Oil Review Middle East 6 2014 by Alain Charles Publishing

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VOLUME 17 | ISSUE 6 2014

Covering Oil, Gas and Hydrocarbon Processing UK £10, USA $16.50

 Saudi Aramco’s expansion plans  Tackling the talent crunch  Effective fire detection and prevention solutions  Increasing oil supply through EOR  Cutting the operational costs of compressors  Harnessing the benefits of the Intelligent Field

Managing contractual risk to prevent

cost overruns

Khalid Al-Falih, CEO of Saudi Aramco, has announced a US$40bn a year investment programme See page 52

Serving the regional oil & gas sector since 1997

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 Editor’s note WE FOCUS ON Saudi Arabia in this issue, as Saudi Aramco ploughs ahead with a US$40bn a year investment programme to maintain its status as the world’s top ranking oil producer, as well as increasingly diversifying its portfolio. The oil giant is also increasingly focusing on R&D, as is petrochemicals company SABIC, with collaboration increasingly sought in this area. Our feature on Recruitment & Reten tion underlines the continuing need to address critical issues that impact the industry such as the skills gap, as well as some recent initiatives to promote increased participation of women in the oil and gas sector. Our HR Forum: Oil & Gas, to be held in Dubai in November, will feature panels of expert speakers and will provide an opportunity to explore some of these areas in depth. As always we bring you news of the latest oil and gas related developments as well as features and analysis on topical issues. I welcome your feedback.

Serving the world of business

Editor: Louise Waters Editorial and Design team: Bob Adams, Prashant AP, Hiriyti Bairu, Sindhuja Balaji, Andrew Croft, Ranganath GS, Rhonita Patnaik, Louise Quick, Prasad Shankarappa, Zsa Tebbit, Nicky Valsamakis and Ben Watts Publisher: Nick Fordham

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Publishing Director: Pallavi Pandey Magazine Sales Manager: Camilla Capece  +971 4 448 9260  +971 4 448 9261  camilla.capece@alaincharles.com

Contents

International Representatives China

Ying Mathieson  (86) 10 8472 1899 - (86) 10 8472 1900  ying.mathieson@alaincharles.com

India

Tanmay Mishra  (91) 80 65684483  (91) 80 40600791  tanmay.mishra@alaincharles.com

Nigeria

Bola Olowo  (234) 8034349299  bola.olowo@alaincharles.com

South Africa Annabel Marx  (27) 218519017  (27) 46 624 5931  annabel.marx@alaincharles.com UK

USA

Steve Thomas  (44) 20 7834 7676  (44) 20 79730076  stephen.thomas@alaincharles.com Michael Tomashefsky  (1) 203 226 2882  (1) 203 226 7447  michael.tomashefsky@alaincharles.com

Head Office: Alain Charles Publishing Ltd University House, 11-13 Lower Grosvenor Place, London SW1W 0EX, United Kingdom  +44 (0) 20 7834 7676  +44 (0) 20 7973 0076

Exploration & Production

Petrochemicals

A detailed round-up of the latest E&P news from around the region

Gas 12

LNG in the Middle East

Technology 80

Hacking into the region’s cybersecurity threat

Harnessing the benefits of the Intelligent Field

Minimising the risk of cyber attacks

Effective fire detection The challenges of fire detection for the oil and gas industry and potential solutions

Deploying the new technologies and practices relating to the Intelligent Field can help companies achieve their goals

Risk Management Contractual risk management

Innovations

Shrinking margins and declining returns on assets make excellence in capital discipline essential

Recruitment & Retention 38

Saudi shale boom shifts energy narrative Saudi Arabia is developing its shale sector as an engine for development

Health & Safety

www.oilreview.me email: oil@alaincharles.com

Saudi Arabia

Rig refurbishment today Rig repair and refitting is big business in the Gulf, with the UAE at the centre of activities

Saudi Aramco grows its presence in chemicals The company is becoming a global competitor in chemical products

Developments in the LNG markets and future prospects

Saudi Aramco pushes ahead Spearheading a US$40bn a year investment programme

Executives’ calendar and event news

Analysis

Chairman: Derek Fordham Printed by: Emirates Printing Press, Dubai.

Subscriptions:  circulation@alaincharles.com

Saudi Aramco Developments

Calendar 16

Developments The latest news on petrochemicals projects from around the region

The latest news on gas projects from around the region

Middle East Regional Office: Alain Charles Middle East FZ-LLC Office 215, Loft 2A, P.O. Box 502207, Dubai Media City, UAE  +971 4 448 9260,  +971 4 448 9261 Production: Nikitha Jain, Nathanielle Kumar Donatella Moranelli, Nick Salt, Erica Sesay and Sophia White  production@alaincharles.com

Developments

Industry developments A round-up of the latest product advancements in oil and gas

104 Rig count / project databank

Breaking down the barriers for women in oil and gas

Arabic

Recent initiatives to promote further participation of women in the industry

News / Analysis

Arabic front cover pic courtesy of Saudi Aramco Issue 6 2014

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ď&#x192;¨ Market News

Oil prices fall as demand growth slows OIL PRICES FELL sharply in August, the second consecutive monthly decline, due to plentiful crude supply and slowing demand growth, according to the International Energy Agency's (IEA) latest monthly report. A strong US dollar also added pressure, making oil more expensive for buyers using other currencies. ICE Brent futures tumbled below US$100 bbl on 8 September for the first time in over a year, as US production continued to surge and OPEC output remained above its official 30mn b/d supply target. Despite the conflicts in Iraq and Libya showing no sign of abating, their effect on global oil market balances and prices remains muted. Exports from Libya are recovering despite ongoing violence, while Islamist militants that swept through northern Iraq have yet to trigger a major outage in OPECâ&#x20AC;&#x2122;s second-biggest producer.

Source: IEA 4

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OPEC output in August was just slightly down from July due to lower Saudi and Iraqi production. The latest dip in Saudi supply seems primarily to reflect reduced import demand from US refiners as well as weaker-than-expected crude demand in Europe and Asia. Latest statistics show that demand growth slowed to below 500 kb/d year-onyear in Q2 2014 for the first time in two and a half years. Demand projections for Q3 2014 have been revised downwards, as have forecasts for 2014 and 2015 as a whole. Although demand growth is still expected to gain momentum, the expected pace of recovery is now looking more subdued, said the IEA. Saudi exports are likely to have run below 7mn b/d for the last four months, their lowest level since September 2011. Exports

to the US led the drop amid rising Saudi domestic demand for crude burn and refinery runs. State oil company Saudi Aramco appears to be pricing oil out of the US market by ratcheting up Official Selling Prices to North America, while those to Asia have come off, likely setting the stage for a broad rebalancing of trade flows, according to the IEA.

Oil prices fell sharply in August (photo: DHL)

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 E&P

Egypt signs oil exploration deals for US$187mn EGYPT HAS SIGNED oil and Egypt has begun repaying its debts gas exploration deals worth to foreign oil companies, which US$187mn, stated the amount to nearly US$6bn country’s petroleum ministry. According to Reuters, the agreements cover seven exploration areas. Germany’s RWE won two exploration blocks in the Gulf of Suez, Tunisia’s HBSI, Canada’s TransGlobe and Italy’s Edison secured five blocks in Egypt’s western desert. In December 2013, Egypt’s General Petroleum Corporation (EGPC) and Natural Gas Holding Company (EGAS) announced an international auction for oil and gas exploration concessions in the Suez Canal, Egypt’s western desert, the Mediterranean sea and the Nile Delta. However, exploration companies have been hesitant to develop untapped gas pockets in Egyptian waters, partly because the amount paid by the government barely covers their investment costs. On the other hand, Egypt’s energy costs have been rising due to high subsidies on fuel. The report added that the country has started repaying some of its debt (amounting to nearly US$6bn) to foreign oil companies.

Seawater to be used to maintain Iraqi oil production WHILE IRAQ IS considered one of the major oil producers in the world, an imminent water shortage might jeaopardise the country’s production capabilities. A report in Reuters stated that a multibillion dollar seawater injection project, considered core to Iraq’s oil production, is entangled in red tape.

Iraqi oilfields require water to maintain production levels

Aqualis Offshore signs contract with Saudi Aramco NORWEGIAN OFFSHORE MARINE and engineering consultancy Aqualis Offshore has signed a contract with Saudi Aramco to provide rig moving services. According to the deal, Saudi Aramco’s jack-up rigs operating in the Gulf will receive moving services and personnel support from Aqualis' office in the Middle East. The deal will last until 2017 but the value of the contract has not been disclosed, added local reports. “We may be a young company, but our team consist solely of highly experienced personnel with 10 to 30 years’ of offshore experience. The experience has secured this prestigious and strategically important contract,” said David Wells, CEO of Aqualis ASA.

Oman’s IBD Group hoping to build oil refinery in Argentina OMAN’S IBD GROUP signed a preliminary agreement with the government of Argentina to explore possibilities of setting up a heavy oil refinery in the South American country. The Argentinian government was represented by its embassy in Rome. The agreement was signed in Rome on 1 September 2014, stated the Muscat Daily. IBD was represented by its CEO Sayyid Mohamed al Said. The Argentinian delegation included Doris Capurro, vice president of communications at Argentina’s state-owned oil and gas company YPF, food and agriculture producer Claudio Andreoli, president of Argentina’s general economic federation Ider Jose Pedretti and eminent businessman Eduardo Eurnekian, stated IBD in a press release. The IBD delegation included Nader Zaid, business development director, and Stefano Donzelli, manager of sales at Foster Wheeler Italy, which already is in a joint venture in Oman with IBD. “In collaboration with our alliance partner, Foster Wheeler Engineering Co, a leader in refinery technology and currently executing

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Issue 6 2014

IBD might build an oil refinery in Argentina FEED for the Duqm Refinery, we are confident of the right partner to assess the viability of the refinery,”said al Said. The refinery development, if proven viable, will be extended into petrochemical industries and fertiliser plants, a statement added. Besides the refinery, the agreement would allow IBD to explore possibilities of developing and utilising shale gas reserves recently discovered in Argentina, which are considered to be among the largest in the world.

The project was announced in 2010 and is being helmed by Iraq’s South Oil Company. Through the seawater injection project, oil can be flushed to the surface to overcome decline in production in oilfields like Rumaila, West Qurna, Zubair and Majnoon. The first phase of the project is designed to pump 5.2mn bpd of treated seawater from the Gulf to the fields. Shortage of water in Iraq is especially hampering production at two main southern fields – West Qurna-1 and Zubair, said official and industry sources. Output from West Qurna-1, operated by ExxonMobil, has fallen almost 40 per cent to around 300,000 bpd compared to 2013. ENI-run Zubair oilfield’s production was at 280,000 bpd. A source at the state-run South Oil Company said production from Zubair had fallen, but declined to give further details. The water injection project, which was supposed to be completed by 2013, is not due to come online before 2018 or 2019, added sources. Oil executives have also stated that procuring approved contracts for service work, such as building new pipelines and drilling wells, as well as getting visas and customs clearance are also not easy. Officials confirmed the decrease in oil production but there has been no update on the status of the seawater injection project. Now, young oilfields such as Lukoil’s West Qurna-2 and and Royal Dutch Shell’s Majnoon may start feeling the pressure by 2016 or 2017 as they need water to manage their reservoirs and lift output, added industry sources said.

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 E&P

PT Pertamina inaugurates drilling rig to explore for oil in Algeria INDONESIAN OIL AND gas company PT Pertamina inaugurated a drilling rig, that will be used for oil exploration projects in Algeria. The rig, produced by PT Citra Tubindo Engineering, was designed in February 2014 and will be handed to PT Pertamina in October 2014. Costing US$26mn, the rig is 10 per cent less expensive than imported oil rigs used by the company, said Pertamina officials. The company operates 65 per cent of Block 405A offshore Algeria. According to The Jakarta Post, Pertamina acquired oil and gas assets in Algeria from ConocoPhilips for US$1.75bn. It also purchased a 10 per cent participating interest in the West Qurna-1 block in Iraq from ExxonMobil Iraq Limited in 2013. PT Pertamina is exploring oil and gas assets in the Middle East, in an attempt to ease dependency on energy imports, added The drilling rig will used to explore for oil The Jakarta Post. offshore Algeria

WesternZagros Resources resumes field operations in Iraq CANADA-BASED company WesternZagros Resources Limited has resumed field operations on the Garmian and Kurdamir blocks, following the stabilisation of industry conditions and return of third party oilfield services in the Kurdistan Region of Iraq (KRI). In August 2014, the company withdrew non-essential personnel from field locations and company branches, after consulting with the Ministry of Natural Resources in the Kurdistan Regional of Government. The company’s operations remain safe in the KRI, confirmed officials from WesternZagros Resources Limited. Simon Hatfield, CEO of WesternZagros Resources Limited, said, “We look forward to completing the Sarqala-1 work over, the testing of Hasira-1, and the further development of the existing production facilities on the Garmian Block. On the Kurdamir Block, following the submission of the Development Plan on 31 August 2014, we look forward to spudding our first horizontal well at Kurdamir-4.”

Keppel FELS signs contract worth US$227mn with Gulf Drilling International KEPPEL FELS LIMITED has signed a contract with Qatar’s Gulf Drilling International (GDI) for US$227mn to build a jackup rig. According to officials from Keppel FELS Limited, the jackup rig is a repeat high-specification KFELS B Class, which would be named Halul. It would be chartered to Qatar Petroleum (QP) for five years and is Keppel FELS has built five jackup rigs scheduled to be delivered to them by Q1 2016. In for GDI addition, GDI also has options for two more rigs for delivery in 2017, the officials added. Halul is the fifth KFELS B Class jackup rig ordered by GDI. The fourth rig called Dukhan was delivered in August 2014. Other rigs include Les Hat, Al Khor and Al Zubarah. Halul will be designed to operate in and adapt to the temperature and conditions in the Middle East. The rig is equipped with larger spud cans for reduced bearing pressure and it can cover larger areas, especially in seabeds where soft soil is predominant. The rig can drill wells through 9,144 metres. It features offline stand building capabilities and 7,500 PSI mud pumps, with accommodation for 150 people, revealed Keppel FELS in a statement. Wong Kok Seng, managing director of Keppel O&M offshore, “We are pleased to have been chosen by GDI to build another benchmark jackup rig. The KFELS B Class has established itself as a reliable high specification jackup rig for the Middle East with more than 10 such rigs successfully operating there.” Aside from providing rigs, the company’s Qatari shipyard, the Nakilat-Keppel O&M, is supporting GDI with the construction of a liftboat and the maintenance of a rig fleet, added Seng.

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China largest importer of Middle Eastern oil CHINA IS TURNING out to be one of the largest importers of oil from the Middle East. Research done by the Brookings Institution has revealed that China imported 2.9mn bpd of Middle Eastern oil in 2011, which accounted for 60 per cent of China’s oil imports. Comparitively, the USA imported 2.5mn bpd from the Middle East in 2011, accounting for 26 per cent of US oil imports. Energy demands in China have been growing, placing greater stress on its energy reserves. The US Energy Information Administration (EIA) has estimated that China accounted for nearly a third of the global oil demand growth in 2013. For 2014, the EIA expects China will surpass the US in net oil imports on an annual basis.

China imports 5.6mn bpd annually Overall, China imports 5.6mn bpd, of which half comes from the Gulf region, with Saudi Arabia, Oman and Iraq the leading providers of oil to China. Much of the country's oil and gas imports are through the sea, with the Strait of Hormuz and Strait of Malacca as the key passages. For the past decade, Saudi Arabia has been the top supplier of oil to China. Now, Iran and Iraq are showing veritable reserves of oil. One of the main reasons behind the dependence on oil from the Gulf is that China has not developed its own reserves. In addition, the US has started relying on its own reserves of oil and shale. According to a report in the Wall Street Journal, the US will halve its reliance on oil from the Middle East by the end of the decade and completely wean itself off it by 2035. The Middle East will, however, continue to play a crucial role in the decisions of US foreign policy makers due primarily to its influence on global prices, observed Carlos Pascual, energy official at the US State Department. Source: The Brookings Institution

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 E&P

Petroceltic International and Edison International to explore Egyptian oilfield A JOINT VENTURE (JV) comprising Petroceltic International PLC and US-based Edison International has emerged as the succesful bidder for the North Port Fouad block, located offshore the Nile Delta in Egypt. The North Port Fouad also lies adjacent to the North Thekah Block, which was awarded to a Petroceltic and Edison JV in 2013. The combined area of both licences exceeds 7,000 sq km, stated officials from Petroceltic International. Regional and seismic evidence indicates that Nile Delta oligocene and levantine basin miocene plays are likely to be present in North Port Fouad. Major hydrocarbon discoveries have been reported in both plays in recent years. Petroceltic International has a 50 per cent nonoperated interest in North Port Fouad, which has an initial three-year term. The three-year term entails the acquisition of 1,000 sq km of 3D seismic data. The new licence will be formally awarded in early 2015 following the ratification and finalisation of the production sharing contract. Brian O’Cathain, chief executive of Petroceltic, said, “We are delighted to have been awarded the North Port Fouad Block, which along with the North Thekah, gives Petroceltic access to a substantial acreage position in the outer Nile Delta and Levantine Basin plays.” The JV also operates an adjacent block

Gulf Drilling International and Qatar Petroleum sign contracts worth US$4.1bn GULF DRILLING INTERNATIONAL (GDI) has signed US$1.4bn worth of contracts with Qatar Petroleum (QP) for the provision of onshore and offshore rigs. Each of the four new contracts and four contract extensions GDI signed with QP has a five-year term, said officials from GDI. The new contracts have been concluded for the provision of two new offshore drilling rigs Dukhan and Halul and two new land rigs GDI-7 and GDI-8. The contract extensions allow the continuation of services performed by four land rigs GDI-1, GDI-2, GDI-3 and GDI-4. Mohammed bin Saleh Al-Sada, managing director of QP, said, “The new contracts will allow continuing, as well as expanding, the important development work QP is undertaking. Each of the contracted rigs is being customised to meet the best in class criteria specified by QP.”

