New base special 08 july 2014

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NewBase 08 July 2014 Khaled Al Awadi

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE

Mubadala installs Manora topsides Press Release .

Tap Oil Limited has provided the following update on the Manora oil development in the

Northern Gulf of Thailand (TAP 30% interest).

Mubadala Petroleum, the operator of the Manora joint venture, continues to advise that the development is on schedule for start of production in late Q3 2014.

On 7 July, Phase 2 of the Offshore Installation program, the loadout and installation of the platform topsides is effectively complete, with welding of the topsides to the jacket currently in progress. The platform topsides were loaded out from the Sattahip yard on 2 July and transported to the Manora development location for installation. The platform topsides were then successfully installed and secured on the previously installed jacket on 7 July.

Final hook-up and commissioning work will proceed prior to the arrival of the Atwood Orca Jack Up Drilling Rig in mid August to start drilling the 10 production and five injection wells. Arrival of the FSO is planned for late July, which will then be connected to the previously installed CALM Buoy and subsea flow lines.

Following completion of the offshore hook-up and commissioning, installation of the FSO, and drilling of the first two production wells, production is expected to start in late September. The loadout, transportation and installation of the topsides was completed safely and within budget.




Iraq: Oryx Petroleum announces production and appraisal drilling update for

Demir Dagh field in Kurdistan Region of Iraq. Source: Oryx Petroleum

Oryx Petroleum Corp has announced a production and drilling update for the Demir

Dagh field in the Hawler license area in the Kurdistan Region of Iraq, including test

results for the Demir Dagh-6 appraisal well ('DD-6'). Oryx Petroleum is the operator

and has a 65% participating and working interest in the Hawler license area.

Highlights:

• Gross (100%) production at the Demir Dagh field is currently approximately 4,000 bbl/d

o Liftings/sales and payments are proceeding in accordance with the agreement with a third

party marketer

• Two cased-hole drill stem tests (“DSTs”) were successfully conducted at DD-6 in the Cretaceous

reservoirs

o Maximum sustained natural flow rate of approximately 700 bbl/d of oil using a 16/64”

choke

o The well demonstrated high productivity but natural gas encountered at the top of the

perforation constrained use of choke sizes and flow rates

o Similar crude qualities were encountered as tested in the Cretaceous reservoirs at other

Demir Dagh wells

• 2014 Demir Dagh Appraisal and Development

o Demir Dagh-7 well (“DD-7”) is to be spudded in the coming weeks and is expected to reach

a total depth in Q3 2014

o Three additional development wells are to be drilled in 2014 as deviated wells to Lower

Cretaceous reservoirs

o Preparation work for the acquisition of 440 square kilometres of 3D seismic data over the

Demir Dagh, Banan and Zey Gawra discoveries commenced in June 2014

Operations remain largely unaffected by the security situation in northern Iraq (outside of the Kurdistan Region)

Commenting today, Henry Legarre, Oryx Petroleum’s Chief Operating Officer, stated:

'We are very pleased that production and sales are both increasing smoothly and we are pleased with the results of DD-6. We successfully flowed oil from the well´s primary target in the Cretaceous. The results confirmed the presence of similar crude qualities for the Cretaceous reservoir tested at other wells drilled at Demir Dagh. However, sustained flow rates achieved were less than expected despite high well productivity. We encountered some natural gas at the top of the perforation interval which restricted our ability to use high choke sizes. If we did not encounter the gas DD-6 would likely have been one of our most productive wells at Demir Dagh.

We expect to spud DD-7 in the coming weeks and expect to drill three additional development wells at Demir Dagh this year in order to increase production capacity and continue delineating the field.




Importantly, our operations remain largely unaffected by the security situation in northern Iraq, outside of the Kurdistan Region. We continue to vigilantly monitor the situation and implement measures to mitigate risks.'

