New base 804 special 09 march 2016

Copyright © 2015 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced, redistributed,

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NewBase 09 March 2016 - Issue No. 804 Edited & Produced by: Khaled Al Awadi

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UAE: Masdar powers up solar PV plants on Vanuatu island The National - LeAnne Graves

Abu Dhabi’s Masdar has completed its sixth project in the Pacific islands under a US$50 million initiative. The three solar photovoltaic (PV) plants, totalling 767 kilowatts, were developed in the Pacific island nation of Vanuatu.

The project forms part of the UAE-Pacific Partnership Fund (UAE-PPF).

Only 27 per cent of Vanuatu’s most populated island, Port Villa, has access to electricity. The island already generated some renewable energy from solar PV, wind and hydropower, but most of the power comes from diesel generators – which means a high import bill for an island without the natural resource.




The latest solar PV additions include 644 kWh ground-mounted and car park structures at the parliament building as well as a 123 kWh ground-mounted structure at the meteorology department building. Masdar’s installations will help save the island $378,000 on its diesel bill alone, based on last year’s prices.

“By helping to alleviate their energy burden, we are enabling these Pacific nations to allocate more of their resources to accelerating economic growth and maximising the potential of their inhabitants," said Mohammed Al Ramahi, the acting chief executive of Masdar.

The UAE-PPF initiative finances renewable energy projects across the Pacific with grants from the Abu Dhabi Fund for Development and projects delivered by Masdar in collaboration with the Ministry of Foreign Affairs.

The programme has delivered more than 2.8 megawatts of renewable energy capacity, helping to replace 1.5 million litres of imported diesel fuel.

The combined output of the projects has saved US$2 million per year and also eliminated 4,157 tonnes of carbon dioxide emissions annually, Masdar said.

“The continued success of the UAE-PPF is tangible evidence of Masdar’s ability to develop workable renewables solutions and deploy them in the service of the UAE’s bilateral partnerships with countries around the world," said Mr Al Ramahi.

“We have already helped to make a real difference in the six countries we are currently partnering and we believe this partnership fund could provide a model for similar agreements around the world."

Projects in Kiribati, Fiji, Tuvalu and Vanuatu are financed by US$50 million UAE-Pacific Partnership

Fund




Bid to recover untapped oil resource in Bahrain Trade Arabia News Service

Bahrain is considering the launch of a pilot project to recover a huge untapped resource in the residual oil saturation in the Gas Cap of the Mauddud reservoir, Energy Minister Dr Abdul Hussain bin Ali Mirza said here at a conference on Monday. Speaking at the opening of the 12th Middle East Geosciences Conference and Exhibition (GEO 2016), the minister said that efforts are being made to produce the residual oil saturation in the Gas Cap of the Mauddud reservoir. “For this, currently an expanded pilot project is being evaluated to determine the best way to recover this huge resource,” he added.

The Bahrain Field, said the minister, was discovered in 1932, the first discovery in the GCC countries. “We are proud of the fact that although a large percentage of the recoverable reserves of the Bahrain Field have already been produced over the last 84 years, National Oil and Gas Authority (Noga), through Tatweer Petroleum, managed during the last few years to arrest, and reverse the declining oil production, and to increase the daily oil output by more than 50 per cent, compared with the production level of 2009. “Additionally, the non-associated gas production capacity was also increased by around 30 per cent, which enabled us to meet all natural gas demands during the last five years,” added Dr Mirza.