GE and Petrojet Egypt inaugurate 1,000th sucker rod pumping unit GE OIL & Gas and Petrojet Egypt inaugurated the 1,000th API-certified sucker rod pumping unit in Cairo. GE’s well performance services (WPS) includes the Lufkin product line, which has historically focused on manufacturing artificial lift solutions including beam Petrojet’s fabrication unit is in Kattamia pumping systems, hydraulic pumping units, plunger lifts, gas lifts, progressive cavity systems, automation equipment, as well as well optimisation and services for the oil and gas sector. The 1,000th pumping unit manufactured locally in Egypt by Petrojet is a milestone for the company, highlighting its competencies in meeting the requirements of the Egyptian domestic oil and gas sector, stated officials from GE. Rami Qasem, president and CEO of GE Oil & Gas for the Middle East, North Africa and Turkey, said, “One of the core commitments of GE to Egypt is to promote localised manufacturing that strengthens the domestic supply chain for the oil and gas sector. The achievement by GE’s WPS highlights our ability to deliver advanced technological solutions to our customers faster as well as provide them the required support services locally.” Petrojet’s key fabrication facility is located in Kattamia, and has been manufacturing process static equipment for oil and gas plants for 25 years. GE officials added that a two-day training event would be conducted, which would include progressive cavity pumps, gas, plunger and hydraulic lifts, beam pumping systems, electric submergible pumps and surface pumping systems, GE well automation and optimisation and GE Power to Lift solutions.

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OPEC’s August 2014 report reveals price fall THE ORGANISATION OF Petroleum Exporting Countries (OPEC) released its August report, according to which the OPEC Reference Basket fell by US$2.28 to US$105.61 per barrel, amid worries regarding supply disruption and weakerthan-expected refinery crude demand in Asia and Europe.

OPEC’s headquarters in Vienna Nymex WTI in July lost US$2.75 to stand at US$102.39 per barrel and ICE Brent slipped US$3.78 to US$108.19 per barrel. Global economic growth for 2014 and 2015 remained unchanged at 3.1 per cent and 3.4 per cent respectively. This was above the expected GDP numbers in the US, which led to an upward revision to this year’s US GDP growth forecast to two per cent from 1.6 per cent. This also lifted the Organisation for Economic Cooperation and Development (OECD) forecast for 2014 to 1.8 per cent from 1.7 per cent, while 2015’s OECD growth forecast remains at two per cent. The positive developments in the OECD have been counterbalanced by downward revisions mainly for Latin American economies. Growth forecasts for China and India remain unchanged. The forecast for world oil demand growth in 2014 has been revised down slightly to 1.10mn bpd, following a weaker performance of the OECD in Q2 2014. For 2015, demand growth is expected to be around 1.21mn bpd, in line with the previous report. The report added that the summer season has lent support to the gasoline market in the Atlantic Basin. Increasing inventories and higher refinery runs are exerting pressure on the US market. European margins have shown a temporary recovery on the back of falling Brent crude prices. In Asia, strong light distillate demand offset increasing supplies of the product with several refineries back from maintenance, preventing a further decline in margins.

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 Gas

Dana Gas secures US$100mn term facility for offshore UAE project DANA GAS SUBSIDIARY Dana Gas Explorations FZE has secured a US$100mn term facility for the Zora Field Development Project offshore Abu Dhabi. The facility will contribute towards the completion of the project in order to bring the Zora gas field on stream. The Zora gas field spans the territorial waters of Sharjah and Ajman and comprises a tilted fault block structure with a closure of some 25 sq km. Once on stream, Zora will provide an additional source of gas for local power generation in the northern emirates, with an expected production capacity of 6,650 boepd. Emirates NBD Bank will act as the global facility agent, term facility agent, security agent and account bank for the deal, with Barwa Bank acting as the Murabaha investment agent for the Shariah tranche of the loan. The repayment for the term facility will

span a period of 15 quarterly investments and will commence in the second half of 2015 on completion of the project and once gas production has begun, subject to a cash sweep mechanism, Dana Gas said. The facility is currently scheduled to mature on 30 November 2018. Up until June 2014, Dana Gas has spent approximately US$49mn as part of the equity financing for the project. Patrick Allman-Ward, CEO of Dana Gas, said, “This financing agreement demonstrates the confidence leading banks and financers have towards the Zora project. The project work is proceeding as per plan and we remain committed towards bringing the project on stream in the first half of 2015. Natural gas produced from the field will provide a much needed source of clean energy for the benefit of the northern emirates of the UAE.”

A US$100mn term facility will contribute towards the completion of the Zora Field Development Project (Photo: Icethorn)

Dolphin Energy passes production milestone DOLPHIN ENERGY HAS celebrated reaching a significant production milestone after its announced that it has produced five trillion standard cubic feet (scf) of gas since it began operations in 2007. Since achieving full throughput in February 2008, Dolphin Energy has delivered two billion scf of natural gas per day to the UAE and Oman, and is currently meeting 30 per cent of the UAE’s energy requirements . “This is a proud moment and is testament to the hard work and dedication of our teams, the support of and input from our shareholders and our strategic partner Qatar Petroleum,” said Ibrahim Ahmed Al Ansaari, CEO of Dolphin Energy. “Utilising the skills, experience and expertise we have at our disposal has made this achievement possible, as has an unstinting commitment to maintaining the highest levels of asset performance and integrity, safety and security. “This has allowed us to make a significant contribution to maintaining energy security for the southern Gulf region and meet an increase in customer requirements when the need arises,” he added. Abu Dhabi’s Mubadala Development Company owns 51 per cent of Dolphin Energy, with French oil major Total and US-based Occidental Petroleum each Dolphin Energy Tower in Doha, Qatar owning 24.5 p er cent.

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Egypt signs US$500mn gas loan with World Bank EGYPT HAS SIGNED a US$500mn loan with the World Bank to provide natural gas to households in Egypt. Najla Ahwani, minister of international cooperation in Egypt, said, “The loan will help fund a Petroleum Ministry plan to connect 850,000 houses, particularly in rural Upper Egypt, to a natural gas grid.” According to a ministry statement, Egypt will pay back the World Bank loan over a 30-year period, with a f ive-year grace period. Hartwig Schafer, bank country director for Egypt, Yemen and Djibouti, at the World Bank, said, “Conversion to piped natural gas will help give households access to a safer, more reliable and cheaper supply of gas compared to buying LPG cylinders.” The World Bank’s current portfolio in Egypt comprises 25 projects for a total commitment of US$4.9bn.

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 Gas

Iran opens region’s largest gas storage facility THE LARGEST GAS storage facility in the Middle East has been launched in the northeast of Iran. The Shourijeh gas facility, located in the province of Razavi Khorasan, has the capacity to supply 20mn cu/m of gas per day during winter months and will increase Iran’s gas delivery capacity to 10mn cu/m of gas per day during its first phase. Approximately seven million cu/m of gas per day is currently being injected into the facility, which has a storage capacity of 4.8bn cu/m of natural gas. The facility will transfer gas to provinces throughout Iran, including North Khorassan, Khorassan Razavi, Mazandaran, Gilan and Ardebil. The Shourijeh gas facility has the capacity to supply 20mn cu/m of gas per day during the Iranian winter (Photo: Dave Crosby)

Cape signs service contract for Pearl GTL plant in Qatar ON-SITE SERVICES PROVIDER Cape has signed a five-year contract with Pearl Gas to Liquids (GTL) to provide multi-disciplinary maintenance services to the gas-to-liquids plant in Qatar. The Pearl GTL, a joint venture between Shell and Qatar Petroleum, is the world’s largest gas-to-liquids plant and one of the most complex and challenging energy projects ever commissioned, Cape said. Located in Ras Laffan Industrial City, Pearl GTL will convert natural gas into cleanerburning fuels. Cape will provide scaffolding, painting, insulation, and refractory services with approximately 175 workers on-site. Cape East operations director for Qatar, Samir Chopra, said, “This contract will provide a solid base of maintenance activity for the Qatar business and enable us to build on our world-class expertise of supporting Qatar Shell GTL in the achievement of its long-term maintenance needs. “We look forward to working closely with our client, and supporting them in delivering safe, efficient and productive facilities for years to come,” Chopra added.

Turkey turns to Qatar for LNG supply deal QATAR HAS SIGNED a deal with Turkey to supply the country with 1.2bn cu/m of LNG. According to officials, Turkey will import nine tankers of LNG from Qatar beginning at the end of this year or at the start of 2015. Turkey energy minister Taner Yildiz said, “We are making our preparations for the winter. Though, it is little less than what we wanted.” Sources said that Turkey last week received only about 30 per cent of its oil demand from Russia because of a drop in pressure in its western import line, creating fears that the country would experience further cuts during its winter months. Matthias Keuchel, head of gas operations at Enerjisa, warned that the Turkey’s daily gas demand during winter could rise to 215mn cu/m, with current infrastructure only capable of supplying 193mn cu/m. In 2013, Qatar had raw gas reserves totalling 247 trillion cu/m — the third

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Kuwait Energy Company selects UOP equipment solution to treat natural gas HONEYWELL’S UOP HAS been selected by Kuwait Energy Company and its partners to condition natural gas to meet pipeline specifications, and to recover valuable natural gas liquids at Iraq’s SIBA gas field. The modular equipment will be used to process 110mn standard cu/f per day of natural gas at the field located in the south of the country, which will be processed via two parallel processing trains that will begin production in 2015. The UOP solution for the project will include the supply and installation of UOP acid gas removal units, UOP Callidus thermal oxidisers, mechanical refrigeration, condensate stabilisation and water treatment. Rebecca Liebert, senior vicepresident and general manager of UOP’s gas processing and hydrogen business unit, commented, “This project demonstrates that UOP’s pre-fabricated modular equipment is a solution for monetising gas quickly, particularly in challenging conditions. “UOP modular equipment is designed to allow Kuwait Energy Company to reduce field construction time, enabling the company to begin processing gas and earning revenue faster than with traditional field-built units, while also lowering its capital and operating costs.” The SIBA gas field is operated by Kuwait Energy Iraq Ltd., a wholly-owned subsidiary of Kuwait Energy Company, and is a joint development project between Kuwait Energy Iraq, Turkish Petroleum Overseas Company, South Oil Company and Missan Oil.

Qatar’s raw gas reserves totalled 247 trillion cu/m in 2013 (Photo: Ken Hodge)

largest after Russia and Iran. Around 52.6 per cent of its gas production was allocated to LNG exports.

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 CALENDAR 2014/2015

Executives’ Calendar 2014/2015 OCTOBER 2014 15-16

Iraq International Oil & Gas Expo

BAGHDAD

www.ifpiraq.com

19-21

Ethylene Middle East Technology

MANAMA

www.ethylene-me.com

26-28

Negotiation in Oil & Gas

DOHA

www.cwcschool.com

28-29

Offshore Energy

AMSTERDAM

www.offshore-energy.biz

NOVEMBER 2014 3-5

SABIC Technical Meeting

JUBAIL

www.stm-11.com

10-13

ADIPEC

ABU DHABI

www.adipec.com

12-13

FPSO Vessel Summit

HOUSTON

www.wplgroup.com

23-25

HR Forum: Oil & Gas

DUBAI

www.hrforumoilandgas.com

24-26

SAOGE

DAMMAM

www.saoge.org

DECEMBER 2014 2-5

OSEA 2014

SINGAPORE

www.osea-asia.com

4-7

Basra Oil & Gas

BASRA

www.basraoilgas.com

9-11

Mediterranean Offshore

ALEXANDRIA

www.moc-egypt.com

JANUARY 2015 13-15

Gas Arabia Summit

DUBAI

www.theenergyexchange.co.uk

19-22

World Future Energy Summit

ABU DHABI

www.worldfutureenergysummit.com

Readers should verify dates and location with sponsoring organisations, as this information is sometimes subject to change.

Talent management to be addressed at new HR forum for oil and gas industry OIL REVIEW MIDDLE East has launched a new conference dedicated to finding solutions to the looming talent crunch in the oil and gas sector. The HR Forum: Oil & Gas will take place in Dubai on 23–25 November 2014 and will bring together experts from Saudi Aramco, Mubadala Petroleum, Gazprom International, Kuwait Petroleum Corporation, ZADCO, Reliance Industries Limited and the Petroleum Institute, among others, to discuss key solutions to dealing with the talent crunch. Additionally, HR experts from Deloitte & Touche and Bain & Company will be on hand to advise delegates on how best to manage and improve their talent pool. Major topics open for debate and discussion include how to recognise high-potential talent, develop virtual leaders, find and keep mentors, attract more Arab women into the workplace, build capabilities and develop on boarding strategies for maximum engagement. Additionally, there will be two special, practitioner-led workshops by Kuwait Energy and Saudi Aramco on how to deal with difficult people and how to change behaviours for better communications. This timely forum will be a new opportunity for HR and talent management professionals to come together, share knowledge, network with their peer group and walk away with effective solutions to the ever present challenge of the talent crunch. For additional information, please visit: www.hrforumoilandgas.com

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Issue 6 2014

Dr Emma Langman, manager of HR and performance at Kuwait Energy, will be one of the speakers at November’s HR Forum: Oil & Gas

Rob Veersma, director of training and development at Gazprom International, will discuss the merits of virtual working

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2:21 PM

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 Event News

OFG to celebrate five years of bringing together oil and gas professionals ONE OF DUBAI’S leading oilfield networking events will celebrate a major anniversary in October having brought professionals from across the region together on a regular basis for five years. Since it was established in 2009, the Oilfield Get Together (OFG) has grown into one of the region’s leading industry networking events providing attendees with the opportunity to discuss the issues affecting their industry with like-minded professionals in an informal environment. “It has been an honour to watch OFG grow from strength to strength in the last five years,” said OFG chairman and founder Jimmy Larsen. “What started off as a meeting of minds has now grown into the leading oilfield networking event in Dubai where business really does take place. “It gives industry leaders a great opportunity to connect and keep on the pulse with current market trends in the UAE and on an international level.”

Attendees at a recent OFG event held at Ruth’s Chris Steak House in Dubai Marina

In August, OFG attracted more than 90 attendees

Leading engineering, procurement, construction and installation company McDermott will sponsor the next event, which will take place on 30 October at Ruth’s Chris Steak House in The Address Dubai Marina. McDermott is focused on executing complex offshore oil and gas projects worldwide and will sponsor the 52nd edition of the event. To mark the fifth anniversary, OFG has planned to put on a memorable day with a strong focus on industry leaders and oilfield heavyweights, including founding members of OFG. OFG board member Hany Mwafy remarked, “Celebrating five years of OFG is certainly an achievement and we look forward to the anniversary event in October where we will see some of the true heavyweights from the industry get together at this unparalleled oil and gas networking luncheon.” OFG provides oilfield professionals with the opportunity to meet other industry leaders in a relaxed environment where business is the focus of conversation. The monthly event will take place at the award winning Ruth’s Chris Steak House.

Abu Dhabi set to host annual safety and competency conference in November 2014 THE FIFTH EDITION of OPITO Safety and Competency Conference (OSCC) will be held at the Fairmont Bab Al Bahr Hotel in Abu Dhabi on 4 November 2014. Suhail Mohamed Al Mazrouei, minister of energy for the UAE, will inaugurate the gathering of oil and gas operators and contractors. Together with training organisations, delegates will discuss and examine how to improve standards of safety and competency to protect the workforce and the industry’s reputation. Some of the keynote speakers at the event include Bob Stewart, commentator on conflicts; Karen Darke, inspirational mountaineer; and Peter Cohen, motivational speaker, who will talk about this year’s theme ‘Leading from the frontline’. The event will be chaired by Gordon Ballard, chairman of OPITO and Schlumberger UK. Al Mazrouei said, “The safety of those working in the energy industry is an absolute priory and it is vital that we continue to discuss how we continually improve the standards of safety and competence. “OPITO has provided the industry and all stakeholders with a highly valuable platform and we are delighted they continue to run this event in the UAE. I urge as many people from the

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Issue 6 2014

UAE minister of energy Suhail Mohamed Al Mazrouei said that OPITO has provided the industry and all stakeholders with a highlyvaluable platform (Photo: OPITO)

industry in our region to attend and demonstrate their commitment to the safety of their workers.” According to organiser The BIG Partnership, OSCC 2014 will explore the dynamic of effective leadership and change management on human behaviours in relation to safety. The event will also outline how the industry can support a safer and more competent workforce. David Doig, group chief executive of OPITO, added, “This year’s conference will provide delegates with valuable lessons on the impact effective leadership and change management can have on workplace safety. “As the conference reaches its fifth year, it is encouraging to see support continuing to grow as we examine ways we can further improve safety worldwide. Previous conferences have been very successful in stimulating debate and we expect this year’s OSCC to provide further thought and discussion as well as influential networking opportunities.” Shell will be the headline sponsor of the event, which will also be supported by IHRDC, Maggie Braid Associates and Petrofac. More than 400 delegates from around the world will be expected to attend this year’s edition of the event.

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Competitive Solutions for Complex Projects

Lamprell has played a pro ominent role in the development of the energy industry y in the Middle East for over 35 years and is the regional market leader in the rig construction and refurbishment busines ss. W We e are the leading non-Asian yard for new build sub-350 feett class rigs with larger rigs well within our core capabilities and we w have extensive full re efurbishment, upgrade and conversion experien nce.

Lampre re e Delivers ell s First st Class s Safety Highly Skillled Workforce Client Satis sfaction World Clas ss Quality Schedule Certainty C

New build ja ack u up rig during jackkin ing trials

Lam mprellâ&#x20AC;&#x2122;s largest rig conversio on and refurbishment project

www.lamprell.ccom

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 Analysis

LNG in the

MENA region Nicholas Newman outlines developments in the LNG markets and assesses future prospects. INCE THE FIRST two LNG tankers carrying 5,000 cu/m of LNG left the Algerian port of Arzew for the UK and France in 1958, the global annual trade in LNG has grown in value to reach US$150bn, accounting for some 10 per cent of the global trade in natural gas. Today, 24 countries export LNG to around 29 countries. Qatar, Malaysia, Australia, Nigeria and Indonesia are in rank order the world’s top five LNG exporters. Asia Pacific countries dominate the global market for LNG, notably Japan, South Korea, China and India. The LNG trade is expected to grow at

Qatar's Pearl GTL project is the largest gas to liquids plant in the world

The North American shale gas revolution promises the beginning of US LNG exports”

a compound annual rate of 2.8 per cent between 2013 and 2019 (Hellenic Shipping News, 11 July 2014), underpinned by rising Asian demand. The Middle East and North Africa (MENA) countries hold a large percentage of the world’s natural gas supplies and provide more than a third of world LNG exports. Algeria, Kuwait, Iran, Saudi Arabia, UAE and Qatar are among the biggest holders of the region’s gas reserves. Qatar is currently the

world’s largest LNG producer and exporter. However, Qatar is expected to cede its crown to Australia by 2017, since its own exports are limited by the 2005 moratorium on increasing LNG exports as well as by rising domestic demand, and since Australia has 83mn tonnes per annum LNG capacity coming on line by 2017. Qatar’s main markets currently lie in Asia, Europe and other MENA countries. Oman and Yemen’s chief markets lie in Asia.