Remaining 2014 Demir Dagh Appraisal Program

The Romfor 22-rig is expected to spud DD-7 approximately 1.5 kilometres from DD-2. DD-7 is expected to reach a total measured depth of 2,121 metres in the Lower Cretaceous in Q3 2014. The well is targeting the Cretaceous reservoir just to the north-west of the fault running from west to east across the structure between the Demir Dagh-1 well and DD-2. Three additional development/appraisal wells will be drilled in 2014 to the Lower Cretaceous in order to increase production capacity and to further delineate the Cretaceous reservoir. DD-7 and the remaining three development wells planned for 2014 will be drilled in a similar deviated manner as DD-6 in order to optimally access the fracture networks.

Preparation work for the planned acquisition of 3D seismic data covering 440 square kilometres over the Demir Dagh, Banan and Zey Gawra discoveries commenced in mid-June. The data acquired should help the Corporation better understand the three discoveries and determine optimal locations of future appraisal/development drilling.

ABOUT ORYX PETROLEUM CORPORATION LIMITED

Oryx Petroleum is an international oil exploration and production company focused in Africa and the Middle East. The Corporation's shares are listed on the Toronto Stock Exchange under the symbol "OXC". The Oryx Petroleum group of companies was founded in 2010 by The Addax and Oryx Group Limited and key members of the former senior management team of Addax Petroleum Corporation. Oryx Petroleum has interests in six license areas, two of which have yielded oil discoveries and four of which are prospective for oil. The Corporation is the operator or technical partner in four of the six license areas. Two license areas are located in the Kurdistan Region and the Wasit governorate (province) of Iraq and four license areas are located in West Africa in Nigeria, the AGC administrative area offshore Senegal and Guinea Bissau, and Congo (Brazzaville). Further information about Oryx Petroleum is available at www.oryxpetroleum.com or under Oryx Petroleum's profile at www.sedar.com




DNO resumes production at strike-hit Yemen blocks Reuters + NewBase

The Norwegian oil and gas operator DNO has resumed oil production at two of its blocks in the Hadramout region of Yemen, nearly two weeks after halting production following blockades by local labour unions.

DNO, in which RAK Petroleum owns a 42.8 per cent stake, yesterday announced the resumption of oil production from Block 32 Howarime and Block 43 South Howarime. Production from the two blocks averaged 1,600 barrels of oil per day before suspension.

The company said that it had suspended production at the two blocks following “unilateral actions” taken by labour unions on June 22 that led to work stoppages, and had issued force majeure notices to Yemen’s ministry of oil and minerals.

“Access to and conduct of operations on these blocks have been restricted since late last year as a result of blockades by local groups restricting movement of equipment, supplies and contractors,” the company said last month.

About 80 local DNO workers went on strike last month demanding an increase in monthly salaries and full medical insurance for their families, according to local press reports.

DNO has six blocks in Yemen, three of which (including Blocks 32 and 43) are in the production phase, with the remaining three being explored and developed.

The labour union action is the latest in a series of events that have affected DNO’s operations in Yemen.




In January tribesmen in the Hadramout region killed at least six soldiers, and warned the Norwegian company to stop operating in the region.

DNO invoked force majeure for its Block 47 South Hood last September. The company is planning to commence production from one of the wells in the block later this year.

Block 32

Yemen Block 32 contains producing fields Godah and Tasour and the Meshga discovery.

In October, the Salsala-1 exploration well led to a new oil discovery on the Meshgha structure. The well flowed naturally at a rate of 5,900 bopd before being choked back to 3,400 bopd due to facilities constraints. The Company plans to appraise the Meshgha discovery in 2014 and evaluate fast-track development options.

Block 43

Yemen Block 43 contains the Nabrajah field.

The Company commenced drilling of the Nabrajah-18S/S2 wells during the fourth quarter of 2013 to test formation intervals previously encountered at the field with the Nabrajah-5 and Nabrajah-9S wells.




GCC fertiliser industry growth twice global average: GPCA Gulf-Times, Qatar

The fertiliser industry in the Gulf region (GCC) is growing twice as fast as the global industry average led by the increased investments from petrochemical producers, says the Gulf Petrochemicals and Chemicals Association (GPCA).