Energy Minister Dr Abdul Hussain bin Ali Mirza alongwith other speakers at

the opening session of the 12th Middle East Geosciences Conference and

Exh




“Despite all challenges, we are confident, and determined, to develop the non-associated gas resources of the deep sandstones formations in the Bahrain Field,” he added. According to him,

Noga has managed to reduce associated gas flaring in the field, to less than 0.5 per cent. The associated gas that used to be flared, he said, is captured and re-injected in the producing reservoirs. A $355 million expansion of gas processing facilities at the Bahrain National Gas Company will increase its processing capacity by 350 million cubic feet per day. It will process the additional associated gas, which resulted from Tatweer’s increased production to produce liquefied petroleum gas. “The residue gas, will then be injected in the producing reservoirs, to maintain pressure and to cycle the rich gas,” he added. During his opening remarks to conference delegates, Dr Mirza said the conference theme ‘Today’s Geoscience, Tomorrow’s Energy’ truly reflected the reality of the petroleum industry. “Today, we find ourselves in a price environment, that has serious implications on the long-term horizon of the world we live in, and on the welfare of nations and citizens. “Many of the producing nations, have set their spending budgets, on

certain revenue assumptions, that are multiples of today’s prevailing prices,” he added. According to him, with the current decline in oil prices from $115 per barrel in April 2011 to an average price of $32 per barrel in January, and as the upstream business grows increasingly competitive, coupled with the realisation that most of the easy oil had already been found and mostly produced, development of new supplies would be more challenging, more expensive to




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




Indonesia: Andalas Energy and Power signs Tuba Obi East gas project farm-in agreement

Source: Andalas Energy & Power Andalas Energy and Power, the AIM listed investment company, has conditionally entered into a farm-in agreement for the Tuba Obi East ('TOE') Technical Assistance Contract ('TAC'), which is located in the South Sumatran basin approx. 30km north-west of Jambi city in Jambi province, Sumatra.

Highlights:

• ADL to acquire 30% working interest in TOE TAC via a farm-in;

• TOE is the entry point for Andalas into the profitable Indonesian gas and power sector;

• Any future gas production from the concession may support either:

o Gas export with the project located close to a major export route; or

o Gas-to-power being located in an area where a significant shortfall in power generation exists;

• Farm-in via execution of a US$1.075 million work programme;

• Work programme comprises technical studies and the drilling and testing of one well which would be put into production on success;

• Work programme is being jointly operated by Andalas;

• Planning and preparations for drilling are advancing rapidly;

• Subject to well results, further gas and power development studies will be undertaken;

• Gaffney Cline and Associates is in the final stages of completing a Competent Person’s Report ('CPR') assessing the gas resources within the TAC; and

• Farm-in constitutes a reverse takeover pursuant to the AIM Rules and, accordingly, the farm-in agreement is subject to the approval of Andalas’ shareholders in general meeting.

• An admission document which will include notice of a general meeting seeking shareholder approval will be published in due course.

Andalas CEO, David Whitby, said 'The signing of this agreement follows the Letter of Intent announced on 3 February 2016 and secures ADL’s foundation gas asset. We are keen to take

full advantage of the opportunity Tuba Obi East now affords Andalas, and we regard it as the base upon which a profitable Indonesian gas and power business can be built.

'TOE has all the essential features to be a successful first asset for the Company. It has gas proven by two wells into the reservoir zone that has been defined on 3D seismic and confirmed by well logs, all whilst located in a prolific hydrocarbon basin. In addition, the field is close to both gas and power infrastructure and has easy access to Indonesia’s burgeoning energy market which is generating high prices for producers. It represents an

unrivalled opportunity for a new Indonesian gas and power market entrant like ADL.'

Farm-in Summary




As previously announced, under the terms of the proposed farm in, Andalas will acquire a 30% direct working interest in the concession through the execution of a single well work programme. The work programme includes the completion of a geological, geophysical and reservoir (‘GG&R’) study along with the drilling and flow testing of a single well to assess the deliverability, recoverable volumes, and gas quality in the Air Benakat formation.

Block operator PT Akar Golindo and Andalas will jointly operate the well work programme, which is expected to cost around US$1.075 million. Andalas has also agreed to pay a further sum of US$500,000 to PT Akar Golindo if the concession is renewed beyond its expiry date of 15 May 2017.

