NewBase 592 special 28 April 2015

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 28 April 2015 - Issue No. 592 Khaled Al Awadi

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

UAE: Inpex in 5% stake in ADCO concession Reuters + NewBase Japanese oil and gas developer Inpex Corp has completed the final adjustments to obtain a 5 per cent stake in a new concession to help operate the United Arab Emirates' biggest oilfields for $1.1 billion, public broadcaster NHK said on Monday.

Inpex was one of 11 firms that bid for stakes in the concession covering Abu Dhabi's 15 principal onshore fields that produce about 1.6 million barrels per day, NHK reported without citing sources. An Inpex spokesman declined to comment on the report. After its previous deal with oil majors expired last year, state-run Abu Dhabi National Oil Company (Adnoc) took 100 per cent of the concession as political leaders in Abu Dhabi weighed up whether to bring in Asian firms or stick with old partners, industry and diplomatic sources said. In January, Total became the first company to renew its concession, with a 10 per cent stake, putting peers like BP and Royal Dutch Shell under pressure to improve terms after the French oil major submitted the best bid offer, according to industry sources. Inpex did not have a previous stake in this concession, where production is expected to reach 1.8 million bpd from 2017. Senior Japanese government officials have been working to strengthen the country's relationship with the United Arab Emirates in energy and other areas.

85%

10%

5%




Trade Minister Yoichi Miyazawa urged Adnoc's director general Abdullah Nasser al-Suwaidi to renew oil concessions held by all Japanese companies during his January visit. Inpex Corp of Japan joined Total in developing the main onshore oil deposits in the UAE as Abu Dhabi calls on new partners for its $22bn effort to pump crude from its largest fields. Japan’s state-backed energy explorer will take a 5% stake in the fields, Yoichi Miyazawa, the trade minister, said at a press conference in Tokyo yesterday.

The concession will give Japan access to crude from the Abu Dhabi deposits for 40 years starting January 1, 2015, Inpex and the emirate’s government-owned oil producer said in an e-mailed statement.

“It makes sense for Abu Dhabi to name an Asian partner since more of their demand is coming from there,” said Robin Mills, a Dubai-based analyst at Manaar Energy Consulting. “Inpex brings quite a lot technically and they operate major projects.” A Chinese company could be one of the next bidders awarded a stake, he said. Abu Dhabi National Oil Co known as Adnoc picked Inpex from at least 10 bidders to join it and Total in the venture. Inpex agreed to pay Adnoc a signing bonus of about $1.1bn, Japan’s public broadcaster NHK reported yesterday, without saying where it got the information. The project “is highly significant in terms of the company’s growth strategies, and also largely contributes to the long-term, stable supply of energy to Japan,” Toshiaki Kitamura, Inpex chief executive officer, said in the statement. Abu Dhabi, the UAE’s largest emirate, holds about 6% of global oil reserves. The UAE capital plans to boost crude production capacity to 3.5mn bpd in 2017, from about 3mn barrels a day now. Output capacity from the onshore bloc in which Total and Inpex are partners will rise to 1.8mn bpd by then, from about 1.6mn barrels now, Adnoc and Inpex said. Adnoc is spending about $22bn on projects to increase onshore oil and gas production and export capacity, Omar Suwaina al-Suwaidi, the company’s deputy director for strategy, said at a conference in Abu Dhabi on November 11. The concession encompasses the fields of Bab, Bu Hasa, Sahil, Asab, Qusahwira, Mender, Al Dabb’iya, Rumaitha and Shanayel, Adnoc said yesterday. Total, along with BP, Exxon Mobil Corp, Royal Dutch Shell and Partex Oil & Gas, was a shareholder in the Abu Dhabi onshore fields, under a 75-year concession agreement that expired in January 2014. Total became the first company awarded a stake in January, getting 10% of the holding. Inpex wasn’t involved in the onshore projects until now. Adnoc, which plans to retain 60% of the partnership, asked the remaining bidders to match the $2.2bn signing bonus Total agreed to pay for its 10% share in the fields, two people with knowledge of the situation said February 12.