According to GPCA estimates, GCC’s fertiliser production capacity reached 42.7mn tonnes in 2013, a 4% increase from the previous year, while the global fertiliser industry grew by just 1.7% in the same period. Capacity growth was achieved with several multimillion dollar projects in Saudi Arabia, Qatar and the United Arab Emirates coming on-stream.

Chairman of the GPCA’s Fertiliser Committee and chief executive officer of Qatar Fertiliser Company (Qafco), Khalifa al-Sowaidi said, “In 2013, GCC producers exported 20mn tonnes of fertiliser products to more than 80 countries worldwide.”

“The GCC industry accounted for approximately one-quarter of global urea trade and for 12% of the global ammonia trade volume in 2013. With double-digit capacity growth over the last five years, the GCC industry has demonstrated its potential to be a major global player.”

With the world population projected to reach more than 9.3bn by 2050, the International fertiliser Industry Association (IFA) predicts that world food production has to increase by 60% to feed the world’s future generations.

“The growth in population and the need to accelerate food production represents a major opportunity for the GCC’s fertiliser producers,” explained al- Sowaidi.




“As an export-oriented market that exports more than 90% of its nitrogen fertilisers (ammonia and urea) to the Far East, the GCC fertiliser industry can make a major global contribution to addressing food security challenges by providing access to and efficient use of inputs and resources.”

While analysts have predicted a slowdown in growth due to the availability of cheaper feedstock elsewhere, particularly due to the shale gas revolution, the GPCA forecasts that region’s fertiliser capacity will continue to grow at a steady pace.

“Several multi-billion dollar projects will be completed in the next years, which will strengthen the GCC’s fertiliser capacity to over 66mn tonnes by 2018,” said Dr Abdulwahab al-Sadoun, GPCA secretary general. “In addition, the industry will further diversify its products portfolio to ensure its long-term competitiveness and profitability.”

To support the region’s fertiliser industry, the GPCA will host its 5th Annual Fertiliser Convention from September 16 to 18 in Dubai. Discussions will focus on how fertiliser contributes to global food security.

Co- organised with CRU, the independent consultancy group specialising in fertilisers, the conference will provide delegates with an in-depth supply and demand analysis from major markets around the globe, thought leadership from industry experts, and project case studies from the Gulf region and beyond.




Shell shelves Saudi gas development project

Reuters + NewBase

Royal Dutch Shell is ending investments in a gas development project in Saudi Arabia, complicating the top oil exporter's efforts to exploit its huge gas reserves. The search for gas has been a priority for Saudi Arabia as it struggles to keep pace with rapidly rising domestic demand. But the emergence of the shale gas industry has opened up more lucrative opportunities for energy companies elsewhere."Shell has decided to end further investment in the Kidan development," it said in an emailed statement. "This was a difficult decision but Shell remains committed to the Kingdom and we are keen to grow our investments, both in upstream and downstream."

Shell did not give a reason for the decision to shelve the joint venture in the Kidan area of the Empty Quarter, the sea of sand dunes that cover south-east Saudi Arabia. Last year, industry sources said the company was set to end investments in the venture due to disagreements with the government over terms.At least three foreign firms - Italy's ENI, Spain's Repsol and France's Total - have already abandoned the search for commercially viable gas deposits in that part of Saudi Arabia. Shell has stuck it out longer in its South Rub al-Khali Co (SRAK) project with state-run Saudi Aramco after finding small quantities of gas. Kidan is rich in sour gas and is near the 750,000 barrels per day (bpd) Shaybah oilfield, one of the biggest in the country. Sour gas has high levels of potentially deadly hydrogen sulphide and therefore is tougher to produce than conventional gas reserves.

Shaybah Oil Field - with an estimated reserves of over 14

billion barrels of crude oil and 25 trillion cubic feet of gas




The relatively high cost of developing challenging deposits in a country where gas sales prices are fixed at a fraction of probable production costs were possible reasons to discourage Shell too, industry sources familiar with the matter told Reuters last year. Saudi Arabia, which holds the world's fifth largest proven reserves of gas, expects domestic demand for natural gas - which it uses mainly for power generation - to almost double by 2030 from 2011 levels of 3.5 trillion cubic feet per year. Saudi Oil Minister Ali al-Naimi had estimated the country's unconventional gas reserves - those held in reservoirs that have not been traditionally exploited - as at over 600 trillion cubic feet, more than double its proven conventional reserves.Saudi wants natural gas to help it cover demand for subsidised domestic power so it can save its oil for more lucrative exports.