Qatar tops the list of LNG exporters, ahead of Malaysia, Australia and Nigeria

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 Analysis

For Algeria, the original supplier of LNG, Sonatrach reports exports of around 2.1 tcf a year (as noted by Bloomberg in January 2014), chiefly destined for Europe. While Egypt has proven gas reserves of 77 tcf, the third largest in Africa after Algeria and Nigeria, its exports have fallen due to the government’s diversion of gas promised for export to the domestic markets, causing foreign energy companies like BG to declare force majeure. Libya, Egypt and Iran’s LNG exports are currently disrupted by economic and political turbulence. Natural gas is liquefied in dedicated export liquefaction terminals in Algeria, Egypt, Oman, Qatar and Yemen. These are listed, together with planned projects, in Table 1. LNG projects take years to construct and are costly. To be commercially viable they need buyers willing to sign longterm contracts under traditional prices linked to oil, and for oil prices to remain high. The most significant exporters of LNG today can be seen in Table 2.

High and rising costs in Australia and uncertainty over the sustainability of high oil prices may threaten planned LNG projects” The changing LNG market The North American shale gas revolution has meant an end to LNG imports in the USA and promises the beginning of LNG exports as early as 2017. By the end of 2013, US gas developers had applied for export permits amounting to 380bn cubic metres equal to all the world’s current liquefaction capacity. Just one-third of this capacity would threaten the viability of higher-cost capacity additions in countries including Australia, Russia and across the African continent (McKinsey, Capturing value in global gas: prepare now for an uncertain future, July 2014). In Europe the economic slowdown, combined with energy efficiency improvements and the availability of cheap coal, has reduced demand for gas. However, for its energy security, given the current uncertainty of Russian gas supplies, we can expect a permanent upswing in European demand for LNG, much of which is likely to come initially from Algeria and Norway. Asian demand has driven global demand for LNG, which has been met largely by Australia and South East Asian countries as well as from Qatar, Oman and Yemen. But how much of the demand for gas in Asia

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Issue 6 2014

Table 1: MENA’s LNG export liquefaction terminals Existing Export Terminals Algeria

Skikda

Algeria

Bethioua

Egypt

SEGAS Damietta LNG

Egypt

ELNG IDCO LNG

Planned Export Terminals

Iran

Tombak NIOC LNG

Terminal Iran

Pars LNG Terminal

Oman

Qalhat

Qatar

Qatargas 1

Qatar

Qatargas 2

Qatar

Qatargas3

Qatar

Qatargas 4

UAE

ADGAS

Yemen

Yemen LNG

Source: Bloomberg, EIA, IEA

Table 2: Top 10 LNG exporters Countries

Table 3: Top 10 markets for LNG

Volume of Exports (mn tonnes per annum)

Countries

Qatar

77.4

Japan

Malaysia

23.1

South Korea

36.8

Australia

20.8

China

14.8

Nigeria

20.0

Spain

14.2

Indonesia

18.1

India

14.0

Trinidad

14.4

Taiwan

12.8

Algeria

11.0

10.5

Russia

10.9

France

7.5

Oman

8.1

Turkey

5.7

Brunei

6.8

Italy

5.2

Source: International Gas Union World LNG Report 2013 Edition

will be supplied by LNG imports in the future is dependent not only on China’s development of shale gas, but also on Australian and Russian LNG project costs, which are only commercially viable with sustained high Asian LNG prices. A noteworthy and relatively recent development is the rise in domestic demand for LNG within the Middle East region itself, due in part to the lack of pipelines connecting gas fields with markets and insecurity of pipeline supplies as well as gas shortages stemming from the demands of rapidly growing populations and economic development. George Sarraf, a Dubai-based Partner with Strategy & (formerly Booz & Co), commented recently that demand for power in the region is growing by seven to 10 per cent a year. Gas rich MENA countries now account for three per cent of global LNG imports, and this can be expected to increase. Dubai and Kuwait import LNG through floating storage and regasification unit (FSRU) projects. Dubai’s Jebel Ali LNG Terminal, a FRSU, completed in 2010, is to be joined by

Volume of Imports (mn tonnes per annum) 87.3

Source: International Gas Union World LNG Report 2013 Edition

a planned new LNG import terminal at Fujairah. Insecurity of gas pipeline imports underpins Jordan’s current construction of a new US$65mn LNG import terminal at Aqaba, which will allow cheap LNG to supplant expensive oil and diesel used for power generation.

Future developments Rising costs in Australia and uncertainty over the sustainability of high oil prices may threaten, delay or even derail planned LNG projects in Australia, East Africa, the Middle East and Russia. Indeed, as Sarraf observed, more gas co-operation between GCC and Middle East countries would provide benefits to all in terms of balancing supply and demand and optimising infrastructure needs. Moreover, North America has the potential to become a serious rival to both Middle East LNG producers, plagued by political disturbances and terrorism, as well as Russia. To protect domestic users from high gas prices, the US government has granted export permits for only 80 bcm per year of LNG to date. n

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Ansell Healthcare â&#x20AC;&#x201C; Middle East 1 Lake Plaza 22-02, PO Box 125299, JLT, Dubai. United Arab Emirates. Tel: +971 4 452 3232 E-mail: info@ansell.eu Web: www.ansell.eu

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 Analysis

Rig refurbishment

today Rig repair and refitting is big business in the Gulf, with the user-friendly UAE at the centre of activities. ITH RIG CONSTRUCTION costs heading skywards and the necessary technical skills in short supply, the rig repair, refit and refurbishment business is growing as never before in the Gulf. A rig refurbishment project can range from a simple topside repair to a major docking lasting several months for the upgrade or replacement of obsolete and / or damaged equipment and machinery. This can include fitting or repairing a complete jack-up leg. Last September, Lamprell, based in Jebel Ali Free Zone and a leading provider of engineering services to the on- and offshore energy industries, was awarded a major rig refurbishment contract by the Millennium Offshore Services (MOS) group relating to the conversion of the MOS Frontier. The Frontier is a three-legged MLT116C jack-up structure valued at over US$60 million. This rig is a multi-purpose unit capable of operating in water depths of up to 100m. At the refurbishment contractors’ Sharjah facility it is being converted into an accommodation support vessel housing 290 workers. CEO James Moffat commented at the time of the award for this local high-profile project, “Lamprell has a well established track record for undertaking major rig refurbishment projects … it is pleasing that one of our existing clients has awarded us a new contract for one of the largest refurbishment and conversion projects in our history.” Since 1990, this company has carried out over 350 similar projects; the Rowan California, currently located in the Aegean Sea,

A rig refurbishment project can range from a simple topside repair to a major docking lasting several months” 24

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Issue 6 2014

Rig construction costs are heading skywards

had been handed over just as the MOS contract was inked. The company maintains that to remain competitive, today’s rig owners are required to provide operating companies with efficient and reliable drilling services from safe platforms that can include jack-ups, fixed units, semi-submersibles and drill ships. Lamprell says it can work on upgrading them all. The company has developed its own state-of-the-art refurbishment facilities in both Port Khalid and the Hamriyah Free Zone to match its docking operations with deep-water berths that can cope with today’s multi-million rig designs. Other well known local customers recently served by these facilities include Saudi Aramco and Arabian Drilling Company. Eversendai Offshore RMC FZE is another rig refurbishment specialist operating at various locations in the Gulf, with new waterside facilities in RAK’s Maritime City as well as a modern yard in Qatar. This is a subsidiary of the major Malaysian EPC contracting business of a similar name. The company’s various facilities here offer complete new-build and refurbishment services including: • Complete rig conversion and modification • Comprehensive engineering design and technical support • Drilling systems and configuration, including hulls, engines including genset replacements, and complete repowering • Accommodation provision and refitting to the latest international standards • Helideck upgrading and complete fitting where necessary • Leg(s) inspection, repair, extension and replacement where necessary. Recently, Dubai’s Drydocks World completed a major refurbishment project on National Drilling Company’s (NDC) offshore Al Ghallan rig. Also UAE-based, the contractors said the works were part of a series of four repair-and-refurbish projects signed with NDC last year alone; a similar eight had been successfully completed earlier. The company claims a well-established reputation for its refitting operations within this growing business, having successfully dry-docked (so that access can be gained from all sides), inspected and repaired more than 100 offshore platforms, drilling rigs and vessels over the years.

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Analysis 

Chairperson Khamis Juma Buamim said in July this year, “We are grateful to NDC for their continued faith in our services. As a regional service provider, we are delighted to work with prominent companies in the region and make a contribution to the growth of the offshore oil and gas sector. “Our facility has three large graving docks and well-equipped workshops that provide us with the flexibility of addressing assignments that are of a highly challenging nature.” NDC’s Abdalla Saeed Al Suwaidi added, “These major refurbishment projects performed in parallel with the fleet expansion plans to obtain advanced offshore and onshore rigs are contributing considerably in strengthening NDC’s operational excellence and sustaining the maximum levels of safety, environment protection and effective performance.”

Major engineering upgrades on rigs and support vessels fit with the local vision to diversify the economy” Why is it that the UAE is the centre of so much of this essential high-tech activity in the Gulf today? The UAE’s excellent international communications – in all forms – are certainly a major asset; essential compact spares and components including technical personnel can be brought in with just a few days notice. The central location for servicing operators from Saudi Arabia to Oman and Yemen is handy too. And the various waterside cities’ infrastructure including accommodation is second to none. Major engineering upgrades on rigs and support vessels fit perfectly with the local vision to diversify the economy beyond reliance on the sale of oil and gas. But serious competition from other GCC states can be expected soon. The UAE’s excellent international communications are a major asset

Finally, most of the above applies to large offshore structures and floating facilities which require a costly drydocking operation for inspection, even before any major repair or refitting work is contemplated. But if it is a land rig that is needing major work – usually a much simpler operation – an alternative solution might be arranging for the delivery of a brand-new structure from a dedicated manufacturer like National Oilwell Varco. Some suppliers like this specialise in rapid-deployment packages that are specially designed to be trucked in within a few days, sometimes with fewer than 30 vehicle loads. And these can involve a minimal requirement for the hire of heavy lifting equipment to assemble and erect the mast. Sometimes a matching bundle of special lightweight engine generator sets and other topside plant is available to power and control the rig at a remote location, or during the assembly process itself. n Issue 6 2014

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 Analysis

Could the Red Sea solve a

Saudi headache? Nicholas Newman assesses Saudi Arabia’s drive to explore the Red Sea. NTIL RECENTLY, WHEN one thought of oil in the Middle East one thought of the massive mature oil fields of the Gulf. The 2010 report by the US Geological Survey on the Red Sea Basin estimated reserves of at least five billion barrels (mean volume) of undiscovered technically recoverable oil and some 112 tcf of recoverable gas. Egypt has made significant discoveries along its part of the Red Sea and has aroun d eight billion barrels of proven hydrocarbon reserves in its waters. However, while Saudi Arabia’s state-owned oil company Saudi Aramco has not disclosed its own estimate of the Red Sea's potential, external analysts have put forward their own estimates. “There could be up to 100bn barrels of oil equivalent (boe) under the sea bed,” claims Gulf analyst Kevin Baxter, quoted in Energy Pro newswire in Novemb er 2013. Other analysts put the figure at around 50bn, an amount which would still increase reserves by 18 per cent. Whatever the speculated numbers, “What Aramco considers a large field is much bigger than expected elsewhere,” said Professor David Macdonald, Professor of Petroleum Geology at the University of Aberdeen in a telephone interview in July. Today, encouraged by sizeable discoveries in the East M editerranean Sea, the Nile Delta and Egypt’s Red Sea waters as well as, crucially, the need to boost gas production to meet rapidly rising domestic energy demand and to free up crude oil for export, geologists are surveying the Saudi side of the Red Sea

Saudi Arabia discovered the Al Haryd deep-water oilfield in the Red Sea in 2013

Saudi Arabia is likely to need to bring in foreign companies with deep-water expertise” on behalf of Saudi Aramco. The company’s oil and gas research and exploration budget is the highest in its history, focusing on frontier areas in the Red S ea and complex reservoirs onshore and offshore.

Saudi Red Sea exploration During the 1960s, drilling in the shallow waters of the Saudi Arabian side of the Red Sea by foreign oil companies yielded disappointing results, ending both interest and

Table 1: Saudi oil and gas resources

foreign participation in the Kingdom’s upstream projects. Exploration and development of the Red Sea is likely to mean that Saudi Aramco’s policy of self-reliance will give way in favour of bringing in foreign companies with both the technology and experience of ultra-deep water locations. In 2009, contractors working on behalf of Saudi Aramco began a 15-month 2D and 3D seismic study of the Saudi side of the Red Sea, focusing on the shallow coastal waters off Tabuk before moving to the more challenging ultra-deep waters. In 2011, Saudi Aramco began a shallow water exploration drilling project in the Red Sea, said Michael Zinger of Saudi Aramco, speaking at a Houston Geological Society Dinner in June 2013. In late 2012, Saudi Aramco made a major gas find some 16 miles north west of Duba, the Ahmar-1 field of non-associated gas. According to Saudi

Table 2: Saudi Arabian power generation by fuel in 2012

Reserves

Production

Consumption

Exports

Notes

Oil

265 bn barrels

11.6mn bpd

3 mn bpd

7.5 mn bpd

Includes the Neutral Zone

Fuel

Per cent

Gas

288 tcf - 4th

N/A

3.5 tcf

Saudi Arabia does

Only 15 per cent of

per year

not import or

Saudi Arabia has been

Natural Gas Oil Diesel Fuel Oil

39 35 20 6

largest in the world

export natural gas

“adequately explored for gas”.

Source: Oxford Energy Comment, May 2013

Source: EIA 2014

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 Analysis

Aramco’s Annual Report 2013, it has discovered three oil and two gas fields including the Red Sea deep-water oil field AlHaryd, following the 2012 discovery of a gas field in the Shaur structure located in the shallow waters off the country’s North Western Tabuk province. This latter gas field is “a potential game-changer in the future of the Kingdom’s energy mix,” notes Saudi Aramco. During 2013, Saudi Aramco undertook its first deep-water drill stem test at Duba-1 in the northern Red Sea at a depth of 648m.

US$25bn project launched By the end of this year, the first of seven planned appraisal wells will be drilled in the new gas field Ahmar-1 discovered in 2012, located some 16 miles off the coast from the port city of Duba as part of a US$25bn development plan, reported 2B1st Consulting in January 2014. Saudi Aramco will drill three wells in shallow waters not exceeding 100 metres in depth and four in deep water of more than 1,000m. This gas field is forecast to produce 75mn cfd of gas and 4,500 bpd of condensate for a 20-year period. The gas will be delivered by pipeline to Duba, where Saudi Aramco is planning to build an industrial complex containing a gas central processing facility, a petrochemical plant and large power station which will be connected to the respective national power and gas grids to supply cities such as Yanbu and Jeddah along the Red Sea coast. Whether any of this resultant new gas and electricity will be exported to neighbouring Egypt or Jordan, both of which suffer from power and gas supply problems, remains an open question.

What production techniques might be used? The specific production techniques on future discoveries and the companies chosen to deploy them will be announced in 2015. However, if the reservoirs are filled with

crude, floating rigs will be used to puncture the seabed to subsea fields lying 1,000m below the water's surface. The oil is likely to be transferred via floating production, storage and offloading vessels to off-shore tankers. If the reservoirs contain large quantities of associated gas, as is the case with the Ahmar -1 field, processing facilities are necessary to separate the oil from the gas. These would be built on land and connected by pipelines to the rigs. “Such a production system would become expensive,” comments Dr Sadad Al-Husseini, retired vice president, exploration and development at Saudi Aramco and now Owner and Founder of energy consultancy Husseini Energy. In either case the production of hydrocarbons on the Saudi side of the Red Sea is unlikely to reach significant scale before the end of this decade, said Professor McDonald.

Red Sea exploration challenges Saudi Aramco customarily operates in Gulf waters not exceeding 330 feet, which is less than a 10th of the average depth of the Red Sea. Lacking both the experience and the technology for deep water operations, Saudi Aramco will have to select from amongst leading deep-water oilfield operators such as Brazil’s Petrobras, Norway’s Statoil, Denmark’s Dong Energy and the UK’s BP, which have extensive experience of deep sea operations in the North Sea and the Gulf of Mexico. Such companies “will be wellpositioned to secure work when tenders are released,” commented energy analyst Kevin Baxter, as reported by UPI in November 2013. Also, Saudi Aramco’s expertise in managing giant contracts with western companies will stand it in good stead during the rush to boost the Kingdom’s gas production. An additional challenge is the complex geology. The seafloor of the Red Sea is unstable, being composed of a thin post-salt section lying above active salt. Such

The need to increase generating capacity is a factor in the drive to discover new energy resources

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Issue 6 2014

Finding more gas is crucial in order to meet current demand as well as to secure a planned increase in generating capacity” conditions suggest that, “It is very likely that the oil will be light and have a lot of gas in it," said Al-Husseini, in the UAE newspaper The National in June 2012. Professor Macdonald reinforces the view that much of the gas discovered will be in the form of associated gas, rather than large independent gas fields.

Why the drive to explore the Red Sea and elsewhere? The main objective of the current exploration drive is to boost gas production in order to limit the use of expensive oil in power generation, as well as to meet rapid growth in demand. Saudi Aramco observes that local demand for crude has increased “to the point where volumes meant for export may fall to unacceptably low levels in the coming two decades.” In addition, fears that Saudi oil production from existing fields has peaked or is likely to peak soon underlie the Kingdom’s search for new sources of energy, including oil, solar and shale gas. Currently, Saudi Arabia consumes at least a quarter of its oil output at heavily subsidised prices, putting a strain on the Kingdom’s budget. Already, there are gas shortages, forcing industrial consumers such as power stations, petrochemical and associated downstream plants to switch to oil. The opportunity cost for Saudi Aramco is high, since it is required to supply domestic industrial customers with oil at the equivalent of US$5 to US$15 a barrel compared to Brent crude prices of around $100 a barrel. Finding more gas is crucial in order to meet current demand as well as to secure a planned increase in generating capacity from 55GW to 120GW by 2020. Saudi Aramco expects domestic gas demand to nearly triple from its current 3.5 tcf by 2030. The evident prospective shortage of gas and fears that Saudi Arabia could turn into a net oil importer by 2030 makes exploration and development of the Red Sea’s hydrocarbons a priority, albeit a very expensive way of maintaining oil export volumes. However, it will take a long time to develop the Red Sea resource. If substantial finds are made, it could also boost the economies of other Red Sea states such as Sudan, Somalia and Eritrea, says Professor Macdonald. In the meantime, reductions in energy subsidies, economies in energy usage and diversification to solar and shale could form important components in the Kingdom’s energy strategy. n

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 Health & Safety

Effective

fire detection PN Rajesh gives an overview of the challenges of fire detection and potential solutions for the oil and gas industry. IL, GAS AND petrochemical facilities are particularly vulnerable to fire. The potential costs of disaster are high in terms of disruption and loss of assets and human life. Early fire detection is crucial to prevent fires from developing quickly and enveloping plants and materials. Oil and gas companies need to take action to address incidents that might occur, however stringent the safety measures in place. Fires at oil, gas and petrochemical facilities are not unusual in the Middle East. Indeed, there were two fatal incidents claiming eight lives in total at the same refinery in 2000 and 2011, while fire broke out in August this year at the 466,000 bpd Mina Al Ahmadi refinery in Kuwait.