Pursuant to Rule 14 of the AIM Rules for Companies this farm-in constitutes a reverse takeover and, accordingly, the farm-in agreement is subject to the approval of Andalas’ shareholders in general meeting.

Work Progress

Under the terms of the agreement the Company will be the technical operator for the Tuba Obi East well work programme. Accordingly, ADL’s in-country team has expedited the design, planning and site preparations for the farm-in well (provisionally called TOE-2). The concession operator, PT Akar Golindo, has also been supporting this work.

Two well locations (a preferred location and an alternate) have now been selected and site surveys have been completed, along with the inspection of potential drilling rigs, during the week commencing 22 February 2016. The drilling team is now progressing the rig selection process whilst services contracting continues apace, with the preparation of critical tender documents.

As part of the reverse takeover process, representatives from the Company’s nominated adviser, Cantor Fitzgerald (Europe), have visited the field. Gaffney Cline and Associates in Singapore has almost completed its CPR assessing the gas resources within the concession. The results of their analysis are expected shortly. Andalas will publish the Admission Document in due course.

Tuba Obi East Gas

Tuba Obi East is located in the South Sumatran basin approx. 30km north-west of Jambi city. The wells previously drilling in the concession have tested gas in the key South Sumatra hydrocarbon bearing formations, namely, the Air Benakat Formation (‘ABF’) and the Talang Akar Formation (‘TAF’). A total of six wells (three wells within the concession and a further three just outside) have been drilled through these zones, with a number having been logged across the ABF and TAF. Several have also flowed gas to surface.

Crucially, the ABF has flowed gas outside the TAC at commercial rates, but only limited data from this formation has been gathered within the concession area. Andalas’ technical analysis indicates that this reservoir zone contains potentially substantial gas resources that can be proven via the drilling and flow testing of the proposed TOE-2 well. If the work programme proves successful, the TOE-2 may be completed as a future production well.

Further GG&R and development studies will be undertaken following the analysis of test results from the well. This work will be conducted in parallel with development planning and a proactive approach to the renewal and extension of the concession contract. Preliminary discussions will also be held with targeted gas and power consumers.




Malaysia's Reach Energy Acquires 60% Stake in Kazakhstan Block for $155M RigZon - Chee Yew

Malaysia's Reach Energy Berhad entered into a tripartite conditional Sale and Purchase Agreement March 5 with Palaeontol Cooperatief U.A. and MIE Holdings Corp. to acquire a 60 percent stake in Palaeontol B.V., the company announced Monday on local exhange Bursa Malaysia.

Palaeontol B.V., a unit of MIE Holdings' subsidiary Palaeontol Cooperatief, is the exclusive owner of Emir-Oil LLP which holds full working interest in an onshore block in Mangistau Oblast in southwest Kazakhstan.

The 328.3 square mile (850.3 square kilometer) block, located around 24.9 miles (40 kilometers) northeast of Aktau -- Kazakhstan's largest port in the Caspian Sea coast, comprises four existing oil and gas producing fields. They are the Aksaz, Dolinnoe, Emir and Kariman fields, occupying around 17.6 square miles (45.5 square kilometers) in the block.

Reach Energy revealed that exploration, development and production of hydrocarbons will continue in the remaining 349.3 square miles (804.8 square kilometers) of the block, including two discovered fields and six drillable prospects.

RPS Energy Consultants Ltd., the independent technical and asset valuation expert appointed by Reach Energy, estimated that the indicative gross proved plus probable (2P) reserves of the producing fields and development fields in the block at around 72.1 million stock tank barrels (MMstb) of oil and 102.4 billion standard cubic feet (Bscf) of gas as at Jan. 1.

The net 2P reserves attributable to the firm upon completion of the proposed acquisition are around 43.3 MMstb of oil and 61.4 Bscf of gas, equivalent to total net 2P reserves due to Reach Energy of 53.5 million barrels of oil equivalent.