Adnoc was last week in advanced talks with two Asian bidders, while proposals “by international oil companies failed to fulfil Adnoc’s requirements and conditions,” director general Abdullah Nasser al-Suwaidi said, according to an April 20 statement from the company. China National Petroleum Corp was among companies to bid for the concession, according to Energy Intelligence Group. Three calls to CNPC’s Beijing-based spokesman Qu Guangxue weren’t returned. “China’s where the action is in terms of demand growth,” Mills said. China could win a stake in the concession if Adnoc wants a partner from the country with the prospect for the greatest future demand and if Adnoc deems the technical aspects of CNPC’s bid strong enough, Mills said. Adnoc is seeking to boost the amount of oil it can extract from its fields to 75% of reserves, double the 35% of crude countries have historically been able to recover, Michael Townshend, regional president of BP Middle East, said last week. That requires “near perfection” in reservoir management, he said. Murban grade crude pumped from Adnoc’s onshore fields can be exported from the Jebel Dhanna port in the Gulf and from Fujairah, the UAE oil trading hub that sits beyond the shipping chokepoint at the Strait of Hormuz. The Strait, separating the Gulf from the Indian Ocean, is the world’s most important transit bottleneck for oil shipments, according to the Energy Information Administration. “This deal will contribute to Japan’s stable supply as exports from the block will bypass the Strait of Hormuz,” Miyazawa said at the trade ministry press conference. The agreement will provide Inpex about 90,000 barrels of oil a day, which is equal to the company’s equity stake in production from the concession, Ryo Minami, head of the ministry’s oil and gas department, said at the press conference.




Oman: Commissioning of Musandam Gas Plant in July Oman Obvervor + NewBase

A major oil and gas processing plant under development at Tibat in Oman’s Musandam Governorate is due to enter the commissioning phase in July ahead of commercial launch planned later in the year.

The strategically important scheme is being implemented with an investment in excess of $600 million by Oman Oil Company Exploration and Production (OOCEP), the upstream energy subsidiary of the wholly government owned investment vehicle Oman Oil Company. When fully operational, the plant will provide natural gas as fuel for the governorate’s first ever gas-fired Independent Power Project (IPP), ending an era of diesel-based electricity generation in this northern enclave of the Sultanate. According to OOCEP’s chief executive officer, Salim al Sibani, the plant will process well fluids from the existing Bukha field offshore platforms in Block 8, as well as future flows from Blocks 17 and 40 operated by PetroTel offshore Musandam. “The plant will cater to multiple scenarios coming out from the offshore blocks,” Al Sibani said. “Currently, the fields are producing through RAK Petroleum, and with the completion of the project by the middle of this year, we hope to see the plant commencing commercial production before the end of the year,” he added in a recent presentation of OOCEP’s upstream operations. Part of the project’s output of natural gas will be used as fuel for the proposed Musandam Independent Power Project. Another offshore export pipeline will transport sales gas from Musandam to Saqr Port in Ras Al Khaimah. The launch of the gas plant, initially slated for Q4 2014, was delayed because of the challenges of




constructing the facility in a green-field and rugged part of Tibat. Additionally, the logistics and formalities of hauling construction machinery and plant equipment across international borders posed difficulties as well.

The scope of the processing plant had to be revamped as well to suit the nature of the well fluids as well as to support sustainable operations. “We knew from the outset that we had to deal with massive quantities of H2S, for example. Later, we had to add an LPG extraction (component), which wasn’t there in the original scope. Captive power had to be added as well.” Given the green-field and mountainous nature of the construction site, levelling works took around 18 months. “Thus, from May 2011 when site activities started, through to December 2014 when virtually 99 per cent of the project had been completed, the project had gone through a massive

transformation to enhance its multiple processing capacities and capabilities in order to harness the offshore resources of that area,” the CEO said. Also in place are the pipelines linking the producing platforms to the gas plant, and the export pipeline from the plant to the UAE gas export network. Commissioning activities are slated to commence by the end of July this year with the start of commercial production planned around October-November, Al Sibani added.

Masandam

Gas Plant

Oman Oil Company Exploration and Production LLC (OOCEP), an upstream oil and gas

subsidiary of Oman Oil Co, has awarded a US$40mn engineering, procurement and

construction (EPC) contract to Abu Dhabi-based National Petroleum Construction Co

(NPCC) for installation of two offshore pipelines in the Musandam area, Emirates News

Agency (WAM) reported last week.