Royal Dutch Shell has admitted that its search for gas in Saudi Arabia has been a decade-long wild goose chase, dashing any hopes of gaining a prized upstream foothold in the kingdom. “We haven’t had a very successful exploration campaign,” Andrew Brown, director of upstream international business at Shell, told The Sunday Telegraph in an interview. “We aren’t conducting any operations there [at Rub al-Khali desert] at the moment.” Mr Brown declined to specify whether the failure of exploration in the desert – where sand dunes can tower 1,000ft high and temperatures can hit 122F – would force it to shutdown the South Rub al-Khali Company (SRAK), its joint venture with state-owned producer Saudi Aramco. The announcement on its activities in the Rub al-Khali comes as Shell – Britain’s most valuable company by market value – aggressively cuts costs. In January, Shell said it aimed to raise about $15bn (£8.7bn) from asset sales and cut capital spending to $37bn this year from $46bn in 2013. No work has taken place in the area since the company said it had stopped drilling in February. Exploration has been plagued by delays and the cost of working in such an environment.




TransAtlantic Petroleum provides update on operations in

Turkey Source: TransAtlantic Petroleum

TransAtlantic Petroleum has provided an operational update on its current drilling program in Turkey Operational Update

For the second quarter of 2014, TransAtlantic had average net production of approx. 5,000 BOEPD, an 8% increase over average net sales in the first quarter of 2014 and a 24% increase over average net sales in the second quarter of 2013. Average net production for the second quarter of 2014 was comprised of approx. 3,500 BOPD of oil and approx. 9.0 MMCFPD

of natural gas. Net sales for the second quarter of 2014, which the Company plans to report in early August 2014, are expected to be slightly lower than net production. The Company currently has three active rigs in southeastern Turkey. TransAtlantic spudded five wells and completed four new wells in the second quarter of 2014.

Southeastern Turkey -- Selmo Field Development

TransAtlantic continued its horizontal drilling campaign in the Selmo field and has spudded eight horizontal wells targeting the MSD zone. The Company recently achieved target depth of 8,100 feet on the Selmo-85H (100% working interest), and has commenced completion operations. In June 2014, TransAtlantic completed the Selmo-54H (100% working interest). The well had an initial production rate of 686 BOPD gross and is currently producing 659 BOPD gross nearly one month later. The Company expects to spud at least five additional horizontal wells in the Selmo field in 2014.

TransAtlantic also continued its implementation of a secondary recovery program in the Selmo field. Year-to-date, two wells have been converted to injection, more than 162,000 barrels of water have been injected into the field and facilities are being expanded to allow for continuous water injection. In the third quarter of 2014, the Company will commence its second phase of polymer injection into Selmo wells to increase their oil recovery.

Southeastern Turkey -- Molla Drilling Program

TransAtlantic reached target depth of 10,500 feet on the Bahar-2ST (100% working interest), on June 12, 2014 and is conducting a two-stage stimulation in the Bedinan formation. The Company is currently logging the upper Bedinan sands of the Bahar-3 (100% working interest) at a depth of approximately 11,100 feet and plans to drill an exploration well into the lower Bedinan formation, as seen in two ARCO wells located 20 miles west of the Bahar field. Multiple oil shows were encountered in each well and core samples were taken from the Bahar-3 Hazro and Bedinan sands for future use in completion and secondary recovery activities.

TransAtlantic recently spudded the Bahar-4 (100% working interest), and expects to spud at least two additional vertical wells targeting the Hazro and Bedinan formations on the Bahar structure in the second half of 2014.