Key risks Some petrochemicals are notoriously volatile. Fires can be started from sources of ignition in close proximity. As the petrochemicals vaporise, they do not necessarily need to be in direct contact with the facility to ignite a fire. High temperatures, sometimes reaching over 50 degrees in the summer in the region, present a very real danger. Petrochemical facilities are complex extraction facilities and supply chains with distribution terminals, offshore and onshore plants. The potential is there for an incident involving a hazardous substance at any part of the process. Neighbouring sites must also be considered, not only in the context of fire detection, but also in terms of the potential damage that can be inflicted on them when in close proximity – for instance, at port facilities. Terrorism is more prevalent today than it has been in the past. Security must be combined with fire security systems. Fire detection solutions that employ a Visual

oilreview.me

Issue 6 2014

Oil, gas and petrochemical facilities are particularly vulnerable to fire

The cost of a disaster outweighs the cost of investing in effective safety technology” Smoke Detection solution, such as FireVu’s, can combine the two. The oil and gas industry is one where the benefits of installing fire detection and prevention solutions for facilities over and above the legal requirement more than outweigh the cost implications. There is no room for accepting risk – a factor that does not apply to all sectors. The cost of a disaster in terms of People, Environment, Assets and Reputation – the PEAR acronym – outweighs the cost of investing in effective safety technology. Higher insurance premiums for less stringent fire detection and prevention can also be factored into the financial decision making process.

Fire detection systems Fire detection solutions can generally be grouped into Aspirating Smoke Detectors (ASD), Infrared (IR) and Visual Smoke

Detection (VSD) Solutions. Each has its own attributes for different environments. Aspirating systems identify particles of smoke suspended in the air to alert safety operators to fire danger. They are highly sensitive, often detecting smoke before it is visible to the human eye. ASD can be effective in indoor environments, but it can take time for the smoke particles to reach the detectors in large spaces, thereby impacting the response time, and where outdoor locations are concerned it can be compromised further. ASD can also struggle to distinguish between dust and smoke particles. IR are transducers of radiant energy, converting radiant energy in the IR into a measurable form. Detecting IR energy emitted by objects takes away reliance on visible light, so obscured conditions should not affect their effectiveness. However, thick smoke, oil and grease can be problematic. Most IR detectors are designed to ignore constant background IR radiation, focusing on the modulated part of the radiation. However, they can be prone to false alarms when exposed to modulated non-flame IR radiation. Visual Smoke Detection is a mature technology developed, refined and tested over the past 20 years or so. It uses flame

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ď&#x192;¨ Health & Safety

as well as smoke detection and analysis of smoke to give early alerts by identifying characteristic smoke patterns across a video image. It analyses changes in a range of variables such as colour, brightness, contrast, shape, edge content, motion, colour matching and loss of detail to alert operators early to potential fire danger. Since it is a video solution, distance is no issue and it can be combined with security. It is used in the Gulf on petrochemical facilities as well as for other sites where petrochemicals are present, such as military and civilian air hangars. Detectors can be linked to alarm systems and integrated into control systems, setting off AC shut down, positive air pressurisation of escape staircases, and total suppression activities such as foam systems.

Further considerations Oil and gas facilities offer a range of hazardous scenarios. So it goes without saying that the most appropriate fire detection solution for each scenario is dependent on the danger. For example, during the construction or decommissioning of a site, high

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Issue 6 2014

PN Rajesh

temperatures are very likely. The nature and light frequency of a gas torch flame, a welding arc, or grinding sparks, are different from the light frequency emitted by a fire flame. This might have a bearing on selecting a fire detection solution. There are strong arguments in favour of having an off-site emergency control centre.

As fires around the world have shown, onsite facilities can easily be destroyed in large-scale incidents. Some systems such as IR and VSD can be remotely monitored to avoid such a potential scenario. Oil companies also need to take into account the resources that are available from the local emergency service in terms of the specialist equipment it has and how quickly it can be deployed. Can the fire detection system be connected to the emergency service? Time is of the essence. Fire detection technology is generally becoming more sophisticated and refined. Its use is stipulated to different degrees throughout the Middle East, but the cost of implementing effective solutions is more than compensated for by the benefits of minimising the likelihood of fires and their consequences. n PN Rajesh is director for Middle East, Africa and India operations at fire detection solution provider FireVu, email: enquiry@firevu.co.uk. FireVu has offices in the Gulf and representation throughout the region; contact Malcolm Gatenby, director BSSME, email bssme@eim.ae. www.firevu.co.uk

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 Risk Management

Contractual risk

management Shrinking margins and declining returns on assets make excellence in capital discipline essential for owner operators of large capital projects, says 8over8’s Clare Colhoun. NTEGRATED OIL AND gas majors face a common threat: shrinking operating margins, declining production and falling return on equity and on assets. The decline in return on capital and operating margins has caused dismay amongst shareholders and investors. Analysts warned that ‘fears over capital discipline’ were a significant factor in the underperformance of the global oil and gas sector. Yet firms have been slow to respond, and few have failed to answer the question of why the downward trend is so pronounced. Global energy companies will have to adjust their expectations for profits in order to make the investments needed to meet future world energy demand, the International Energy Agency (IEA) warns. The capital cost of producing a unit of energy – whether oil, natural gas or power – has doubled since 2000, and continues to rise even as prices for key commodities have flattened out, the Paris-based energy group said in a report released recently. “The doubling of capital costs is a serious issue,” the IEA’s chief economist, Fatih Birol, said in an interview from Paris. “Companies have to improve their capital discipline and they have to be a bit more realistic in the future about rates of return, so long as prices remain at these levels.” The easy oil is gone, hydrocarbons are harder and more expensive to extract, and the largest capital projects are increasingly complex and unpredictable. Projects also have more stakeholders, more investors, and are typically in frontier areas of the world with national government involvement. The result is significant growth in communications traffic laden with instructions, authorisations and vital content

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Issue 6 2014

Capital projects today are increasingly complex (Photo: BP)

Projects today are not only technically challenging, but fraught with risk and change” for decision-making. As such, projects today are not only technically challenging, but fraught with risk and change.

At the commercial interface Change is a given in oil and gas projects. Even the best design team that produces the frontend engineering design (FEED) will never foresee and conceive of 100 per cent of what is required to deliver the project – thus contractors will always instigate change orders. Variation requests and change orders made in communications from contractors take time to filter through to the financial teams and treasuries of owner operators. Over time, they can fester to significant levels that result in costly claims later on in projects, when it is harder to establish the origin and validity of the changes.

According to a report by McKinsey late last year, the key risks during project execution are related to contractual default, claims, keeping public political stakeholders aligned, and monitoring for mismanagement by contractors. The interface with contractors is therefore the critical element. Schlumberger reports that 35 per cent of capital projects budgeted at over US$5bn will blow out by more than 50 per cent. The significance of this figure cannot be understated: the average project size in the oil and gas industry currently stands at about US$1.9bn and continues to rise as more ‘super-sized’ mega projects come online. Several projects are averaging between US$30-50bn and upwards, with the Kashagan oilfield development in Kazakhstan standing at US$115bn, having suffered significant delays and cost overruns.

Managing contractual risk Unplanned cost overruns and poor cost recovery not only impact directly on the owner operator’s financial performance, they place shareholder value at risk. Earlier this year, shares in Spanish construction consortium Sacyr fell on news of a claim of more than US$1bn, relating to the Panama

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 Risk Management

Canal Expansion project where it had the lead construction role. The dispute between Sacyr and its contractors over liability for the additional costs resulted in a substantial delay to the work to widen the waterway. With large capital projects in the oil and gas sector increasingly characterised by several venture partners sharing both risk and return, the contracts that underpin them have many interdependencies. Clear rules of engagement must be defined in advance, both amongst the venture partners and between the venture and its contractors. Successful contract execution in groundbreaking floating LNG (FLNG) projects, such as Shell’s Prelude for example, involves developing a suite of project contracts across the FLNG value chain that creates an effective alignment of interests among each of the relevant project parties, whilst eliminating or mitigating risk. Many interdependencies also mean many open channels of communication. These channels are absolutely critical, but are risk laden in that they can drive unnecessary change into the project. The inherent risk only becomes manifest when the owner operator looks to cost-recover a percentage from a joint venture partner only to discover that the communications surrounding the change are untraceable. This is why instructions and the thread of communications that trigger a contractual change must be recorded meticulously, as the sequencing of events is relied upon in the event of arbitration.

DNA sequence Contractual risk management entails derisking the commercial engagement by ensuring that the chaotic communications that exist on a large capital project are streamlined and controlled – whether they are a communication about an instruction, an obligation, potential change, or site query. Imagine, for example, that time is a constant represented by a horizontal axis. Capital is deployed in increasingly larger amounts as construction of the project progresses over time. That capital is deployed via contracts, but without a system of engagement to provide a disciplined way of managing the risk inherent within those contracts, then the entire process is left open to change due to unnecessary, unstructured and cluttered communications channels. This occurs both internally with the owner operator and its partners, and externally with contractors. Now imagine the application of contractual risk management as being like a coil that wraps around the project timeline. The ‘coil’ is a system of record. When it is switched on, it aggregates all communications across the project timeline. Here, unstructured communications become structured under specific categories. 36

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Issue 6 2014

The timeline and the coil are intertwined, like a DNA sequence

Contractual risk management solutions integrate fully with other enterprise systems” Crucially, the timeline and the coil are intertwined, much like a DNA sequence, to provide an indisputable record of all formal contract data, communications, contractual obligations, review decisions and decision response times. By being able to retrieve, as required, auditable and irrefutable evidence held within a ‘DNA sequence’, owner operators are able to reduce instances of claims and maximise cost recovery to ensure all project and contract stakeholders bear their appropriate share of legitimate unplanned costs.

Early warning and proactive risk management Applying analytics to a combined system of engagement and system of record, where disciplined and structured communications are stored within a single platform, owner operators can start to act on the business intelligence available. For example, if a variation order request on a major project is received from a contractor and has a significant value associated with it, that communication can be routed to those that need to see it and, more importantly, to those that need to take the decision on whether or not to approve it. A further benefit is that owner operators

can measure the riskiness of a particular project. Should a large volume of variation order requests come in over a short period of time, they can be escalated to appropriate stakeholders to notify them that scope is a problem and as such the project is at risk of blowing out. Action can then be taken to avert significant value leakage and scheduling overruns in commercial relationships with contractors, which current in-house systems are simply unable to achieve. Contractual risk management solutions integrate fully with other enterprise systems and bring a disciplined approach to all communications between project partners and contractors by: • Instructing contractors, partners and stakeholders to use a single formal commercial platform for communicating with owner operators whilst executing contracts and to adopt the oil company standards as a ‘must’. All instructions and communications to and from the contractor and owner operator teams flow through this one channel in a predefined, organised way. • Connecting the engineering world with the commercial world by insisting all technical queries, instructions and otherwise are routed through the commercial channel for review, checking alignment or disparity with the contract, and then to the contractor and owner operator’s technical teams. • Gaining significant and valuable insights by analysing the commercial communication traffic that highlights priority areas of the engagement that need attention. This is a new ‘early warning’ focus on potential change requests. It allows owner operators to accept necessary changes, but, importantly, allows them to avoid unnecessary changes that can blindside a project when they fester to significant levels and result in claims.

Predictable outcomes Several of the largest super majors, majors and independents are changing the way they manage change in the execution of their capital project contracts. What is more, they are generating US$100s of millions – and even US$billions – of savings by driving greater discipline into their capital deployment processes and enhancing communications, governance and transparency. These elements are critical to realising maximum returns and mitigating contractual risk in large capital projects. Ultimately, by managing key contractual risks, owner operators benefit from connected decision-making through improved capital discipline, and therefore realise a much more predictable commercial outcome. n

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 Recruitment & Retention

Breaking down barriers for

women in oil and gas A number of initiatives have recently been established to promote the participation of women in the oil and gas industry. These include the ADIPEC 2014 Middle East Petroleum Club ‘Women in Industry’ events. UNIFIED EFFORT from the energy sector is needed to encourage women to pursue careers in the oil and gas industry, which statistics show continues to be a male-dominated field, experts said during a VIP panel discussion held in Abu Dhabi on 1 September. Challenges to bridging the gender gap were addressed during this year’s first panel discussion on ‘Women in Industry’, an exclusive series of ADIPEC 2014 Middle East Petroleum Club (MEPC) events and initiatives dedicated to women in the energy sector. Numerous reports have shown the critical role of gender diversity in meeting business goals, from sourcing talent pools to increasing profitability. However, a recent study by PricewaterhouseCoopers in association with the Women’s Oil Council looked at the 100 largest listed oil and gas companies in the world and found that only 11 per cent of board seats were held by women. The study shows that while it is clear that women play a pivotal role in the energy sector, achieving progress remains a challenge.

Addressing the challenges Offering opportunities for professional development is key to making the oil and gas industry a viable career choice for women, said Souad M. Al Hosani, President and Founder of Nexus Business Services. “Oil and gas companies can retain women in their sector by offering them leadership positions and growth in their career,” said Al Hosani. “Leading and mentoring are two important challenges that need to be looked at for women in the oil and gas sector.”

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Issue 6 2014

Participants in the ‘Women in Industry’ panel discussion

With these small but imperative steps, we are definitely moving in the right direction” These challenges go beyond the borders of the Middle East and are faced by the industry worldwide, according to experts. “This is not just a regional challenge, it is a global challenge,” said Cynthia Babski, Internal Communication Manager at Qatar Shell Service Company. “Companies need to have a pro-active plan in place that goes beyond a recruitment quota.” “For example, Shell is addressing the gender imbalance by implementing supportive and inclusive corporate policies, from designating fieldwork timings, to protocols that address work-life balance. Such policies can change the dynamic of the workenvironment, and ultimately how people perceive the industry.” Strong female networks are crucial to building a sustainable professional environment for women in the industry, said Maryam Amiri, senior communications advisor at the Abu Dhabi National Oil Company (ADNOC). “There are cultural barriers that we need to address, but these take time to change

and will not happen overnight,” Amiri said. “I would like to see a stronger support system among women. We need a ‘sisterhood’, a network of women who stand by each other, especially given these challenges that we all acknowledge. You often find this bond between men, but not so much among women because they are afraid of jeopardising their relationships.” The forum is of critical importance in light of new employment trends showing a growing number of women graduates considering the energy industry for longterm career opportunities. According to a recent report by the Economist Intelligence Unit (EIU), UAE Economic Vision: Women in Science, Technology and Engineering, women account for 50.7 per cent of graduates in science, technology and engineering (STE) and maths-related courses across all institutions, and 56.8 per cent in government universities in the 2011-2012 academic year. The report showed that among those studying STE and mathematics (STEM), and wanting to stay in STE in the UAE, the energy sector was the second most attractive industry to work in (17 per cent) after green technology (22 per cent). However, both professional and cultural barriers continue to prevent women from making a smooth transition from university into the workforce. According to the EIU report, 60 per cent of STEM respondents

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 Recruitment & Retention

with experience working in an STE environment believe that female employees face obstacles when trying to manage worklife balance, and 66 per cent of STEM respondents see cultural issues as a barrier to women in those fields.“Managers must be continuously educated about what is needed to overcome these challenges,” said Samar El Mnhrawy, Vice President of Human Resources at Baker Hughes. “For example, in addition to mandating that 30 per cent of our field engineers must be women, we offer female employees a rotation schedule that encourages them to get experience on the field. We also have specially dedicated nursing rooms for new mothers. “We have yet to fully tap into the potential of this talent pool. However, with these small but imperative steps, we are definitely moving in the right direction.” An important factor that should not be underestimated, experts said, is the pressure women often place on themselves.

Taking charge “Women should also take charge of their careers and should not be victims to circumstance,” Babski said. “Do not be afraid to voice your opinion and share your thoughts with your line manager. Make it happen for yourself. It will be difficult, but you are paving the path for others to follow.” With a local, regional and global mission to recruit more women in the energy sector, young female graduates must not be discouraged, say women pioneers in the industry.

We have yet to fully tap into the potential of this talent pool”

Women should be educated early about careers in the oil and gas industry

“Women who are truly interested in engineering should not let anyone force them to change their career paths. It can be challenging at times, but the key is to focus on the positive and not the negative,” said Mariam Al Hendi, Young ADIPEC Ambassador and a Mechanical Engineer at GASCO. “Everywhere in the UAE there are people encouraging women to pursue their dreams; it is part of the vision and mission of our leadership. People subjecting women to gender profiling must realise half the global population is female, and not harnessing the talents of women because of their gender is not only discriminatory, but also a waste of human resources.” Conference Director Claire Pallen said, “We are very excited to be hosting an official series of Women in Industry events as part of ADIPEC 2014. We are dedicated to engaging with and creating a community for women working within the oil and gas sector, whether that be engineers, administration personnel or senior managers.

A recent survey of female engineers worldwide by NES Global Talent on ‘Attracting and retaining women in oil and gas engineering’ reported the following key findings: • 75 per cent of the women that responded to the survey said they felt welcome working in the oil and gas industry, yet almost half (45 per cent) said they do not feel they get the same recognition as their male colleagues. • 89 per cent said they would encourage a female friend to pursue a career in the industry now, with 82 per cent saying they would recommend a career in the sector to someone who is due to finish their studies in a decade’s time. Some respondents said other energy industries such as nuclear and renewables could join oil and gas as attractive options in the future. • 95 per cent said mentors were important for career

The second topical panel discussion of the Women in Industry series, ‘Achieving CEO or Member of the Board status’, takes place on 13 October in Abu Dhabi and will review the current number of women working in these positions and look at the factors contributing to the glass ceiling, including cultural attitudes and male dominated environments. Both panel discussions take place at Li Beirut, Jumeirah at Etihad Towers, providing attendees with the opportunity to meet in an exclusive ‘women only’ gathering, while enjoying a private and informal, yet business-focused environment. The series will conclude with a landmark event at ADIPEC 2014 that will feature live on-stage interviews with women, outlining their journey to success in their fields. The session will take place at the MEPC Theatre on 11 November, and will offer attendees a networking opportunity where they can share their thoughts and ideas with likeminded individuals. n

advanc ement, yet 42 per cent said they were neither a mentor nor a mentee. • Respondents provided a diverse range of suggestions when asked what companies could be doing to attract and encourage women employees such as: educating women early (in secondary schools) about careers in the oil and gas industry; giving women a chance to take on more challenging offshore roles; and providing equal benefits and opportunities. • 39 per cent said they would consider taking less money in return for more work flexibility, with many citing a better work life balance and spending more time with the family as the main reasons. • 82 per cent said they planned to stay in the industry for the next two to five years.