A new multiphase offshore pipeline will import well fluids from the Bukha field to the

Musandam Gas Plant for processing. An offshore export pipeline will also be installed to

transport gas from Musandam to Saqr Port in Ras al Khaimah, according to a press

release from NPCC. The two pipelines have a total length exceeding 30km and will be

laid underwater at a depth of up to 90m. The nearly US$40mn contract provides NPCC

an entry into the lucrative Omani market and is in line with its expansion strategy.




Algeria:Petroceltic International awards rig contract for the Ain Tsila project Source: Petroceltic International

AIM-listed Petroceltic International has announced the award of a contract for

the provision of a drilling rig between Groupement Isarene and SINOPEC for the Ain Tsila gas and

condensate field.

Groupement Isarene, the joint operating

organisation responsible for executing the Ain Tsila field development plan established by Sonatrach,

Petroceltic and Enel, successfully

completed the tendering process resulting in the award and signature of

the contract to SINOPEC.

The 1500 horse power rig,

which is now built and ready to ship, will drill up

to 24 new development wells. The first 12 drilling

locations, all in the northern region of the

field, have already been selected and approved.

The award of the rig contract represents the

achievement of a further

milestone for the Ain Tsila project and will enable drilling to commence on schedule in 2015.

The Front End Engineering and Design of the project which was awarded in September 2014 to Chicago Bridge and Iron is also progressing well. The

Groupement has launched the process to identify suitable companies to perform the Engineering, Procurement and Construction ('EPC') contract via publication of an invitation to pre-qualify in the Algerian Bulletin of Public Tenders in the Energy and Mine Sector.

The Groupement is in receipt of a number of submissions, and it is anticipated that a shortlist of potential bidders who will be formally invited to tender for the EPC

contract will be established shortly.




Oman’s biggest Pilot Solar Project by Renaissance commissioned in Fahud

Times of Oman

Pilot Solar Project at the Renaissance Permanent Accommodation for Contractors (PAC) in Fahud was inaugurated on Monday by Salim bin Nasser Al Aufi, Undersecretary of Ministry of Oil & Gas, accompanied by His Highness Sayyid Tarik bin Shabib bin Taimur Al Said.

The solar project will be largely considered to become the Sultanate's primary source of power generation and will be add to the current power generation in Oman as it is a cheaper alternative to gas, Al Aufi said. "I think these projects are more strategic than commercial. At some point in time gas and fuel prices will rise while solar panel prices will fall. It won't take time to actually have renewable energy as a primary source of power and hydrocarbon as a backup system in case something does not go well," said Al Aufi.

"It (solar power) is definitely not going to phase out the oil and gas industry but will be an addition to them. I don't personally see it as a threat; I think it is complimenting what we do and we need to embrace it constantly," he added.

We definitely give top priority to develop alternative energy. Presently, Oman is using quite a lot of gas to generate power and our consumption is going up by 10 per cent on an annual basis. So we need to concentrate on renewable energy, not necessarily as a cost effective way of generating power but as a strategic way to develop the technical know-how and further develop it to make it more cost effective in the future, Al Aufi said.

The Renaissance Pilot Solar Project at Fahud is by far the biggest solar power project in Oman. I hope Renaissance will continue to develop the project for everyone else to follow, he added.




The innovative project consists of 4,000 polycrystalline solar panels designed as 10,000 square metres of shaded car parking. The novel concept saves additional design and structural costs, while generating up to 2.2 million kWh ( 6.0 MWH )of renewable energy annually, meeting almost all of the facility's daytime electricity needs. In addition to providing energy, it also saves about 25 barrels of oil a day.

The project's environmental benefit includes reduction of 1,500MT carbon emissions annually, which is equivalent to planting 580 acres of trees or not driving 4.5 million kilometres. The panels are not limited to PACs but small and medium enterprises (SMEs) can also pursue a sustainable source of power if they wanted to, a Renaissance official said.

"We do a lot of research to find the panels that are good for this climate and systems that are good for maximising the potential of solar energy. We will be

able to implement such similar project for others if they are interested," he added. This is Renaissance's first project in Oman to provide renewable and sustainable energy.

"At Renaissance we ensure we carry out our business in a responsible and sustainable manner and this solar project is the latest and most important statement of our stewardship of the environment. How we conduct our business is important to all of us. It matters to our customers, our investors, the communities in which we serve, and it matters to all of us who work in the company," said Ananda Fernando, MD, Renaissance Services.