The firm, a special purpose acquisition company, will pay $154.9 million (MYR 638.2 million) for the stake in Palaeontol B.V., which upon completion will give Reach Energy majority ownership and control over the Emir-Oil fields.




"The Proposed Acquisition represents Reach Energy’s qualifying acquisition as stipulated under the Equity Guidelines issued by the Securities Commission Malaysia and will transform Reach Energy into an independent Malaysia-based E&P (exploration and production) company with its maiden operation in Kazakhstan," the firm said in a press release.

“Reach Energy entered into this Proposed Acquisition after identification and evaluation of some 40 candidates. The Producing Fields and Exploration Area (collectively known as Emir-Oil Fields) provide a unique opportunity for Reach Energy for investing and operating a balanced portfolio of O&G (oil and gas) fields covering the wider spectrum of upstream O&G production, development and further exploration activities," Reach Energy's Managing Director Shahul Hamid Bin Mohd Ismail commented in the press release.

"We are confident that we can deliver much value to our shareholders from this asset with the co-operation of our partner, MIEH, who is an established independent E&P company with operations in China, Kazakhstan and the U.S. The Producing Fields are in their early and prime stage of production and the Development Fields are currently under pilot production. We believe that there is significant upside potential through further planned efforts, techniques and schemes,” he added.

The proposed acquisition of the onshore Kazakhstan block meant that Reach Energy had dropped a plan to purchase an upstream target in the Asia Pacific.




South Africa to Start Shale Gas Exploration Next Financial Year Reuters + NewBase

Shale gas exploration in South Africa is expected to commence in the next financial year (Apr-Mar). “One area of real opportunity for South Africa is the exploitation of shale gas. Shale gas regulations were published in the second quarter of 2015-16. Exploration activities are scheduled to commence in the next financial year. This will lead to excellent prospects for beneficiation and add value to our mineral wealth, the South African government said in a statement published on its website Tuesday. In January, Minister for Mineral Resources, Mosebenzi Zwane stated that South Africa has world’s 5th largest shale gas reserves.

“Currently South Africa is a net importer of energy sources such as crude oil, refined petroleum products and natural gas. It is estimated that the Karoo shale gas resources would mean South Africa has the 5th largest reserves, estimated at 485 trillion cubic feet (Tcf),” Zwane said in January.

“We however take a conservative view of a 30 Tcf economically recoverable resource, which is equivalent to 30 times the size of the Mossgas plants.”

Regulatory hurdles have resulted in delay in start of shale gas exploration in the country. Energy major Shell last year exited the shale gas exploration space due to repeated delays in issuance of licences.

The Karoo Basins

The southern Main Karoo Basin is considered to be the most prospective area for shale gas in South Africa, due to the presence of deeply buried, thermally mature black shales. To date,




exploration right applications have been received from Shell International, Falcon Oil and Gas in partnership with Chevron, and Bundu Gas.

Natural gas and oil shows across the Main Karoo Basin indicate an active petroleum system with multi-play potential. The widespread occurrence of pyrobitumen (pseudo-coal) in the southern part of the basin indicates an originally oil-prone source rock.

In 1968, exploration well CR1/68 in the southern Main Basin yielded a gas flow rate of 1.83 mmscf/day for 23 hours from the fractured Fort Brown shale. The Fort Brown was thought to be self-sourcing (i.e. a gas shale), but may also have been charged by the underlying Whitehill Formation.

The volume of gas in place in the Main Karoo Basin is highly uncertain, but possible scenarios suggest that technically recoverable volumes may range from 30 Tcf to 500 Tcf. A key uncertainty is the gas content of the various Karoo shale formations – this may be limited where diagenesis is particularly high.

The Permian Whitehill Formation is considered to be the most promising shale gas target in the Karoo, due to its high organic carbon content (TOC = 5 % average), high thermal maturity (Ro = 1-4 %), high quartz content (50 %), thickness (30 m average) and regional continuity (200 000 km2). However, a major exploration risk factor is the existence of dolerite intrusions, which occur in much of the Karoo Basin.