Watch out for an interview with Mariam Al Hendi, Young ADIPEC Ambassador, in the next issue of Oil Review Middle East 40

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 Recruitment & Retention

The need for further

industry collaboration Tackling skills shortages and addressing the issue of retention are the key challenges highlighted by a recent survey. HE NEED FOR moe collaboration within the oil and gas industry to tackle the skills shortage is highlighted by the latest Global Oil & Gas Workforce Survey by Air Energi, the leading workforce solutions provider, and OilCareers.com. The survey documents the views of more than 500 professionals from across the world. “If we are going to see a real and positive change in the skills gap, the industry as a whole must work together on the development of education, training and local content initiatives,” says OilCareers managing director Mark Guest. While three quarters of respondents confirmed that their organisation offered internal training, 29 per cent of these admitted there was not a full selection of training available. Also highlighted in the survey is the on-going challenge surrounding staff retent ion as an anticipated increase in project activity in the Middle East, North America, East Africa and Australia begin to filter through. Air Energi CEO Duncan Gregson said, “The oil and gas industry is powered by a highly mobile and skilled workforce. Experienced professionals are highly sought after, highly remunerated and offered excellent benefits. The critical issue for the industry in 2014 will be retaining staff, which is one of the key factors in budget overspend and schedule delays.” Other findings of the survey include 58 per cent of respondents confirming they expect salaries to rise in 2014 and 50 per cent predicting that hiring rates will increase. Meanwhile, 69 per cent of those questioned believe more should be done to promote the opportunities within the industry to younger generations. According to the survey, engineers are the scarcest commodity followed by project managers, drilling personnel, contract administrators and geologists.

High demand in the Middle East As far as the Middle East is concerned, the survey predicts a continued high demand for all disciplines across all engineering verticals, as a result of the high level of project activity, with the strong demand for geology and geophysics personnel looking set to continue. Iraq continues to be an area of substantial growth while the number of significant projects in the UAE means intra-regional competition will become increasingly fierce. “Iraq and Qatar are our strongest areas at the moment, and we are excited about prospects in Abu Dhabi, where we have developed a number of programmes and strong relationships with clients,” says Andy Ryan, Air Energi’s vice-president for the Middle

The industry as a whole must work together on the development of education, training and local content initiatives” 42

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Issue 6 2014

What is the biggest concern to industry in the Middle East? 3.15%

3.15%

19.85%

4.40%

34.75%

34.70%

Source: Air Energi/OilCareers.com

Capital Costs

Safety Regula!ons

Economic Stability

Skills Shortages

Labour Costs

Visa/Immigra!on

East. “Saudi Arabia is very significant as well. These will be our areas of focus for the foreseeable future. We are excited about growth prospects and have opened up a number of new offices in the region. There are some exciting projects coming up, some at the FID stage.” However the situation in Syria and Iraq is, not surprisingly, having an impact on recruitment in the region. Increased competition in the EPC/PMC market from Asia in particularly, and the tight margins for such work, are increasing competition for affordable talent, according to the survey. This has meant that salaries have had to become more and more competitive, with companies having to be more creative in putting together packages for attraction and retention. Furthermore, the differential in earning potential between the Middle East and other regions of the world is not as great as it has been in the past. “We are having to source talent from previously untapped markets,” says Ryan. “The global LNG market is still exceptionally busy, and within the region itself, the national operators have very similar sourcing strategies, which impact on retention. Most clients tend to have robust risk management frameworks and processes concerning areas such as occupational health, but they do not tend to apply these risk processes to areas such as recruitment and retention,” adds Ryan. “We are working closely with clients to help them improve their retention and rehire rates.” Labour market regulations such as those restricting the free movement of expatriates from one employer to another can also present obstacles to recruitment in the region, as can lengthy visa processes, while national content policies continue to have an impact. With nationalisation programmes in place across the region, a strong focus will remain on the sourcing, training, development and retention of national workforces, according to the survey. It is noteworthy that around 35 per cent of survey respondents find skills shortages the biggest threat to the industry in the region, despite significant investments having been made in this area. “Air Energi is committed to assisting with the recruitment, training and development of nationals,” says Ryan. “We are engaging with local labour departments to help build local content.” n

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 Recruitment & Retention

Tackling the region’s

talent crunch The shortage of talent within the Middle East’s oil and gas sector needs to be addressed sooner rather than later, says Riad Mannan. OST OIL AND gas companies in this region and beyond are facing a critical talent pool shortage that could, if not tackled, hinder the long-term performance of their organisations. While the root causes of the talent crunch are clear – an ageing workforce coupled with highly specialised roles and low supply of qualified engineers and managers – the solutions to meet the challenge remain less so. Replacing this ageing workforce with highly motivated, skilled and loyal staff has become the number one priority for many companies in this sector. If they are to prosper in the future, they have to manage this ‘great turnaround’ now and ensure it is as smooth as possible. So serious is the issue that, in recent years, heads of HR and recruitment have been focusing their efforts on a global recruitment drive. However, the recruitment pool is not as big as it used to be as younger, locally-based engineers are attracted to other engineering jobs outside the oil and gas sector, perhaps offering more pay and better conditions. This brings the issue of developing a globally mobile workforce to the fore. This solution, however, has its own challenges, particularly on the ability to transfer staff smoothly from one part of the globe to another and managing that transition in a cost-effective way.

Developing strategies While recruitment is an outward facing feature of many oil and gas companies, they have also been realising that it is important to develop strategies to keep the people they already have. Managing their internal talent is a more personalised inward facing challenge, encompassing strategies for on boarding, engagement, career development, succession planning and developing leaders – in simple terms, doing all they can to keep the staff they already have. All these issues have to be interweaved, both at a strategic level as well as the delivery point. Recent research carried out by Oil Review Middle East with industry HR and talent management professionals raises some interesting questions about how to develop the capability of staff, engage them, develop virtual leaders to manage virtual work teams and create a pipeline of leaders for effective succession planning. While recruitment can play a role in meeting the talent crunch challenge, it seems that managing the talent currently in place has become a high priority. As competition for scarce human talent heats up, oil and gas companies have to develop their own internal pool of talent, devising innovative and flexible models, which are customised for their staff. This may mean more change management initiatives, proactively attracting more

Riad Mannan

As competition for talent hots up, companies have to develop their own internal talent pool” women and moving them up the ranks, or more successful on-boarding strategies, which lead to better employee engagement, performance and retention. Creating workplaces where employees feel aligned and engaged with their roles and the organisation can be a highly effective way to retain staff. Also, understanding how engagement levels are influenced by an organisation’s culture, strategy execution, leadership, structure and processes is an important step. It lets employees take ownership of their own development and it underscores the link between individual performance and business results. As the talent crunch in the oil and gas sector i ncreasingly takes hold, companies need to meet this challenge head on or face a human resource crisis, in both the office and in the field. While recruitment is one part of the solution, effective talent management is a key component of the long-term answer. n Riad Mannan is conference director of the HR Forum: Oil & Gas, to be held on 23–25 November 2014 in Dubai. This timely forum will provide a platform for oil and gas company representatives to debate not only these challenges, but more importantly, the solutions. http://hrforumoilandgas.com.

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 Petrochemicals

Bapco joins forces with Technip to offer FEED services THE BAHRAIN PETROLEUM Company (Bapco) has entered an agreement with Technip Italy S.p.A, for the provision of Front End Engineering Design (FEED) Services for the Bapco Modernisation Programme (BMP). Bapco’s chief executive, Dr Peter Bartlett, signed the deal with Technip Italy S.p.A chief executive officer, Marco Villa, in Awali. Technip will be based in its office in Rome, Italy, working to complete the critical front end development work for this mega-project by early 2016. Bapco and Technip sign a deal for the provision of The ambitious BMP has been described as Front End Engineering Design Services. not a ‘Project’ but in fact a ‘Programme’ which, in project management terms, is a group of related projects managed in a coordinated way to obtain maximum benefits. It will be the single largest investment to date for Bapco, after the recently concluded US$1.2bn Strategic Investment Programme, as a result of which the Bapco Refinery is now the first refinery in the Middle East to successfully demonstrate the capability of producing nearly 100,000 bpd of Euro V Diesel and Group III Lube Oil Base Stock. The BMP’s main goal is now to improve gross margins and ensure the refinery’s competitiveness in future years to come. The signing ceremony welcomed dignitaries from both sides, and members of the Bapco board of directors. The chairman of the board, Adel Khalil Al-Moayyed, wished all the best to both the Bapco and Technip project teams for the successful completion of the FEED work. Al-Moayyed also highlighted Bapco’s ‘one-team’ concept, which is important to the company’s work culture. Furthermore, Dr Bartlett added that it was key for both companies to establish longlasting friendships.

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Orpic invites bidders to qualify for EPC projects OMAN OIL REFINERIES and Petroleum Industries Company (Orpic) has invited bidders to prequalify for projects linked to the US$3.6bn Liwa Plastics Project (LPP) located in Sohar in the north of Oman. There will be four engineering, procurement and construction (EPC) projects, comprising a steam cracker, polymer unit, a Natural Gas Liquids (NGL) extraction unit and a 300 km-long pipeline that interested parties can bid on, said officials from LPP. Prequalification of bids for these projects will be executed in two stages. By the end of the second stage, the conception of joint consortia will also be finalised. Orpic plans to issue invitations to prequalified applicants, to tender for the four projects by the end of 2015 once the front-end engineering design (FEED) has been finalised. LPP will be established adjacent to the Sohar Refinery Improvement Project (SRIP), which is currently under construction in Sohar. The project features a 900,000 tonnes per year ethylene cracking plant as well as other plants and associated utility and offsite facilities.

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Petrochemicals

FireVu introduces the Middle East’s first Multi Detector FIREVU HAS INTRODUCED the new Multi Detector, bringing together Visual Smoke and Flame Detection and Thermopile technologies for the Middle East’s petrochemicals industry. FireVu is rolling out the first fire detection technology that features Visual Smoke Detection (VSD), flame detection and now temperature sensing technology in the form of being built in thermopile. The Multi Detector will provide petrochemical operators a solution that will detect and analyse smoke and heat patterns to raise alerts. VSD technology works by identifying characteristic smoke patterns across a video image. It analyses changes in a range of variables such as colour, brightness, contrast, shape, edge content, motion, colour matching and loss of detail so operators are ready to act if there is potential fire danger. The installation of a thermopile to detect radiated heat will have the advantage of raising alerts by using different technology. It will offer future triggers for false alarms. Steam, for example, can be removed as a danger point by setting heat www.firevu.com

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Issue 6 2014

criteria above temperatures likely to be reached. Simon Jenkins, product manager for FireVu said, “Visual Smoke Detection is already a very effective and proven technology, combining it with thermal radiated heat detecting technology gives us a solution not offered by competitors.” FireVu works with various oil and gas The New Multi Detector from FireVU installations in the Middle East and will aim to expand its presence in the industry. The Multi Detector will also be rolled out across other industries including manufacturing, food processing, power generation and air hangars. FireVu is a brand of the solutions arm of AD Network Video, part of surveillance monitoring pioneer AD Group. FireVu works with a number of oil and gas installations in the Middle East and has targeted an expanded presence within the petrochemicals sector.

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Petrochems projects plans to be discussed at Adipec THE COMPLETION OF key petrochemical and refinery projects will be announced at the Abu Dhabi International Petroleum Exhibition and Conference (ADIPEC). The event will take place at the Abu Dhabi National Exhibition Centre (ADNEX) from 10-13 November 2014. More than 60,000 oil and gas professionals from around the world will attend the three-day event exploring challenges and opportunities facing the petrochemicals industry over the next 30 years.

Adipec will be held at the Abu Dhabi National Exhibition Centre According to organisers of ADIPEC, details of the completion of the US$10bn (Dh36.72bn) Ruwais refinery expansion, the Abu Dhabi Oil Refining Company’s (Takreer) and the US$2mn Borouge project of Abu Dhabi Polymers Company will be given. The Ruwais refining complex, which is situated 240 km west of Abu Dhabi city, was launched in 1982 and is set for completion by the end of the year. The Abu Dhabi Polymers Company’s Borouge 3 petrochemical project, also due for completion by the end of 2014, will be discussed during the three-day event. Other key themes for discussion at the event will include US shale gas extraction, supply and demand dynamics for fuels and petrochemicals in the Middle East, new regional downstream projects, and new trends and technologies. A number of key officials including Jasem Ali Al Sayegh, CEO of Takreer, and Abu Dhabi Polymers Company CEO Abdul Aziz AlHajri will talk during a session on the UAE’s downstream industry. Michio Kaku, an acclaimed physicist from the USA, will make a keynote address focusing on fracking and the changing dynamics of the oil and gas industry. Ali Khalifa Al Shamsi, ADIPEC 2014 conference chairman and strategy and coordination director of ADNOC, said, “We will discuss shale gas and other nontraditional topics during the event.”

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Petrochemicals ď&#x192;§

Qatar to invest US$25bn into petrochemicals sector QATAR IS SET to inject US$25bn for the growth and development of the domestic petrochemical and chemical industry. In 2012, the Qatar Petroleum and Shell oil companies revealed plans to set-up an olefins project in Ras Laffan Industrial City at a total cost of US$6.4bn. The project will produce 1.1mn tonnes of ethylene and 170,000 tonnes of propylene per year. "Petrochemical industries in Qatar have seen a remarkable increase during the past few years," said Qatar Fuel Additives Company general manager Nasser al-Kuwari. A number of plastics manufacturing industries use low-density polyethylene (LDPE) in the production of cables and wires, injection moulds and pipes, agricultural product packaging, paint and lamination, said Qatar Petrochemical Company (QAPCO) CEO Mohammed Yousef al-Mulla. QAPCO operates a plant adjacent to existing facilities in the Mesaieed Industrial City as part of the Qatari strategy to make optimal use of natural resources in Qatar. "Qatar complies with the quality and environment protection standards in its petrochemical industries," al-Mulla added.

Advanced Petrochemical Company to invest in PDH plant SAUDI ARABIAN FIRM Advanced Petrochemical Company has announced it will invest in a propane dehydrogenation (PDH) plant with SK Gas in South Korea for the production of propylene, which is used in plastics manufacturing. The US$1bn project, which Advanced Petrochemical Company is set to commence in the will invest in a propane beginninig of 2016, will have dehydrogenation (PDH) plant with capacity to produce 600,000mt SK Gas in South Korea per annum of propylene. The board of directors of Advanced Petrochemical Company gave the go-ahead to the equity investment of 35 per cent in PDH plant with SK Gas, for the production of propylene in South Korea, through its subsidiary Advanced Global Investment Company (AGIC) which has a 95 per cent stake in Advanced and sources of AGIC equity participation will be announced later. The total cost of the project is estimated around US$1bn and the project will be financed 40 per cent equity and 60 per cent will be financed by the JV Co. through lending companies.The project has set off the construction activities and it is scheduled to be fully operational in the first half of 2016, with a nameplate capacity of 600,000mt annum. The financial impact of the new investment will be seen following the commencement of commercial operation of the project in 2016. Advanced Petrochemical star ted the construction of its plants in May 2005. The company produces 455,000 tonnes per year of propylene and 450,000 tonnes per year of polypropylene from its production facility situated in Jubail Industrial City, on the eastern coast of Saudi Arabia.

Issue 6 2014

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 Saudi Aramco

Saudi Aramco

pushes ahead Saudi Aramco is to spearhead a US$40bn annual investment drive over the next decade to maintain its number one producer status. Martin Clark assesses the oil giant’s prospects and plans. AUDI ARABIA INTENDS to maintain its position as the world’s top ranking oil producer, with huge spending plans that will drive forward developments across the upstream and downstream sectors through the coming decade. The head of Saudi Aramco, the state oil company, announced this summer that the group will roll out a capital spend of US$40bn every year over the next 10 years to keep oil production capacity steady, and to double gas output. Aramco is already the world’s biggest oil producer, underpinning global demand, but is keen to expand its gas capacity to meet fast-rising local demand from industry and the power sector. Khalid Al-Falih, the company’s chief executive, told a summer conference that he expects to see funds being directed across the board, although he singled out offshore work as being an important new thrust among the portfolio of upstream projects. Much of this capital spend will go into offshore, he said, both in large-scale projects similar to the Manifa project in the Gulf, and more recent offshore exploration in the Red Sea and Midyan fields. “Although our investments will span the value chain, the bulk will be in upstream, and increasingly from offshore,” he said. The goal is to maintain maximum sustained oil production capacity at 12mn barrels per day (bpd), “while also doubling our gas production,” he added. Al-Falih also warned about rising industry costs, which will gulp a greater share of the budget, throwing the spotlight more closely on project economics. “To tap these increasingly expensive oil

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Khaled Al-Falih, CEO of Saudi Aramco, has announced a capital spend of US$40bn every year over the next 10 years

Business as usual

Although our investments will span the value chain, the bulk will be in upstream and increasingy from offshore” resources, oil prices will need to be healthy enough to attract needed investments,” he said. “Long-term prices will be underpinned by more expensive marginal barrels.” At Aramco, project costs have already more or less doubled during the past decade despite all best efforts to mitigate cost escalation. That is the result of bottlenecks and shortages in the supply chain plus, of course, the always rising cost of utilising cutting edge technologies in the field to extract oil and gas from ever more complex and challenging reservoirs.

For the most part, this is all business as usual for Aramco’s engineers and technicians, who are quite accustomed to managing large budgets and who have worked tirelessly to grow the Kingdom’s production capacity to its current lofty heights. As Saudi Arabia’s number one economic sector - last year oil netted Riyadh US$274bn in revenues - the oil and gas industry routinely enjoys multi-billion dollar investment programmes, which have proved a rich source of work for foreign contractors and service companies. Among the large upstream projects underway is the US$3bn Khurais oil field expansion in the Eastern province, where bidding is currently in play. According to statistics from the National Commercial Bank, the oil and gas sector accounted for 40 per cent of total local construction contracts awarded during the second quarter of 2014.