"This initiative meets our long-term strategy to enhance energy efficiency at our PAC and reduce our overall carbon footprint," he added. The potential for solar power is high in the Sultanate, with its high ratio of 'sky clearness' and one of the highest solar energy densities in the world. Moreover, His Majesty's Vision 2020 strategy envisions up to 10 per cent of Oman's total electricity requirement to be met by renewable energy sources.




Mauritania: Kosmos Energy makes significant gas

discovery offshore Source: Kosmos Energy

Kosmos Energy announced Monday that the Tortue-1 exploration well, drilled to test the Tortue West Prospect, which forms part of the Greater Tortue Complex, in Block C-8 offshore Mauritania has made a significant, play-opening gas discovery.

Based on the preliminary analysis of drilling results and intermediate logging to a depth of 4,630 meters, Tortue-1 has intersected 107 meters (351 feet) of net hydrocarbon pay. A single gas pool was encountered in the primary Lower Cenomanian objective.

The Lower Cenomanian is comprised of three excellent quality multi-Darcy reservoirs totaling 88 meters (288 feet) in thickness over a gross hydrocarbon bearing interval of 160 meters (528 feet). A fourth zone 19 meters (62 feet) thick was penetrated within the secondary Upper Cenomanian target over a gross hydrocarbon bearing interval of 150 meters (492 feet).




Andrew G. Inglis, chairman and chief executive officer, said:

'Volumetrically, the Tortue-1 well has far exceeded our pre-drill expectations and has discovered a large scale gas resource. Our seismic imaging indicates the areal extent of Tortue West could cover approx. 90 sq kms that will be better defined with appraisal drilling. Importantly, given the results and excellent well-to-seismic calibration, the Tortue-1 well has significantly de-risked our large and under-explored 27,000 sq km deepwater position in Mauritania. Our acreage offers substantial follow-on prospectivity including a diverse range of Cenomanian as well as deeper Cretaceous plays and fairways with strong dependency.' An appraisal program is being planned to delineate the Tortue West discovery. In addition, the Marsouin-1 exploration well, located in the central part of Block C-8, is expected to spud in the third quarter of 2015. An exploration program is also being formulated to test the other prospects in the Greater Tortue Complex, which extends into the St. Louis Offshore Profond Block in Senegal, including the Tortue East andTortue North prospects. In support of this program, a 3D seismic survey acquired over our Senegal blocks in 2014 is currently being processed and interpreted. Brian F. Maxted, chief exploration officer, said:

'This significant play-opening discovery validates our frontier exploration strategy where we are now one in three in our ‘Second Inning’ campaign. Our results demonstrate that our organic deepwater exploration business model, which targets early access to build large acreage positions with significant follow-on dependent prospectivity, can deliver significant value for our shareholders.'

Located approx. 285 kms southwest of Nouakchott in 2,700 meters of water, and drilled with the Atwood Achiever drillship, the Tortue-1 well is now drilling to the planned total depth of approx. 5,250 meters. Kosmos currently owns a 90 percent interest in the Tortue Prospect, along with Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM) at 10 percent. Since 2012, Kosmos has held rights to conduct exploration in the C-8, C-12 and C-13 contract areas under production sharing contracts with the Government of Mauritania.

In March 2015, Chevron Mauritania Exploration, a wholly owned subsidiary of Chevron Corp, acquired a 30% non-operated interest in the C-8, C-12 and C-13 contract areas under production sharing contracts. Chevron has an option to elect to participate at a 30% interest in theTortue Prospect, subject to Chevron paying a disproportionate share of their costs related to the Tortue-1 exploration well. The blocks are contiguous, range in water depth between 1,000 and 3,000 meters, and have combined acreage of

approx. 27,000 sq kms.




Indonesia:Cooper Energy's Bunian-3 development well flows oil Source: Cooper Energy

Cooper Energy reports that the testing of the Bunian-3ST2 development well foreshadowed in the Update dated 21 April has begun successfully with oil flows from the primary targetTRM3 sand.

