects because of costs, we’re getting close to equilibrium,” Watson said. “When host countries respond by changing terms and being more receptive, that’s a sign of a new reality to me.”

Another new reality is that the projects that industry will pursue to meet demand are bigger, more complex and face longer lead times. With a cost squeeze facing many in the industry, the marginal barrel is coming from more expensive sources.

“The new reality is that costs have caught up with revenues,” said Watson, who also expects the trend of tightening capacity in services to continue.

Chevron can afford to be choosy with the projects it pursues, and is slowing development of some projects to ensure it has the cost equation balanced well. Chevron will still pursue development of the Rosebank development in the UK North Sea, but will recycle the project until it can bring costs down, Watson noted.

Resource-rich countries also see they need competitive fiscal terms to attract capital and investment. “There’s no shortages of resources,” said Watson, adding that Chevron can now operate in more countries today than in all of Watson’s time with the company.

However, restraints remain above the ground on oil and gas investment in some parts of the world. Watson said he was glad to see Mexico and Argentina improving their fiscal terms to attract investment, noting that Chevron would not have invested $80 billion in Australia if the country didn’t have a stable government and policies.

“The new reality for consuming governments is that the conditions and fiscal terms have to be right to attract investment,” said Watson. These include transparency, a straightforward permitting process, and a tax environment conducive for investment.

In the new reality, the consumer is the ultimate party that has an interest in energy policies, given




that energy will be more expensive, Watson said. In this reality, subsidies for energy resources are not sustainable indefinitely. Germany and the UK have rolled back subsidies, and Indonesia had to raise prices for its consumers to reduce costly government subsidies.

Pointing to the growing income disparity in the United States, Watson said that many energy policies actually promote income disparity. While the wealthy can afford to pay more for energy, the poor bear the greatest burden of energy subsidies.

Watson expects more growth in the world economy and more people moving into the middle class as a result of free trade and economic policy. Meeting this energy demand will require development of all forms of energy.

“We have the geology, the technological know-how to develop the world’s resources,” said Watson. “We just need to get all the policies right above ground so we can invest and meet the needs of a growing world,”

Watson said the industry was caught by surprise in terms of infrastructure to support its needs, noting that industry needs to respond more collaboratively and work with suppliers and service companies in terms of building capacity to operate at sustained levels. The oil and gas industry also faces a challenge from the significant pressure on labor availability for the petrochemical, LNG and traditional oil and gas projects – and projects in other industries – in areas such as the U.S. Gulf Coast.

Watson said the industry has come a long way in its understanding of shale plays, but still does not yet know how far it can go in terms of liquids production. Chevron has had success in the Marcellus shale play in Pennsylvania, the Permian Basin in West Texas, and western Canada’s Duvernay play. The company also has recently entered Argentina. Other less mature plays in China and central Europe are in the early stages of development.

Watson remains bullish on energy growth in Asian countries, noting that the pace of economic development that will lift more people out of poverty is a good thing to see. However, these countries will need to make decisions on policies on energy issues, such as the move towards using cleaner sources of energy. Watson said it would be interesting to see how China addresses pollution in the country.




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

[email protected]

[email protected]

Khaled Al Awadi is a UAE NaKhaled Al Awadi is a UAE NaKhaled Al Awadi is a UAE NaKhaled Al Awadi is a UAE National with a total of 24 yearstional with a total of 24 yearstional with a total of 24 yearstional with a total of 24 years of experience in theof experience in theof experience in theof experience in the Oil & Gas sector. Currently working as Oil & Gas sector. Currently working as Oil & Gas sector. Currently working as Oil & Gas sector. Currently working as

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the GCC area via Hawk Energy Servicthe GCC area via Hawk Energy Servicthe GCC area via Hawk Energy Servicthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations e as a UAE operations base , Most of the experience were spent as the Gas Operations e as a UAE operations base , Most of the experience were spent as the Gas Operations e as a UAE operations base , Most of the experience were spent as the Gas Operations

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NewBase 06 March 2014 K. Al Awadi

new base special 06 march 2014

Economy & Finance

strategic storages

uae uae

meeting of india

strategic storage facilities

common strategic interests

oil companies

south india visakhapatnam

petroleum products