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 Saudi Aramco

A lot of this was focused on the Jizan region and Aramco’s development of the Jizan refinery and terminal project there, one of a number of flagship refining initiatives underway to boost the nation’s downstream capabilities. All of this means plenty of continuing work for contractors like India’s Essar, which recently bagged a US$54mn deal to upgrade a crude stabilisation plant at the Abqaiq plant in Shaybah on behalf of Aramco. One of the challenges facing international firms, however, is a greater emphasis in Saudi Arabia on using local suppliers and equipment manufacturers. This has become something of a priority for Aramco, to support government-wide initiatives to involve Saudi nationals in the country’s leading industry as much as possible. It has promoted a raft of joint ventures between Saudi enterprises and foreign investors.

Hunt for gas Boosting natural gas production especially has become a top priority for Aramco. The search for new gas deposits is also taking centre stage as Saudi Arabia struggles to keep pace with its rapidly rising domestic demand. The country holds the world's fifthlargest proven reserves of gas, although much of its current production is associated gas linked to oil production. The Kingdom expects local gas demand, mainly for power generation, to almost double by 2030 from 2011 levels of 3.5 trillion cubic feet per year. Aramco has been spending heavily to get the ball rolling with major gas developments such as Arabiya, Hasbah and Karan, Saudi’s first non-associated offshore gas field development. One flagship scheme now being rolled out is the master gas system expansion. India’s Dodsal secured a contract earlier this year for the development of the first phase of the system expansion in Madinah, which is due in late 2017. It involves the installation of 585 km of pipelines and the construction of two gas compression stations. Not all of Aramco’s gas projects have run smoothly though, notably efforts to explore the barren Empty Quarter desert region. A number of high profile joint ventures have come unstuck in this zone after failing to find gas with the drill bit. Shell is the latest partner to announce its exit from the area, even though it did find some gas, leaving Aramco to go it alone. It is a disappointing end to what was originally seen as an exciting new initiative

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to get involved in Saudi’s lucrative upstream sector.

Unconventional gas One of the challenging areas that Aramco plans to square up to as it seeks to bolster homegrown gas production is harnessing the nation’s unconventional energy potential. The turnaround in gas production in the United States through tapping into shale has not gone unnoticed by others around the world, with many now keen to emulate this success. Saudi oil minister Ali al-Naimi has estimated the country's unconventional gas reserves at more than 600 trillion cubic feet, more than double its proven conventional reserves.

Innovation and cutting-edge technology are the key strategic enablers of our current success and future competitiveness” A number of top international companies are now showing an interest in bidding for work to develop some of this clear potential. Aramco is looking to build processing facilities, wellheads and pipelines for unconventional gas in Turaif in the northern part of Saudi Arabia where large mining project Waad al-Shamal is currently under development. It hopes to produce as much as 200mn cubic feet per day of unconventional gas by 2018 to supply the project and an associated power plant. Potential partners include South Korea’s GS Engineering and Construction, Italy’s Maire Tecnimont, Japan’s JGC and Canada’s SNC-Lavalin, according to industry sources cited recently by Reuters. Like others, Riyadh has been inspired by the recent North American shale gas surge, which has transformed the country from a net gas importer to an exporter. Saudi has begun investigating its unconventional gas reserves in various other locations including the northwest area, the Eastern Province and in the Empty Quarter, although work remains at an early stage.

Technology The test facing Aramco in the unconventional gas sector also underscores the company’s growing dependence on technology, once again, a similar theme throughout the industry.

Al-Falih acknowledged the industry’s proven track record of reinventing itself to turn challenges into opportunities and expects more of the same. “We are convinced that innovation and cutting-edge technology are the key strategic enablers of our current success and future competitiveness,” he said. It means the group is tripling its research and development manpower, and increasing its funding for this crucial area five-fold. Again, the rationale here is largely economics. Aramco is on target for increasing its oil recovery rates to 70 per cent, allowing it to add more than 100bn barrels of oil resources to an already substantial reserves portfolio. New advances in drilling and other areas will also be vital to Saudi Arabia realising its as yet untapped unconventional gas potential. On a national level, there is interest too in the renewable energy segment, with Saudi Arabia looking to solar power, in particular, to offset some of its dependence on fossil fuels. It is not a short-term fix, but long-term it could keep Aramco among the top tier of oil and gas producers for many more decades to come, keeping the lights on in homes across the country, without draining precious hydrocarbon reserves. It is good news for the market too, potentially freeing up additional oil and gas for export. In fact, in the future Saudi Arabia could – at least, theoretically – be one of the world’s lowest cost mass producers of solar electricity, although this remains some way off.

No shirking Despite all of these many challenges, Saudi Aramco does not plan on shirking its responsibilities as the world’s leading oil producer. The company continues to diversify and increase its global footprint, and ramp up its domestic business, just as it has done for many years previously. And the intention is to do it in hand-inhand with other international oil companies. “Even as other companies are retrenching, we will be investing to build a vertically and horizontally integrated, top-tier refining, marketing, petrochemicals, lubes and power business,” al-Falih said recently, “with much of that expansion coming in the form of joint ventures with other leading global firms at home and abroad.” It has been a busy year for the Aramco team already, and 2015 will be no different. The company has been in the oil game for a long time and, as in most other walks of life, experience counts for a lot. n

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 Saudi Aramco

Saudi Aramco grows its presence in chemicals SAUDI ARAMCO IS rapidly leveraging its feedstock cost advantages and a favourable geographic portfolio to become a growing global competitor in chemical production, according to new research from IHS (NYSE: IHS), the leading global source of critical information and insight. Similar to the chemicals businesses of other oil and gas majors, Saudi Aramco’s product focus is comparatively narrow. The company produces commodity chemicals and polymers, including olefins, derivatives and aromatics. At present, Saudi Aramco’s chemical business accounts for around 10 per cent of the corporation’s revenues and earnings. “Saudi Aramco’s entry into the petrochemical space is quite recent, so its rapid growth in the space is quite remarkable,” said Sanjay Sharma, vicepresident, Middle East and India at IHS Chemical. “Saudi Aramco is pursuing a business strategy that identifies advantaged feedstock and optimises the linkages between refinery, gas processing operations and petrochemicals. This trend of integrating refineries and petrochemicals is common in other regions, but is more recent in the Middle East, which is leading to more aromatics and derivatives production.” Saudi Aramco is participating in domestic and international joint ventures (JV), and the company has driven continuous improvements in its domestic and international projects, mainly in China, South Korea, Japan and the USA, according to the new report, IHS Chemical Company Analysis: Saudi Aramco. “The integration of Saudi Aramco’s oil and gas production into its refinery and gas processing operations, along with the manufacturing site synergies achieved in the company’s large petrochemical complexes, provide strong competitive advantages for the company,” Sharma said. “This approach is exemplified by the company’s world-scale Sadara petrochemicals project, a US$20bn JV between Dow Chemical and Saudi Aramco.”

Sadara, according to the IHS report, is scheduled to be onstream in 2016 and will take advantage of the company’s access to low-cost, gas-based feedstocks and liquid feedstocks. Sharma said, “Sadara’s Jubail complex will produce an array of higher-value performance products – some of which have never been produced in the region, which is significant for the market.” The company’s Petro Rabigh integrated petrochemicals complex, a JV with Sumitomo of Japan, that produces olefins and derivatives is undergoing expansion, with the addition of Rabigh II, which is expected to start production in 2016 to 2017. The main products will include ethylene propylene rubber (EPR), thermoplastic polyolefin (TPO), methyl methacrylate (MMA) monomer and polymethyl methacrylate (PMMA), as well as low-density polyethylene/ethylene vinyl acetate (LDPE/EVA), para-xylene/benzene, cumene and phenol/acetone. “Sadara and Rabigh II will be the leading projects that will continue to secure a strong foothold for Saudi Aramco in the petrochemicals market,” Sharma said. “They will enable the company to realise its vision of becoming a leading player in chemicals production.” According to the IHS report, Saudi Aramco has a number of other JVs, both in the region, and elsewhere, including in South Korea, China, Japan, and in the USA, where it holds a 50 per cent share in Motiva Enterprises LLC. Saudi Aramco’s strategic projects, noted the report, located mainly in the Middle East and Northeast Asia, cover the most demand-thirsty markets in the world. Saudi Aramco (Aramco Asia) is also exploring the possibility of starting a refinery in Tuban, East Java, Indonesia. The company signed a memorandum of understanding in 2012 with PT Pertamina (Persero). If started, this refinery will produce petroleum and petrochemical products that will enable the company to cover broader Asian markets. “Cost reduction and reliability will, however, remain critical elements of any company’s strategic direction,”Sharma said. “Saudi Aramco is in a growth mode, aiming to claim a greater global market share for many commodity chemicals and plastics, as well as make new forays into higher-value performance chemical markets. As they significantly broaden their portfolio with these higher value performance chemicals, we expect they will become a force to be reckoned with during this decade.” For more information on the IHS Chemical Company Analysis: Saudi Aramco report, please contact becky.donham@ihs.com.

Facts and figures: Saudi Aramco in 2013 • Saudi Aramco sourced 75 per cent of material procurement (US$6,232 mn) and 92 per cent of service procurement (US$30,432 mn) from local companies in 2013 • 25 per cent of Saudi Aramco’s workforce was born after 1980 – by 2020 ‘Generation Y’ will be the largest demographic in the company • 6,546 employees received leadership training • Saudi Aramco’s total workforce in 2013 was 57,283, of which 48,385 were Saudi and 8,898 expatriates • Saudi direct hires were 1,428 in 2013, 65 per cent up on 2012 • Saudi Aramco sponsored more than 2,000 undergraduate and postgraduate students • Saudi Aramco employees completed 5.2mn hours of training • 216 women completed the women in business programme • 395 students graduated from the Saudi Aramco Professional Development Academy • 57 patents were granted by the US Patent and Trademark Office Saudi Arabia’s Exploration and Petroleum Engineering Advanced Research Center (EXPEC ARC) made progress in developing technologies including a SmartWater Flood Field Pilot; reservoir nanoagents; the ‘Prosperity’ application for predicting reservoir quality; microwave energy to mobilise heavy oil; drilling microchip sensor technology; and a high-temperature resistant downhole video camera.

Source: Saudi Aramco Annual Review

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 Saudi Aramco

SPTC receives Saudi Aramco manufacturing approval SAUDI POWER TRANSFORMERS Co (SPTC) has received Saudi Aramco approval to manufacture power transformers and has been added to the list of approved suppliers. SPTC manufactures power transformers up to 100MVA and 145Kv class, meeting IEC, BS, and ANSI-IEEE specifications. SPTC also has a repair shop to repair and refurbish old transformers, field services teams and a shop to assemble mobile substations. SPTC’s factory in Dammam, Saudi Arabia, is the largest power transformer factory in the region and its test lab is the most advanced. SPTC started production in late 2012 and has manufactured and repaired many power transformers for utilities SPTC has received Saudi Aramco approval to manufacture and industries in Saudi Arabia such as power transformers Saudi Electricity Company, Marafiq and National Grid SA. SPTC is a 50 per cent JV between CG power Belgium (Pauwels) and Electrical Industries Co. (WESCOSA & Saudi Transformers Co.). The factory is ISO 9001 certified by TUV Germany and under a know-how license from CG power Belgium, with design and production quality monitored by CG staff. SPTC contributes actively to offer career opportunities at all levels to Saudi nationals, with provisions for training locally and in Belgium.

•

• •

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Saudi Arabia rig count SAUDI ARABIA’S TOTAL rig count continues to rise in 2014, reflecting the high level of exploration and development activity. According to industry sources, the total rig count could reach 200 by the end of 2014. Saudi Arabia Land Rig Count, 2014 55

50 45

Gas

35 30

Jan

Feb

Mar

Oil

34 31

25 20 Apr

May

Jun

Jul

Aug

Source: Baker Hughes

Saudi Arabia Oﬀshore Rig Count, 2014

20 20

Gas Oil

10 6 5

5 1

0 Jan

Feb

Mar

Apr

May

Jun

Jul

Aug

Source: Baker Hughes

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Saudi Aramco 

Saudi Aramco boosts R&D activity SAUDI ARAMCO RECENTLY opened a new research centre in Houston, the latest in a global network of new research and development centres, marking the energy giant’s increased commitment to R&D. Speaking at the inauguration of the centre, Khaled Al-Falih, president and CEO of Saudi Aramco, said that the centre would address the range of upstream opportunities and challenges, including production and drilling technologies, reservoir engineering, geology, geophysics technologies and advances relating to subsurface sensing and control. “We believe the way to research success lies in co-operating and collaborating with other leading institutions, whose strengths are complementary to our own,” said Al-Falih. “That is why we have adopted an open model of innovation, integrating capabilities and ideas from around the world through strategic research alliances, investing venture capital in startup companies pursuing cutting-edge energy technologies and, of course, through our network of global satellite research centres.”

The new research centre in Houston, USA In another development, Saudi Aramco Energy Ventures (SAEV), the venture investment subsidiary of Saudi Aramco, has made a major investment in Siluria Technologies, a pioneer in the commercial production of fuels and chemicals made from natural gas. Siluria has developed a catalytic process for transforming natural gas into transportation fuels and commodity chemicals in an efficient, cost-effective, scalable manner using processes that can be integrated into existing industry infrastructure. It has created a growing portfolio of process configurations with applications in upstream, midstream gas processing, downstream chemicals production and refining operations. The investment could lead to Saudi Aramco using Siluria’s natural gas to chemicals process and fits with its drive to diversify its portfolio and grow its downstream activities. SAEV’s mission is to invest globally in start-ups and high growth companies with technologies of strategic importance to Saudi Aramco.

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 Saudi Aramco

Raccortubi Middle East celebrates success after first year in business RACCORTUBI MIDDLE EAST FZE, the stockist and distributor of pipes, tubes, fittings and flanges, continues to do good business following its establishment last year in response to regional customer demand for piping materials. Supplying industrial facilities, such as chemical and petrochemical plants, oil installations, power plants, shipyards, and offshore platforms, the Raccortubi Group subsidiary provi des customers with piping materials in stainless steel (304/304L, 316/316L, 321/321H, 304/304H, 347/347H), duplex and superduplex (UNS S31803/S32205, UNS S32760 and UNS S32750), superaustenitics (6Mo, 904L), and nickel alloys. Raccortubi Middle East said that as a result of the Raccortubi Group’s organisational structure, which incorporates both stockholding and manufacturing activities, it is able to take advantage of the integration between Group companies for continuous stock replenishment. Raccortubi Middle East launched in 2013

Mr Swami, Raccortubi Middle East managing director, said, “Thanks to our integrated manufacturer we are able to provide exstock materials in accordance with specifications which already adhere to the most stringent market demands.” The Group’s Tecninox plant continuously replenishes Raccortubi stocks with fittings in stainless steel, duplex, superduplex, superaustenitics, and nickel alloys. Tecninox has recently added to its list of end-user approvals, with its butt weld fittings being technically approved by the global energy corporation Petrobras. This news follows the launch of Raccortubi’s new subsidiary in South America, Raccortubi do Brasil Ltda, which is a further example of how the business is optimising its synergies to maximise the services provided at each of its latest distribution points in Brazil, Dubai, and Singapore. A Raccortubi representative said that due to the stock availability and integrated manufacturing plant, the company is able to respond immediately to material requests, while the manufacturing activities provide support in both the flow of stock replenishment and flexibility of supply, an attractive prospect to end users. Furthermore, according to Raccortubi, in-house specifications have been engineered to cover the vast majority of end-user requirements, and its certified products do not need additional testing, as this has already been carried out as part of the standard production process. Raccortubi Group companies benefit from ISO, PED and NORSOK certifications, as well as featuring on a large number of vendor lists, including those of SABIC, Sadara, BP, ADNOC, ZADCO, GASCO, TAKREER, KOC, Litwin, Maersk Oil Qatar and EIL. Swami concluded, “We continue to strive for top-quality products and satisfied customers.”

Geyad looks to play enhanced role in GCC project market GEYAD FOR INDUSTRY and Contracting (formerly Geyad for Commerce and Import), a leading Saudi Arabian Saudi Arabian fabricator of structural steel, pressure vessels, storage tanks and pipe spools, is expanding capacity, having commissioned a new production unit in Dammam. The new facilities will enable it to increase steel production and to manufacture higher thickness pressure vessels. Geyad’s general manage r Naif Ababtain said that the company’s commitment to customer satisfaction was the secret of its

Geyad has been expanding its capacity

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business success as it is able to retain its customer base even in difficult times. Established in 1980, Geyad is registered with SGS for ISO 9001:2008 and is accredited with ASME “U” stamp related to pressure vessel fabrication and “R” and “NB” stamps from the National Board of Boiler and Pressure Vessel Inspectors (NBBI), according to the company. It has supplied shop-fabricated structural steel to Saudi Aramco and SABIC on many of their large projects. The company has also been a supplier to a water cooling project in Ras Laffan Qatar, as well as to National Chevron Phillips, Satorp and Sadara. Geyad provides a comprehensive design and detailing facility for steel structures, tanks and pressure vessels, utilising stateof-the-art design software. Geyad operates on strict Quality Assurance and Quality Control (QA/QC) procedures for its manufacturing processes. Internal and external quality audits are carried out by certified auditors. Welding inspection is carried out by AWS qualified inspectors. The company has an in-house NDT testing facility, carried out by certified Level II inspectors. Geyad’s product portfolio falls into five principal categories: structural steel;

Geyad general manager Naif Ababtain

pressure vessels; storage tanks; pipe spools; and miscellaneous structures. Manufacturing capabilities include plate rolling up to 50mm thick and 3m wide and CNC-controlled cutting, drilling and coping. Geyad is in the process of revamping its safety system and getting it accredited to OHSAS 18001: 2007. The company is an approved vendor with S audi Aramco, SEC, SABIC and MARAFIQ as well as with the Saudi Arabian Ministry of Defense and Aviation.