Karoo shale gas is considered to be only a prospective resource at present, and will remain undiscovered until a hydraulically fractured test well produces enough gas to be of commercial interest. The economic value of Karoo shale, in turn, will only be known once a statistically significant number of well flow rates have been measured. The long term market for gas in South Africa is likely to be strong as the country's energy needs continue to grow. However, a significant investment in infrastructure will be required before South Africa becomes a major shale gas producer.




NewBase 09 March 2016 Khaled Al Awadi

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

Oil prices dip on stronger dollar, demand concerns Reuters + NewBase

Oil prices dipped on Wednesday, weighed down by a strengthening U.S.-dollar and concerns over slowing demand, although falling U.S. production lent crude markets some support.

U.S. crude futures were trading at $36.46 per barrel at 0219 GMT, down 4 cents from their last settlement, but still almost 40 percent above February's 2016 and multi-year low.

International Brent crude futures were at $39.54 per barrel, down 11 cents from their last close, but still some 40 percent above their January lows for this year.

The dips came as the dollar reversed recent losses against a basket of leading currencies overnight, potentially hampering oil demand as imports of dollar-traded crude get more expensive.

But analysts said the main reason for the dip in prices and at least temporary end to the rally was concern over faltering demand in China, where the economy is growing at its slowest pace in a generation.

"The recent oil rally is looking overextended ... China's export data was horrendous," Matt Smith of Clipper Data said in a daily report.

China's February trade performance was far worse than economists had expected, with exports tumbling the most in over six years.

Oil price special

coverage




Although China imported record crude volumes of 8 million barrels per day (bpd) in February, analysts expect this figure to fall as the government scales back purchases of strategic reserves, and car sales begin to fall as the sharpest economic slowdown in a generation starts to show results.

The price dips at least temporarily halted a price rally that started in mid-February on hopes that a coordinated freeze in production would stop growth in a global supply glut of at least 1 billion bpd above consumption that helped pull prices down as much as 70 percent since 2014.

But OPEC-member Kuwait, this week poured cold water on hopes of such a freeze by stating that it would only cap output if all major producers participate, including Iran, which has balked at the plan.

One key factor in determining the oil market balance will be U.S. output, which the government said would be 8.19 million bpd in 2017, down from over 9 million bpd currently.

But with demand growth also slowing, many analysts including influential bank Goldman Sachs, say that it will take time for markets to fully rebalance.

Energy consultancy Wood Mackenzie said that it expects "the annual average (oil) price for 2016 being lower than 2015 and then recovering in 2017, reflecting large oversupply and high stock levels during the first half of 2016".

It added that the main risks to its forecast were changes in demand in China and the extent to which Iran manages to increase oil exports after sanctions against it were lifted in January.




An oil output freeze would have a limited impact Asiya Investment - Camille Accad

The Russian energy minister announced on Tuesday that over 15 countries had already announced their intention to join the agreement. According to the Russian energy minister, that would be equivalent to 73% of global oil supply, a substantial success. That number seems to be exaggerated or inaccurate. Assuming that the United States, Canada, China and Iran are not in the agreement (they account for 26% of global production), it would imply that all other oil producers in the world have agreed to the freeze.