Following an initial cleanup period, the TRM3 sand flowed for 2 hours at a stabilised flow rate equivalent to 1,742 barrels per day of oil through a ¼ inch choke, with a flowing tubing head pressure of 500 psi. The flow consisted of oil and gas with no water. Measurements to quantify the gas rate are ongoing. The flow rate achieved was limited by the capacity of available surface facilities. Oil flows are being directed to a temporary production facility and produced

oil is being trucked directly to market. Further flow testing of the TRM3 sand is being conducted to gather additional data. On completion of the initial evaluation of the TRM3 sand, flow testing of the K1 sand will be conducted. Analysis of the increase in reserves will be completed after the completion of the production tests.

Cooper Energy Managing Director David Maxwell said 'these encouraging initial results are consistent with post drill expectations and will assist with the identification of additional reserves in this reservoir'.

The drilling rig was released on 23 April and has been moved off site while maintenance work is carried out prior to commencing the drilling of Tangai-5. Joint Venture participants in the KSO Tangai-Sukananti Block are Cooper Energy Ltd (Operator 55%) and Mega Adhyaksa Pratama Sukananti Ltd (45%). Background

Bunian-3 ST2 is an onshore well in the Sukananti KSO, South Sumatra, Indonesia. The Bunian structure is a four-way, fault bounded anticline defined by the 2011 Sukananti 3D seismic survey. Bunian-3 is located 730 metres southwest of Bunian-1 and the primary target is the Talang Akar Formation TRM3 Sand. Bunian-1 was drilled in 1998 and initially tested at 1,585 barrels of oil per day. Bunian-1 has produced 993,000 barrels of oil from the TRM3 sand and is currently producing at approx. 200 barrels of oil per day.




Kazakhstan: Condor Petroleum receives Zharkamys contract extension Source: Condor Petroleum

Condor Petroleum has announced that the Government of Kazakhstan has approved an extension to theZharkamys West 1 exploration contract for ten months until December 14, 2016. The Zharkamys exploration contract will be amended in due course.

Drilling Update: A drilling contractor has been selected to drill the KN-501 Primary Basin well. The well location will be constructed in May and drilling is expected to commence in June. The KN-501 well offsets the Company's play opening KN-E Primary Basin discovery by 8 kms and is located under the same salt dome. The well is planned to reach 4,250 meters and is targeting 67 MMboe unrisked mean prospective resources (internal Company estimate).

Working Capital: The Company's current working capital is CA$55 million and the Company has no debt. About Condor: Condor is a Canadian based oil and gas company with a 100% interest in the exploration rights to the 3,777 sq km Zharkamys West 1 Territory located in Kazakhstan's Pre-Caspian basin. The Company is listed on the TSX under the symbol 'CPI'.




Madagascar: Sterling Energy acquiring 3D seismic over the

Ambilobe Block. Source: Sterling Energy

AIM-listed Sterling Energy has provided an update on activities in the Ambilobe

Block, located offshore Madagascar.

Sterling has commenced its planned 3D seismic survey of 1,250 km² over a high-graded portion of the Ambilobe Block. The acquisition is being undertaken by CGG

Services, on behalf of the Joint Venture Partners, and completion is expected within 45-50 days. A further announcement regarding this survey will be made once

acquisition is completed.

The Ambilobe PSC, awarded in 2004, is in Phase 2 of the Exploration Period with all minimum work commitments for the current phase completed. In December

2013, Sterling completed a farm-out agreement with Pura Vida under which all

costs associated with the acquisition of the discretionary 3D seismic programme, up to a maximum of US$15 million, are carried by Pura Vida. Sterling expects that the

carry will cover all the costs of the 3D seismic survey. Sterling and Pura Vida each hold a 50% interest in the Ambilobe Block with Sterling as operator.

Details of the Ambilobe PSC can be found in Sterling's Investor Presentation which

can be viewed on the Company's website.

The Company's Chief Executive Officer, Eskil Jersing said:

'We are looking forward to safely and efficiently acquiring the first 3D seismic survey on the Ambilobe Block; providing valuable new data which will be used to identify

potential drillable prospects.'




Oil Price Drop Special Coverage

Oil falls more than 1 percent as U.S. crude stockpiles expected to hit high (Reuters + NewBase

Oil fell more than 1 percent today Tuesday , 28 April 2015 , ahead of weekly U.S. crude inventory data that is expected to hit another high and as Saudi Arabia pledged to supply more oil to China if needed.