Southeastern Turkey -- Arpatepe Drilling

The Arpatepe-7 (non-operated, 50% working interest), a Bedinan appraisal well which had initial production of 330 BOPD gross (165 BOPD net) is currently producing 223 BOPD gross (112 BOPD net) by natural flow after 38 days of production. Following its success, TransAtlantic intends to spud a second appraisal well, the Arpatepe-8 (non-operated, 50% working interest), in the second half of 2014. The Company also plans to initiate a waterflood pilot test to assess the effectiveness of secondary recovery in the Arpatepe field.

Southeastern Turkey -- Idil Exploration

TransAtlantic is preparing to drill a vertical exploration well on its Idil license in the second half of 2014. The Company's joint venture partner, Onshore Petroleum Company AS ("Onshore"), has been assigned a 50% interest in the Idil license and will fund 100% of TransAtlantic's initial exploration well, up to $3.5 million. Expenses over $3.5 million will be split equally between Onshore and TransAtlantic.

Northwestern Turkey -- Thrace Basin Development

TransAtlantic expects to recommence drilling in the Thrace Basin with one rig in July 2014. The Company plans to drill two additional horizontal wells (41.5% working interest) in the Mezardere and Teslimkoy formations at a vertical depth of approximately 3,300 feet and five shallow, conventional, vertical wells (41.5% working interest) in the Osmanli area based on 3D seismic shot in the fourth quarter of 2013. Current average gross production for the two horizontal Mezardere wells drilled in the first quarter of 2014 is approximately 750 MCFPD.




DECC: UK oil and gas reserves between 11.1 and 21 boe Press Release .

DECC today published its annual updated estimates which show UK oil and gas reserves and resources are in the range of 11.1 to 21.0 billion barrels of oil equivalent (boe).

DECC says that these figures show there is still a lot of potential remaining in domestic energy reserves. They also further underline the importance of greater collaboration and efficiency in the industry as described in Sir Ian Wood’s recommendations.

It’s for that reason that the Government has fast-tracked the recommendations of the Wood Review to maximise the potential of the North Sea and make sure the whole of the UK benefits.

“The Government recognises the importance of the oil and gas sector and is committed to

working with industry to create the right conditions to maximise opportunity and investment

to the benefit of the whole UK economy,” DECC said in a statement.

The published estimates do not include any estimates for shale gas or shale oil reserves as exploration for shale gas is still at a very early stage in the UK.




China starts multibillion-dollar power line Reuters + NewBase

China has started operating another multibillion-dollar ultra-high voltage (UHV) power line, connecting its second-largest hydropower plant in the landlocked west to a province on the east coast, the official China Energy News reported yesterday.

The world’s No 2 economy has struggled to expand its grid to keep up with growing power demand, with most of its new energy supplies in the far west, while demand is in the east and

south.

State Grid Corp of China (SGCC), the world’s biggest utility and a pioneer of UHV technology, plans to spend 620bn yuan ($100bn) by 2017 on 20 UHV lines in China, a company executive said last August. The project has been controversial with critics arguing SGCC is betting too much on costly and untested technology that could expose the system to blackouts.

The firm has said that UHV lines are reliable and designed to prevent outages. The latest UHV line spans five provinces – Sichuan, Guizhou, Hunan, Jiangxi and Zhejiang – and cost about 19.7bn yuan ($3.2bn).

It will be part of a UHV complex that will ship about 40bn kilowatt hours of electricity a year from the hydropower-rich southwestern regions to eastern consuming hubs, China Energy News said. That would be equivalent to conserving 12.28mn tonnes of standard coal and reducing carbon dioxide emissions of 34mn tonnes every year.




The third such project run by SGCC, a 1,653-kilometre line that starts in the southwestern province of Sichuan and ends in Zhejiang, started operating last week, the paper said. That coincided with the start of full operations at the Xiluodu hydropower station, the country’s second largest in terms of capacity.

The UHV lines would allow China to build power plants near coal mines or gas fields before sending electricity rather than coal across country. This would free up rail capacity and could reduce the need for coal and gas imports.