A coordinated oil output freeze will have little impact on global supply since the group of countries in the agreement will freeze production at record-high levels. OPEC members and Russia are already producing around record highs with little room to produce more. Thus, a freeze would only succeed at controlling a small part of the potential increase in future oil output. Exceptions are (a) Iran and Iraq, which will most likely be given an output allowance since both countries are producing much less than their full capacity and will not accept any cap at current levels , and (b) Libya, which despite producing much less than full capacity remains severely handicapped by a disrupting civil war. Despite having little effect on actual oil production, the agreement would produce important benefits for oil exporters. First, the deal would create a wider-than-OPEC framework for decision-making. Second, it creates a mechanism for producers to track each others’ production levels – the details are already under discussion. Transparency has been a recurrent problem for OPEC members and steps on this direction will improve the effectiveness of future decisions. Finally, a production freeze is a prerequisite to




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




NewBase Special Coverage

News Agencies News Release 09 March 2016

Global oil Slump Brings These Two Rivals Together Bloomberg - Rene Vollgraaff

Misery loves company. Africa's two biggest economic rivals — South Africa and Nigeria — are turning to each other as they fall on tough times.

South Africa's economy is threatened with recession as demand from China, its main trading partner, weakens and commodity prices plunge, while Nigeria has been hit by a collapse in oil revenue. To weather the global storm, the two countries are seeking closer trade and investment ties when South African President Jacob Zuma leads a high-level delegation of ministers and business executives to Nigeria on Tuesday. In the process, he may rebuild a relationship that's come under diplomatic strain in the past.

Nigeria may be Africa's largest economy — having overtaken South Africa in 2014 after the data was overhauled — but South Africa still dominates because of better power and transport infrastructure, a sophisticated financial services industry and a more diversified economy. Both economies are now under pressure, with growth slowing to 1.3 percent in South Africa last year and reaching a 16-year low of 3.3 percent in Nigeria, according to the World Bank.

South Africa is the biggest buyer of Nigerian oil in Africa, shipments of which have more than doubled between 2008 and 2014, according to data from the International Monetary Fund. However, Nigeria doesn't even feature in the top 20 of South Africa's export markets.




"There is scope for the two countries to expand trade ties, particularly in non-commodity products," said William Jackson, a senior emerging markets economist at Capital Economics Ltd. in London. There could "be greater benefits over the medium term, as rising trade in non-commodity goods tends to come alongside faster productivity growth and more rapid rises in incomes," he said.

The one thing standing in the way of stronger trade ties is the Nigerian currency. The central bank has effectively pegged the naira at 197 to 199 per dollar for a year by banning imports of everything from glass to wheelbarrows and restricting foreign-currency supply. The currency




controls are deterring investors, like Johannesburg-based Truworths International Ltd., which shut its two remaining stores in Nigeria in January.

In his first state visit since Muhammadu Buhari was elected Nigeria's president last year, Zuma may also seek to resolve a dispute that threatens the Nigerian operations of one of South Africa's biggest companies, MTN Group Ltd. Nigeria's telecommunication regulator imposed a record $3.9 billion fine on MTN last year for failing to meet a deadline to disconnect unregistered mobile-phone subscribers.

Even before that, diplomatic relations between the two countries were strained by xenophobic violence in South Africa last April, in which Nigerian businesses were attacked. Nigeria temporarily withdrew its two most senior diplomats from South Africa at the time.

"These two countries need this competitive kind of relationship, where they cooperate even though they are competing," said Azwimpheleli Langalanga, a visiting research fellow in the economic diplomacy department at the Johannesburg-based South African Institute of International Affairs. Nigeria wants "to be taken seriously because they are a serious player on the African continent," he said.




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Khaled Malallah Al Awadi, Energy Consultant MS & BS Mechanical Engineering (HON), USA Emarat member since 1990 ASME member since 1995 Hawk Energy member 2010

Mobile: +97150-4822502 [email protected] [email protected]

Khaled Al Awadi is a UAE National with a total of 25 years of experience in the Oil & Gas sector. Currently working as Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years, he has developed great experiences in the designing & constructing of gas pipelines, gas metering &

regulating stations and in the engineering of supply routes. Many years were spent drafting, & compiling gas transportation, operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcasted internationally, via GCC leading satellite Channels.

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

NewBase 09 March 2016 K. Al Awadi

New base 804 special 09 march 2016

Business

Transcript of New base 804 special 09 march 2016