U.S. commercial crude stockpiles were expected to have risen for a 16th straight week last week, up from a record 489 million barrels even as drilling activity fell, a preliminary survey by Reuters showed on Monday.

Comments made by top Saudi oil officials on Monday reiterated the country's position of keeping production high to meet demand as it maintains its market share. Brent June crude futures had dropped 83 cents to $64.00 a barrel by 0152 GMT. U.S. June crude had declined 85 cents to $56.14 a barrel.

The fall in prices "reflects the major gains that have been made in the last few weeks and a little bit of concern over what the inventory numbers in the U.S. might show," said Michael McCarthy, chief strategist at CMC Markets in Sydney.

Brent crude hit 4-1/2 month high last week, while West Texas Intermediate (WTI) has risen for six consecutive weeks, underpinned by net long positions on both contracts as speculators bet on a decline in U.S. shale output.




The number of active U.S. rigs drilling for oil has fallen to the lowest since 2010 and the U.S. Energy Information Administration expects to see a drop in oil output in May from April, the first monthly decline in four years.

"It's pretty clear production is being pulled back and finally we're seeing the impact of lower rig counts," McCarthy said.

"There is potential for a bounce back in inventories if that was only a temporary aberration, but, of course, if the recent trend continues, we should see some support."

The two oil benchmarks are sitting above key technical levels, with Brent above $64-$64.50 and WTI above $56, he said.




Traders Seen Mispricing Oil as Spending Slump Signals Crunch by Bill Lehane

Oil traders are mispricing crude futures for later this decade because they’re underestimating how

a collapse in spending will affect supplies, according to consultants who advise energy producers

and analysts.

Prices could rise to about $100 a barrel by 2019, about 34 percent above where Brent crude oil futures for that year are trading, says JBC Energy GmbH, a Vienna-based company that’s followed oil markets for more than two decades. Energy suppliers cut about $126 billion of expenditure following last year’s price drop of almost 50 percent, estimates Wood Mackenzie Ltd., an Edinburgh-based consultant.

Oil plunged as OPEC responded to a global glut by insisting that suppliers outside the 12-nation group join in any effort to eliminate the surplus, keeping its own output unchanged at 30 million barrels a day. The investment decline is at odds with how future oil prices traded this year: immediate ones have started to recover from the crash, while those for the end of decade have continued their slump, as this graphic shows.

“The longer and the lower the current oil price slump goes on, the faster and higher the bounceback in the oil price will be further down the line,” Luke Parker, director of corporate research at Wood Mackenzie, said by phone April 24. “There have been volumes taken out of future production growth.”

While the most-traded front-month contract for Brent rallied 14 percent to about $65 a barrel this year, it remains 43 percent below where it was in June. Later-year futures may have dropped as a result of producers using the contracts to hedge future sales prices, says JBC Energy.

$90 a Barrel

Royal Dutch Shell Plc, Europe’s largest oil company, assumed oil prices will average $90 a barrel from 2018 to 2020 when it said it intended to acquire BG Group.

Pipelines run toward oil storage tanks stand at the Enbridge Inc. Cushing

storage terminal in Cushing, Oklahoma. Energy suppliers cut about $126

billion of expenditure following last year’s price drop of almost 50

percent, estimates Wood Mackenzie Ltd.,




December 2020 Brent futures dropped about 5 percent this year to $75 a barrel and by 24 percent since July. Prices will probably rise above that level by the end of the decade, according to Parker.

“Our view is that we will see another spike in oil prices in 2019 above $100 per barrel for Brent,” said David Wech, managing director of JBC. “Globally, every year we have to replace about 3 to 3.5 million barrels per day of natural decline and that will be a challenge for the global upstream industry and the U.S. shale industry alone cannot counter balance that.”

The industry has cut its per-barrel costs for extracting oil by about $18 to $72 a barrel for 50 of the world’s biggest producers, Wood Mackenzie estimates. Still, reduced investment will have more influence on long-term prices than any savings that can be made, said Paul Horsnell, a London-based analyst at Standard Chartered Bank Plc.

“We find it inconsistent that prices could possibly stay low for an extended period given the degree of supply-side damage that’s been done,” Horsnell 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

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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 28 April 2015 K. Al Awadi

NewBase 592 special 28 April 2015

Economy & Finance

Transcript of NewBase 592 special 28 April 2015