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 Saudi Arabia

SABIC signs MOU to boost

R&D efficiency S ABIC SIGNED A Memorandum of Understanding (MoU) with hte in Heidelberg, Germany on 5 September 2014 to establish a satellite laboratory for high throughput experimentation to increase its R&D efficiency. hte is a leading high throughput experimentation company that provides a valuable upside to heterogeneous catalysis and enables fast track R&D. The MoU was signed by Dr. Ernesto Occhiello, EVP – technology and innovation, and Dr. Wolfram Stichert, CEO at hte GmbH. Under the MoU, hte will provide a technology platform to support SABIC in catalysis R&D. This will include advanced

testing equipment which will be hosted exclusively at hte’s newly constructed laboratory building in Heidelberg, Germany. SABIC will benefit from a unique R&D environment with dedicated high throughput experimentation laboratories and specialised personnel. hte’s offering additionally encompasses state-of-the-art workshops, infrastructure, technology, service, and cata Commenting on the MoU, Dr. Ernesto Occhiello said the memorandum is in line with SABIC’s 2025 strategy for the growth of petrochemicals and meeting the future challenges of R&D. “We are happy to continue our collaboration with hte who we consider a forefront provider of modern R&D

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solutions and technology. An innovative partner like hte will indeed add value to our business in the long term, and this will enhance our innovation pace significantly.” n

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Saudi Arabia 

SABIC to host STM-11 in November THE 11TH ROUND of the SABIC Technical Meeting & Exhibition (STM-11), will be held from 3-5 November 2014 at the Multi Event Center in Jubail Industrial City, Saudi Arabia, under the patronage of Saudi Basic Industries Corporation (SABIC). Organised by Al-Harithy Group - ACE Creative, STM is a specialised meeting where SABIC officials and researchers gather every other year to exchange technical knowledge and to become acquainted with state-of-the-art technologies (www.stm-11.com). This year’s exhibition is touted to be the largest exhibition in the Kingdom and one of the largest in the Middle East, with the theme ‘Commitment to Reliability & Sustainability’. SABIC has invited companies from all over the world to present their latest products, services and technologies to SABIC decision makers and top professionals. The wide-ranging technical programme includes keynote speeches, workshops and

paper sessions by experts from Saudi Arabia and elsewhere. The exhibition, which will be held as part of STM-11, has been drawing a growing number of participants over the years, the organisers said. The last event attracted 310 exhibitors from 23 countries. STM has been attracting leading corporations such as GE, ABB, Siemens, Emerson, Schneider, Shell, Yokogawa, Emerson, Johnson Matthey, Honeywell, Hisaka, Endress & Hauser, 3M, BASF Corporation, HOERBIGER, GEA Group, V Line Group and many others who have participated in the last three events. The sectors for STM-11 include petroleum, mineral resources, chemicals, industry and electricity, infrastructure and development, environment, agriculture and water, communications and electronics, education and training, health and safety, operations and maintenance, and transportation and shipping. The growth in the number speakers,

STM-10 had 310 exhibitors and 30,000 visitors (Photo: ACE Creative)

visitors and exhibitors has led to a demand for an increase in exhibition space from 12,000 sqm to 20,000 sqm. SABIC is the world’s second largest diversified chemicals company, and is the largest and most profitable non-oil company in the Middle East. A public company based in Riyadh, it operates in 40 countries.

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 Saudi Arabia

Saudi shale boom shifts

energy narrative While the US leads the way in shale gas development, Kenan Nouwailati, managing director of Accenture Management Consulting, discusses Saudi Arabia and its unconventional plans. N MARCH 2013, Saudi Arabia’s oil minister Ali Al Naimi announced plans to drill seven test wells to extract shale gas as part of a programme to develop the Kingdom’s unconventional oil and gas reserves. While the US unconventional oil and gas boom has made ‘shale’ a buzzword among energy and business analysts, the move to develop this resource in a country renowned for its conventional oil and gas reserves can seem like a curious contrast. The development, however, of a national shale gas network can be seen as a strategic move for the Saudi government to drive its economic growth and secure future revenue and employment streams. While shale gas has gained public prominence, due to the development of reserves in the US, few understand what the development of this resource actually entails. Essentially pockets of natural gas trapped in dense, impermeable sedimentary rock, shale gas production is a complex business involving seismological study, complex extraction systems and multifaceted distribution infrastructures. Similar to nuclear and renewable energy, the development of shale gas depends not only on the availability of resources, but on supportive fiscal measures and skilled talent. There is good news for Saudi Arabia in this respect. The oil minister has forecast approximately 17 trillion cu/m of shale reserves in the Kingdom, which equates to more than 100mmbbl of oil. Saudi Arabia’s shale reserves exceed that of Mexico (averagely 15.4 trillion cu/m), Australia (12.4 trillion cu/m) and Russia (8 trillion cu/m). Saudi Arabia has identified substantial shale gas formations in the northwest of the country, the South Ghawar basin – the world’s largest conventional oil field – and the Rub’al-Khali. A recent report by Accenture, International Development of Unconventional Resources: If, Where and How Fast, states that the development of the unconventional energy infrastructure in Saudi Arabia will

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enable it to meet its domestic gas needs and increase oil exports. While it is blessed with vast oil and gas reser ves, Saudi Arabia is also experiencing a surge in domestic electricity demand. With an estimated population of 27mn currently using up to 53GW of electricity in the peak season, according to Saudi Arabia’s Electricity and Cogeneration Regulatory Authority, coupled with an ambitious pipeline of multi-billion dollar infrastructural projects, the country’s electricity consumption will surely rise. In order to meet the electricity demand, Saudi Arabia has burned oil and gas that could be exported, leading to a loss in export revenues. Similarly, this fuel is provided to local utilities at a subsidised rate, further exacerbating the problem of lost income. In fact, the International Energy Agency (IEA) predicts that the Kingdom could turn into an energy importer within the next 20 years if the rate of electricity consumption continues. Developing unconventional resources like shale gas could provide a way to address increasing domestic electricity demand. It provides resources to produce electricity while freeing up existing oil reserves for export, thus earning valuable revenues. It also means that the ‘business case’ for the country for shale gas is attractive. Although the local gas sale price is heavily subsidised (at US$0.75 per million BTUs – about 20 per cent of process in the US), using this gas to substitute oil produces an attractive return based on the international sale price of the produced oil available for export rather than on the gas price. Also, a ’multiplier’ effect means that, as well as releasing oil for export, this gas produces electricity which supports the country’s economic growth, allowing it to continue to diversify from a crude oil exporter to an exporter of refined products and other goods and services. Harnessing national shale gas reserves

Accenture Management Consulting managing director Kenan Nouwailati will not happen overnight given the development required and technical challenges. The country does, however, have a strong oil and gas services sector and conventional skilled workforce, and local companies have made progress in recruiting foreigners with unconventional skills to support development. The progress was illustrated by Saudi Aramco CEO Khalid al-Falih who recently stated that the company plans to produce 5.7mn cu/m per day of unconventional gas by 2018, to power a 1,000MW plant to feed a new phosphate mining and manufacturing facility by Maaden in northern Saudi Arabia. Meanwhile, there is also progress on the domestic utilities front. The government plans to decrease its dependence on conventional fuel to produce electricity by diversifying its energy mix. By 2032, it will have 41GW of solar energy and 17GW of nuclear energy to meet its domestic electricity demand. What Saudi Arabia has, which is unique, are the reserves, government support, and vision to develop this sector as an engine for continued country development. The next two decades will be filled with much activity, change and dynamism proving that the Kingdom has what it takes to remain a global powerhouse in the world energy business. n

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SAOGE 2014 ď&#x192;§

Saudi Arabia set to host SAOGE 2014 THE SIXTH SAUDI Arabia International Oil and Gas Exhibition (SAOGE) will be held in Dammam from November 24-26, with more key industry players, technical experts, professionals and decision makers than ever before set to descend on Dhahran for the event. More than 150 companies will welcome more than 8,000 visitors, as industry players from more than 18 countries meet with their peers at the 2014 edition of SAOGE. SAOGE, the biggest oil & gas exhibition in the Kingdom, has experienced high demand from exhibitors

Last year SAOGE welcomed 7,975 visitors to the Kingdom of Saudi Arabia this year, with confirmed companies including Qatar Petroleum, China Petroleum Technology & Development Company, Al Estagamah Global Group, Abdullah H. Al-Shuwayer Sons Trading and Contracting Company, Alaa for Industry, Alfanar, Alsuwaiket Oil and Gas Services, Middle East Specialized Cables Co. (MESC), Sawary Energy and Saudi Steel Pipe Company among the exhibitors involved in the upcoming sixth edition of the exhibition. Companies from both regional and international markets understand the huge potential that the Saudi Arabian oil and gas sector offers, and will look to use SAOGE to roll out their products and services to this lucrative sector. Event attendees confirmed so far will comprise of 34 per cent foreign exhibitors from China, France, Germany, India, Indonesia, Italy, Russia, Switzerland, Singapore, Taiwan, Turkey, United Kingdom and the USA.

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 Valves Lester Millard, managing director at Alcatraz Interlocks B.V., looks at the effectiveness of key interlocks as a locking device.

Reducing the risk

of operator error W

HILE THE OPERATION of process equipment is governed by international health and safety protocols, the possibility of human error cannot be ruled out. Mechanical key interlock systems can help operating companies to reduce this risk by preventing process control equipment from being incorrectly operated.

What are mechanical controls and interlock systems? Mechanical key interlock systems are twin-keyed mechanical locking devices which operate on a 'key transfer' principle to control the sequence in which process equipment may be operated. This system is widely accepted as an effective safety management tool and is being adopted by many of the world’s oil, gas and chemicals majors. Valve mechanical interlocks are also recommended in a number of internationally recognised standards for specific process ap plications. Key interlocks date back to 1856, when they were first used in the

British railway interlocking control for track switching. Trapped key interlocks are applied to valves, gears, pig launcher closure doors, switches, machine gates, railways or any form of equipment which may be operated manually. The 'open’ or 'closed' position of a locked valve of an interlock can only be changed by inserting a unique coded key, which unlocks the operating mechanism enabling the operation of the valve Alcatraz type DML valve interlock or other device. mounted on a 2”globe valve Operating the unlocked incorporating keys, 1 and 2 equipment immediately traps the initial (ie, inserted) key; when the operation is complete, a secondary (previously trapped) key may then be released, thereby locking the equipment in the new position. This secondary key will be coded in common with the next lock (item of equ ipment) in the sequence. By this simple coded key transfer principle a ‘mechanical logic' system is created which prevents operator error.

Key interlocks date back to 1856, when they were first used in the British railway interlocking control for track switching” Standards such as UK Pipeline Safety Regulations recommend interlocks as a suitable safety system in the operation of pig traps. Whether a process system is of a simple design, controlled manually, or a complex controlled system like DCS, key interlocks can provide a reliable mechanical assurance of safe operating practice in which the operator's scope for error will be eliminated.

A customised solution Alcatraz Interlocks provides a full mechanical solution with mechanical key interlocking on all types of valves, gears and switches. Whether a primary or secondary safety system, key interlocks can be customised to fit valves, switches or devices. Meeting the relevant API, British and European standards relating to specific process applications, Alcatraz interlocks are recognised as an effective safety management tool and safeguard the most complex operating sequences. They are used in the oil, chemical and gas industries and offshore industry. Applications include numerous critical installations, such as changeover of pressure relief valves, loading and unloading of pig traps, sampling devices, industrial mixers and separators, filters and granulators. Alcatraz interlocks also safeguard the coupling and uncoupling of loading arms and hoses on discharge and loading stations. For example, a simple, low-cost system eliminates the risk of human error or negligence in the tanker loading procedure by preventing a vessel leaving the transfer area still connected to t he onshore facilities via a loading arm. n 68

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 Technology

EOR offers huge potential for

increasing supply Only around a third of oil in conventional reservoirs is typically recovered through primary and secondary recovery processes. This can be significantly increased if the right combination of technologies is employed. N THIS YEAR’S ‘World Energy Outlook’ the International Energy Agency (IEA) says that Enhanced Oil Recovery (EOR) is currently little used, but has enormous potential for increasing the world’s available supply. Developments – both on- and offshore – could make a huge difference to the supply side in the Gulf. “EOR can be defined as the set of technologies that permits production of a greater share of the oil that remains after primary and secondary recovery,” says the IEA1. It lists the associated technologies as: 6 Use of steam to reduce viscosity 6 Miscible gas injection (including use of CO2 and water-alternating gas)

There is considerable scope for increased deployment of EOR technologies (Photo: Shell)

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6 Chemical flooding with polymers and/or

6 Tailored water injection (usually consid-

surfactants 6 Microbial EOR 6 Combustion flooding

6 Use of vibration processes.

Around 280 schemes are thought to be in operation at present, producing an additional 1.3mn bpd of oil”

ered as an unconventional technique)

In a document on Enhanced Oil Recovery2 Shell Global Solutions International states, “Studies indicate that just a one per cent increase in the global efficiency of hydrocarbon recovery would raise conventional oil reserves by up to 88bn barrels (bbo), which is equivalent to three years of annual production at today’s level.”

Varying projections Projections vary widely, but the IEA points out that most information concerning the potential

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 Technology

of EOR actually relates to the USA, where it is estimated that more than 50 bbo are currently recoverable by one or more of the processes listed above (CO2 injection principally so far). Without EOR, recovery rates average just 35 per cent. “Using a conservative estimate of 10 per cent for the additional average recovery possible by systematic application of EOR technologies gives 100 bbo of potential additional oil,” says Shell. Globally, including in MENA, the picture is much more uncertain. The IEA’s own predictions suggest that 430 bbo are recoverable, using an average improvement in recovery rate of just 10 per cent and on the same basis of output calculation. Using a different model, the Agency says “This yields an EOR potential of some 1,000 bbo, four times the reserves of Saudi Arabia”; of these at least 300 bbo look most likely to be achieved. These are huge numbers, whichever view is taken. The global energy watchdog stresses that most of the technologies classified as EOR only developed in the special conditions of the 1980s, with plenty of room for improvement (but also a puzzling lack of application so far, especially outside the USA). Around 280 schemes are thought to be in operation at present, it states, producing an additional 1.3mn bpd of oil.

One of the determining factors will be developments in OPEC Middle East countries” So far, steam-assisted gravity drainage has been frequently chosen locally; this process’s share of output is falling, but the large Wafra project planned for the neutral zone between Kuwait and the KSA could reverse this trend. Use of chemical EOR employing watersoluble polymers and/or surfactants, including alkaline surfactant polymers, remains minimal, but Shell is planning a local ASP pilot project in association with PDO. “Interest in CO2 EOR is growing globally, although no full-scale project has materialised yet outside North America,” the IEA report says. “Of particular significance is the interest in using such technology shown by Saudi Arabia and the UAE, as a 10 per cent increase in recovery rates in fields in these two countries would represent a large amount of oil.”

Huge potential The potential for EOR is very large indeed, with Shell estimating that EOR currently accounts for four per cent of global oil production. “Available information on costs,

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Shell is playing a leading role in the development of EOR technologies (Photo: Shell) benefits and drawbacks suggests that deployment is profitable at current oil prices,” says the IEA. “So why is the industry preferring to invest in light tight oil (LTO) rather than EOR? The answer lies in the risks, returns and staffing intensity.” EOR is usually associated with moderate capital expenditure, but much higher operating costs (materials and the injection process itself). The time taken to see positive returns – years in some cases – is another key factor. So, compared with LTO, EOR is more attractive for investors looking for longer-term returns, such as national oil companies. The IEA report suggests CO2 EOR could be particularly attractive. However, key constraints are availability of skilled staff and the time taken for projects to be evaluated and then yield an acceptable return. In conclusion, the IEA’s report maintains that “One of the determining factors will be developments in OPEC Middle East countries, where interest in maximising recovery is growing; a pilot project for steam-based EOR, using solar energy to generate the steam, has been built in Oman, and similar projects are planned in the UAE.”

Leading role Prominent in the development and application of the technologies outlined above are the oil and gas service companies, which now play a vital role both in assisting NOCs and enabling new small-scale operators to successfully take over control of supposedly “exhausted” wells. Also playing a leading role are the IOCs, like Shell, whose EOR document provides an excellent summary of the current state of play, and emphasises the central role that its

partner PDO takes in investigating various technologies in Oman. “Advances in oilfield technology are leading to step changes in oil recovery,” its brochure says. R&D tasks undertaken under an EOR Strategic Alliance with PDO at Shell Technology Oman include solar-generated steam injection in the Qarn Alam and Amal fields, polymer injection at Marmul and miscible gas injection at the Harweel cluster. At Marmul, for example, a field which came on stream more than a quarter of a century ago, only 15 per cent of the very viscous oil has been recovered. A waterflooding scheme was installed, but this was insufficient. So the operator switched to polymer flooding: treating the water to remove impurities; mixing it with an advanced polyacrylamide compound; and injecting this into the well under very high pressure. The aim is to increase the recovery factor to more than 25 per cent – that would be an extra 8,000 bpd. “Following this success,” the company says, “PDO intends to expand operations at Marmul, creating one of the largest polymer flooding facilities in the world.” Shell emphasises that the optimum recovery technique always requires “deep understanding of reservoir behaviour and oilfield economics”. It also stresses the need for integration of techniques at all levels, from as early on in the well development process as possible. ■ www.worldenergyoutlook.org http://s05.static-shell.com/content/dam/ shell/static/future-energy/downloads/eor/ eor-brochure-2012.pdf 1 2

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 Compressors A look at how oil and gas companies can cut the operational costs of compressors by utilising common sense solutions

Cutting the operational

costs of compressors M ORE THAN 80 per cent of the day-to-day cost of operating a modern compressor – whether reciprocating or rotary-screw type, electric motor or diesel driven, conventional or oil-free, and single- or multi-stage – can go into paying for the fuel or power used. Huge operating-cost savings can be made if a reasonable attempt is made to recover most of that energy, with some manufacturers claiming that more than 90 per cent is possible. In general, the larger the system in use, the more sense it makes to recover all that wasted heat. The savings are particularly apparent with electric motor-driven rotary screw compressors, the sort that are widely used by local industries, as well as within the onshore and offshore oil and gas sectors. The principal means of achieving real savings like these in North Africa and the Gulf is by retrieving the waste heat produced and using this in some kind of industrial or fluid-heating process. Where this is not feasible, however, major savings can be made if a compressor is chosen in which the casing employed optimises the pattern of air flow by some form of ducting and overall thermal management, allowing cooler intake air to be used and avoiding the discharge of excessive heat to the atmosphere. This requires a really effective cooling system to be incorporated, usually one which uses water as the cooling- and heat-transfer medium. An exceptionally efficient motor and direct drive mechanism can help achieve cost and energy savings too; so can an efficient integrated dryer installed at the output end. A top-grade automatic monitoring and control system adds efficiency, especially if incorporated within a master management system for the sort of multi-compressor set-up often found in an electrically-powered industrial system. The problem of heat recovery is usually more complex and less cost effective in the case of premium compressors that deliver virtually oil-free air for special applications such as food, pharmaceuticals and other high-end industrial processing. This is

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An efficient motor and direct drive mechanism could help oil and gas operators using compressor technology to achieve cost and energy savings (Photo: Doosan) because they usually operate at substantially higher internal temperatures which produce much hotter air at the outlet end. Raising the temperature of process water is the most obvious application for heat recovered in hot and arid territories, while space heating is widely used in seasonally colder countries. n The next issue of Oil Review Middle East will feature a comprehensive report from the first in our Round Table series, where we will bring together representatives from leading compressor manufacturers to discuss the logistic chain, operational and safety issues relating to developments within the Middle East’s oil and gas sector for the compressors industry.