WITH 2020 clean-energy targets to meet, China is set to accelerate the building of hydroelectric dams, reversing a long halt caused by environmental concerns and the social upheaval of relocating people living in the shadow of dam sites. The trend will create a "golden decade" for the nation's hydropower sector, analysts say, as high fuel prices continue to squeeze margins of coal-fired power plants that comprise the bulk of China's electricity-generating capacity. Renewable energy sources like solar power have been slow to come on line on a big scale because of high costs and grid-configuration problems.

The Chinese government now aims to have 430 gigawatts of hydropower capacity by 2020, increasing its earlier target of 380GW, the China Securities Journal reported last month, citing unidentified sources. “That means each year, the equivalent of one new Three Gorges Dam will be added in China over the next decade,” said Shao Minghui, an analyst at China Post Securities, using the 2020 target of 380GW as a base. “The market is really sizable.” The 18.2GW Three Gorges Dam, which spans the Yangtze River and is located in Yichang, Hubei Province, is the world's largest.

China must address the problems of environmental protection and people relocation,” said Zhou Yanchang, an analyst at Huatai United Securities. “And that will increase construction and operating costs.” One solution is to raise the price of hydropower electricity. At present, the on-grid tariff — or the price charged by power producers to grids — for hydropower is below that of energy produced by coal-fired plants. The prices are set based on operational costs of producing the power. Hydropower projects require larger investments and involve longer construction times than coal-fired plants, but they run at lower costs upon completion.




Production of fossil fuels from federal and Indian lands fell in 2013 Source: U.S. Energy Information Administration, U.S. Department of the Interior

Sales volumes of fossil fuels from production on federal and Indian lands in fiscal year (FY) 2013 dropped 7% from FY 2012, according to EIA's recently released annual report. Crude oil production on federal lands increased slightly in FY 2013, but that increase was more than offset by decreases in coal, natural gas, and natural gas plant liquids (NGPL) production. Sales of fossil fuels from federal and Indian lands accounted for about 26% of total fossil fuel sales volumes in the United States in 2013.

Since FY 2003, sales of fossil fuels produced on federal and Indian lands have fallen 21%, driven by declines in natural gas production and coal production. From FY 2003 to FY 2013, total U.S. fossil fuel production increased by 14%, with a 34% increase in production from nonfederal, non-Indian lands offsetting the decline from federal and Indian lands.




One of the main drivers in the decline in sales of fossil fuels from federal and Indian lands is the drop in offshore natural gas production, even as total U.S. natural gas production has grown rapidly because of rising production from onshore shale resources on private lands. Federal onshore natural gas sales volumes have generally increased over FY 2003-13, overtaking federal offshore production in FY 2007.

Source: U.S. Energy Information Administration, from Federal Lands and Bureau of Indian Affairs




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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 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 as Oil & Gas sector. Currently working as Oil & Gas sector. Currently working as Oil & Gas sector. Currently working as

Technical Affairs Specialist for Emirates General Petroleum Corp. Technical Affairs Specialist for Emirates General Petroleum Corp. Technical Affairs Specialist for Emirates General Petroleum Corp. Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for “Emarat“ with external voluntary Energy consultation for “Emarat“ with external voluntary Energy consultation for “Emarat“ with external voluntary Energy consultation for

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

Manager in Emarat , responsible for Emarat Gas Pipeline Network FacilityManager in Emarat , responsible for Emarat Gas Pipeline Network FacilityManager in Emarat , responsible for Emarat Gas Pipeline Network FacilityManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developed & gas compressor stations . Through the years , he has developed & gas compressor stations . Through the years , he has developed & gas compressor stations . Through the years , he has developed

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routes. Many years were spent drafting, & compiling routes. Many years were spent drafting, & compiling routes. Many years were spent drafting, & compiling routes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs for gas transportation , operation & maintenance agreements along with many MOUs for gas transportation , operation & maintenance agreements along with many MOUs for 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 broadcasted Energy program broadcasted Energy program broadcasted Energy program broadcasted

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NewBase 01 July 2014 K. Al Awadi

New base special 08 july 2014

Economy & Finance

Transcript of New base special 08 july 2014