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 Technology

Sonardyne receives Queen’s Award for 6G product SONARDYNE HAS BEEN selected to receive the Queen’s Award for enterprise by the Lord-Lieutenant of Hampshire in the UK. Dame Mary Fagan presented the award in the innovation category for Sonardyne’s Sixth Generation (6G) product platform at the company’s head office and manufacturing facilities in Yateley, UK. The Lord-Lieutenant was offered a tour The Lord-Lieutenant of Hampshire presents Sonardyne of Sonardyne’s campus, which is set with The Queen’s Award across three buildings on Blackbushe Business Park, including the company’s engineering, production and machine shop facilities. Based in the UK, with regional offices in Aberdeen, Brazil, Houston, Plymouth and Singapore, Sonardyne specialises in the design and manufacture of underwater acoustic positioning, inertial navigation, wireless communications and sonar imaging technology. “We are honoured to welcome the Lord-Lieutenant of Hampshire, Dame Mary Fagan, to our Hampshire headquarters for the presentation of The Queen’s Award,” stated John Ramsden, Sonardyne managing director. “This is the third occasion in 20 years she has visited us to present us with a Queen’s Award and we’re proud to show her how the company has progressed and grown from the small rented premises we occupied in 1994 to the prestigious multi-building manufacturing and production facility it is today,” added Ramsden. The Queen’s Award is granted by HM Queen Elizabeth II, on advice of the UK Prime Minister, and is the highest award a UK business can receive.

ComputIT awarded R&D contract to develop fire-simulation technology COMPUTIT HAS BEEN awarded a US$3.1mn R&D contract from authorities in Norway, through the Research Council of Norway, Statoil, Total, ENI, ConocoPhillips and Gassco, to develop an advanced fire-simulation technology for the oil and gas industry. Based on industrial fire-simulation tool KAMELEON FIREEX KFX, the new technology will aim to contribute to an enhanced understanding of fires, fire safety and the prevention of major accidents within the industry. KFX is the result of R&D activities on turbulence and turbulent reacting flows carried out since 1969. The fire-simulation and analysis tools today covers the simulation of conventional jet and pool fires, complex multiphase spray fires with rainout, and well-ventilated and under-ventilated fires in congested geometries. It also covers LNG leaks with pool spreading, gas dispersion and LNG fires, water-based fire migration by deluge, monitors, mist and water curtains in complex systems, optimisation of passive fire-protection, flare analysis and general gas dispersion and smoke analysis.

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Belden highlights oil and gas cyber threats THIS YEAR, THE Belden Industrial Ethernet Infrastructure Design Seminar was held in Houston featuring a number of seminars focusing on applications for the oil and gas sector. Among the sessions that took place during the event, Scott Howard looked at the primary goals of cyber security measures in industrial networks: to enhance safety, to reduce downtime and to improve productivity. The goals of cyber security are the same as the core goals of most manufacturing teams, Belden noted. Over the past few years, there have been many high-profile, advanced malware threats that have proved to be a threat to the energy sector, such as Stuxnet, Flame, Shamoon. While these are important threats that need to be considered in oil and gas industry risk assessments, they account for a low number of overall threat sources. Industrial networks can be affected by internal incidents because many PCs on the network run 24 hours per day, seven days a week, and do not have antivirus protection. As well as this, there are many ways for malware to affect control networks, such as USB keys, maintenance systems and the laptops of visitors. Controllers designed for real-time I/O, and not robust network communications, may not react well to malformed messages or high levels of traffic. The best way to deal with this issue is by using Defense in Depth, which is essentially where there are many layers and types of security in place. The guidelines which will enable this are the ISA/IEC 62443, previously ISA99, standards which recommend outlining “zones” within networks and enabling the zones to communicate only through secure “conduits”. Using this process will mean, only the minimum necessary network traffic passes between zones and unusual traffic will set off alarms and is blocked. Belden’s product line supports security at many levels of communication, including at the physical level with high-reliability cables and at the data level with switches that have security features enabled.

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 Technology

Eztek provides customisable range of electronic instrumentation to STATS EZTEK, KNOWN FOR its TallyBook data loggers and TalkBack intercom systems, recently provided pipeline engineering specialists STATS Group with a radio data link system. The project, which required a quick turnaround time, has led STATS to work with

Eztek’s products are often used by oil and gas companies whose projects are located in hazardous conditions

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Eztek again in developing and manufacturing a noise survey unit. Eztek has now won a contract with STATS to build additional noise survey units, as well as subsea communication systems. STATS uses noise survey equipment as part of its quality assurance process, in order to

reduce the likelihood of encountering technical difficulties at remote locations, and in this case required a lighter and smaller unit. In order to improve efficiency of operations Eztek was provided with a design specification, with a view to creating more variations in the future. STATS electronics engineer Matthew Grant explained, “Eztek worked with us to rapidly ‘fleshout’ a working design into a finished product. “We have been happy with the build quality and professional finish to the items, and also with the level of communication, planning and flexibility. They have been a reliable and valuable partner in realising designs to meet the technical requirements of a challenging and expanding market.” Eztek general manager Robin Hunter commented, “Our clients know that we'll listen to what they need and that we offer flexibility and a wealth of expertise. Sometimes this means configuring a TallyBook to suit different types of sensors and sometimes it means developing a completely new innovative design.” Eztek’s products are used by oil and gas companies whose projects are diverse, where time requirements are often tight and conditions are hazardous.

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 Technology

Hacking into the region’s

cyber security threat As the Middle East oil and gas industry continues to incorporate digital solutions and smart devices in order to maximise on productivity, how far does this also feed the risk of cyber attacks? HE MIDDLE EAST energy industry is increasingly adopting digital and remote technologies in the running of its facilities, both in upstream and downstream, which intends to ensure both boosted production and maximum business. By and large, companies in the region continue to utilise new and advanced technology to its full effect. As Cisco UAE general manager Rabih Dabboussi told Oil Review, benefitting from these technical advancements allows businesses to connect global operations, drive efficiency, automate dangerous tasks and manage complex supply chains. The benefits, unfortunately, do not come without risks. In fact, in June 2014 Cisco announced that the global energy sector featured in the top five industries most at risk from malware. According to the 2014 Cisco Annual Security Report, the energy sector faces a malware encounter rate of more than 400 per cent, which is 300 per cent higher at risk than the median industry. Dabboussi said, “The Middle East’s energy sector is rapidly adopting smart devices and cloud computing to enhance business, but this is also creating a larger landscape for cyber security threats. Malware can cripple an energy company’s IT infrastructure and halt business operations, and potentially disrupt the world’s energy supplies.” As a region that boasts a high density of oilfields, increasing upstream and downstream activity and, as such, is rapidly adopting digital solutions, the Middle East is particularly susceptible to cyber attacks and malware. So, as the industry grows to rely increasingly on the advanced, remote technology, it begs the question as to how

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Issue 6 2014

In continuing to adopt cloud computing to boost business, the Middle East energy sector creates a larger landscape for cyber security threats (Photo: Ian Southwell)

The energy sector faces a malware encounter rate of more than 400 per cent” significant the threat posed to the regional oil and gas producers truly is. Globally, the energy sector has and continues to experience major cyber attacks. A prominent example in the Middle East, which illustrates the reach and force of certain malicious software, is the 2012 cyber attack on Saudi Aramco. The Saudi Arabian oil giant was forced to halt operations of its main internal computer networks after a virus infected approximately 30,000 of its workstations. While Saudi Aramco claimed that exploration and production were not affected, as it was operated on separate and isolated systems, the attack did mean the company had to cut off its electronic systems from the outside world in order to prevent further attacks.

Therein lies the key danger and difficulties for those companies that come under attack. Wherever the origins and intentions of the hack, it could be argued that it is not the cyber attack itself that causes the real problem, but rather the millions of dollars in damage that a business can accumulate through both temporarily shutting down operations and combating the attack. Speaking to Oil Review, Sebastian Madden, group cyber and technology director at the UK risk management and security firm Protection Group International (PGI), said, “The cyber attacks on Qatar Gas and Saudi Aramco really shook the oil and gas industry, as well as governments in the Middle East. They’ve registered that there are real vulnerabilities in the industry and people out there who are prepared to exploit them in order to damage national economies by sabotaging systems and disrupting production.” It is worth noting that in the fuelproducing sector, disruption to business does not just affect the company itself and the relevant service companies. It can have

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 Technology

a considerable knock-on effect, influencing national economies, the economies of the countries if helps fuel, and even national and international fuel prices. As a product of such high commercial value and global demand, it is important to consider that the level and complexity of malware used to target the oil and gas companies will be considerably higher. The higher the value of the asset, as Madden explained, the greater the malware used to target it. Ultimately, this means that companies in the industry must not only be prepared for hackers, but adapted to deal with a high-end category of cyber attacks. “As economically strategic assets, oil and gas companies are subject to the interest of state actors with hostile intent,” Madden stated. “This means they have to deal with cyber reconnaissance and attacks at a level of sophistication much higher than that faced by other industries. Consequently, they require higher levels of protection.” As the push for fuel production in the Middle East and North Africa grows, so too does the evolution of technology and the development of companies’ infrastructures. Oil and gas producers are relying increasingly on controlling operations remotely and monitoring data from across the globe. In fact, according to figures by Cisco, smart devices in the Middle East and Africa will grow from 133mn in 2013 to 598mn in 2018. The region is also set to post the world’s strongest cloud traffic growth, reaching 157 exabytes by 2017, up significantly from 16 exabytes in 2012.

All organisations across the Middle East should assume they have been hacked”

Rabih Dabboussi, Cisco UAE general manager

Dabboussi explained, “Great mobility means that mobile devices can get more easily infected and can lead to malware spreading faster. The introduction of mobility is a concern for energy companies as there are a wide range of devices used with pipelines, oilfields and oil platforms. Securing and managing these devices is critical.” It is safe to say, unfortunately, that attacks from malware, or at least the threat of such attacks, has become a common and consistent feature in the energy sector business. “All organisations across the Middle East – especially in the energy, oil, and gas sector – should assume they have been hacked, and that it is no longer if they will be targeted by cyber-attacks, but rather when and for how long. Adversaries are coming up with new methods for embedding their malware in networks, remaining undetected for longer periods and stealing data or disrupting critical systems,” warned Dabbouss i. Fortunately it appears steps are being

taken to tackle the growing threat, but perhaps it has reached a point whereby infrastructure development and cyber security should be considered hand-in-hand. According to global consulting firm Frost & Sullivan, the oil and gas infrastructure market is expected to grow worldwide to US$24.68bn by 2021, up from US$19.63bn in 2013, comprising of a range of solutions intended to defend critical assets across the industry. Furthermore, the Middle East has been highlighted as an area requiring the highest levels of security across all segments and, alongside South America, in future will experience a significant growth in security spending. Dubboussi concluded, “Companies must realise that security is no longer the responsibility of IT professionals alone. Mobile operators, device manufacturers, software developers and businesses all have to take up a post in this war and be on high alert for potential cyber spill over, especially with mobile malware.” n

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 Technology

Energy efficiency through

optimal operations Brendan P Sheehan from Honeywell Process Solutions, USA, and Xin Zhu from UOP, a Honeywell company, discuss how to utilise data as a way of achieving energy efficient operations and, ultimately, capital savings. VEN AS WE currently see a more stabilised and favourable price in the energy sector, energy efficiency cannot be overlooked as a successful way of gaining a competitive advantage in the oil and gas industry. Energy usage can often be optimised through simple improvements that are not necessarily expensive, yet operators, engineers and other users do not typically have the information they need to give them the confidence to simultaneously push against the many system constraints that are necessary for optimal plant operations. They typically avoid the challenge and instead frequently make a conscious or unconscious decision to back off to a more conservative position, which involves running the plant safely, but at a considerably lower level of efficiency.

Providing users with process data The first step in improving energy efficiency is to provide users with data that they can use to make the right decisions. This enables users to look at the ‘actual’ versus the ‘predicted’ energy use and adjust the predicted energy usage according to the operating conditions, as opposed to leaving it as a static target. As the actual energy consumption deviates from target these changes can be calculated and quantified in terms of their energy impact, meaning operators can easily focus on the most important items. This data will also show the greenhouse gas (GHG) emissions associated with the unit and help provide answers to questions, such as: how much energy consumption and GHG emissions should one expect for a particular crude feed? If production rates fall by a certain amount how much should energy consumption fall? How are GHG emissions affected by changes in operating conditions? How can energy consumption and GHG emissions be reduced by changing operating parameters?

By providing operators with data on the ‘actual’ versus the ‘predicted’ energy use and adjust the predicted usage accordingly

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A report answering such questions can be produced by calculating actual energy use, per unit and equipment item, from process data and calculating key energy indicators (KEIs) to provide guidance to operators. In this case, energy use can be calculated by determining steam per barrel of production, million British thermal units (MBTU) fuel per barrel of production and Megawatt power per barrel of production. Energy consumption may also be calculated on a per rate or per hour basis. KEIs provide operational targets that help identify where energy is being wasted. Energy consumption may also be calculated by a simulation model, estimating energy consumption by regressing historical data that covers a wide range of operating conditions. In a distillation column, for example, the expected steam consumption may be estimated as a function of the feed rate, the feed composition and perhaps the operating mode or product specification targets. The alternative approach for simulating the process is useful in applications where there is only limited historical data or where all the data is at one operating point. The simulation model could be put online with live process data connected directly to the inputs of the model, which can often provide a reasonable estimate of energy consumption while avoiding the effort required to develop, implement and support a complex model.

Measuring performance against targets To monitor energy performance against targets, actual energy use, (per unit or equipment), can be compared to energy use predicted by the model; an adjustable threshold that identifies violations will alert the user as a particular variable moves away from the target. The economic and environmental impact of these deviations can be calculated and tracked over time to help prioritise areas on which to focus for potential improvements and can also perform the calculations required for reporting on GHG emissions. Where deviations from target are identified, the system operator can use the KEIs to determine and record the reasons for these deviations. For example, high fuel consumption around a heater might be due to high air or high stack temperature or excessive heat input to a downstream column. By developing a set of reason codes and logging them over time, operators are able to build up a library of common causes for deviations and consistent use of reason codes helps predict the likely cause of future deviations. Measurements that are not currently being taken are often needed in order to provide the necessary granularity to identify where opportunities for improvement may exist. This could include total power to an area of the plant that may be measurable at the substation, and by further breaking down these measurements, by unit or major item of equipment, can help pinpoint problems and ultimately reduce energy consumption. A particularly cost-effective approach to adding these instruments is to use wireless transmitters,

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ď&#x192;¨ Technology

which eliminate the expense of running wiring between the instrument and the control room, and can provide a simple-tomanage, easy-to-operate solution that integrates with the existing distributed control system (DCS). For a small installation, a multinode receiver with wireless transmitters is sufficient, but for a larger installation, a mesh network that provides multiple redundant paths enables better reliability and can support a variety of protocols and applications simultaneously. This data can then be consolidated into an energy dashboard that provides users with a roadmap of how to minimise energy consumption and emissions. The dashboard clearly identifies which unit or area is deviating from the target, the economic and environmental impacts, and the most likely causes of the problem. Users can quickly pull up a report of the top-10 worst energy problems that can serve as a work-list for the team, and shows how much energy should increase as feed rates go up and down, or feed type changes in order to account for production changes. Planning and energy consumption monitoring should be based on the same model so that they are aligned with each other. Consistent execution of operating procedures can also improve energy efficiency, with examples including start-up and shut-down, moving to a safe operating position when an abnormal situation occurs, cyclic planned activities, including regeneration, catalyst reload, and pump changeovers. Execution can be made more consistent by providing the operator with easy access to the details of the procedure. The operator, for example, can click on the shutdown procedure button on his operator screen and pull up the details for shutting down the unit in question.

Developing an advanced process control (APC) strategy Major improvements in energy efficiency and emissions reduction can be achieved by providing operators with tools to help them manually optimise operating conditions. Even greater improvements can usually be obtained by incorporating best practices into an online predictive control strategy that automatically optimises operating conditions. Multivariate optimisation applications can be used to maximise throughput, maximise yield and minimise energy consumption and emissions just by changing cost factors in the objective function. This environment makes it possible to incorporate energy strategies into overall operating parameters so that minimising energy is not done at the expense of other important objectives, such as maintaining yields of the most valuable products.

Optimisation and control of the utilities plant is an important part of any energy management strategyâ&#x20AC;? A common strategy for any unit that has a significant heat load is to maximise feed preheat to reduce fuel consumption in the process heater. An effective optimisation strategy for multi-path preheat trains, typically found in crude units, is to estimate the heat transfer coefficients across the exchangers in each path and use them to calculate the potential increase in duty that can be achieved in either path from an increase in feed flow through each path. These coefficients can then be incremented until the duty gain is the same in either path of the preheat train. This kind of simulation can be incorporated into a multivariable predictive control strategy as a controlled variable (CV), a strategy that can reduce fuel consumption or, if the heat is the bottleneck, increase throughput. Column control can also be used to improve energy efficiency. The advanced control strategy should aim to control yield and quality of the product streams, the feed temperature, reflux ratio and the steam/feed ratio. Where distillation endpoints are an objective, the side stripper steam can be used for maintaining five per cent distillation point close to the specification. A common strategy to improve yields and reduce energy consumption and GHG emissions is to reduce column pressure, which, in turn, improves separation of key components. It is also important, however, to avoid flooding in the column by monitoring pressure across the critical sections.

Optimising the utility plant Optimisation and control of the utilities plant is an important part of any energy management strategy. The boilers should be controlled with the objective of providing the process with adequate steam and power, while minimising fuel consumption in boilers. Multiple boilers will vary in performance so it is important to be sure that they are balanced by boiler efficiency rather than steam production. Boiler cost curves should be used to distribute the total heat requirement, whereas the incremental load should be distributed to the boiler with the lowest incremental cost. The implementation of operational solutions for improving energy efficiency, which tightly link demand from the process to supply from the utility plant, can typically improve energy efficiency by two to four per cent with corresponding CO2 emissions reduction of approximately 21,770mn to 43,540mn mt per year for a typical 100,000 bpd refinery. Many of the solutions discussed here can be implemented quickly and without large capital costs, while still generating immediate savings that can help pay for long-term energy efficiency strategies that require more substantial capital investments. â&#x2013;

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Utilising offshore

multiphase pumps We look at the successful implementation by multiphase pumps and systems specialist Leistritz Pumpen GmbH of multiphase pumps on a project in the UAE. HE USE OF multiphase pumps in both onshore and offshore applications has been experiencing an increasing acceptance among oil and gas producers thanks to the technologyâ&#x20AC;&#x2122;s role in keeping marginal and declining oil fields producing, as well as acting to reduce flaring. An offshore installations in the UAE commissioned the use of twin screw multiphase pumps on a wellhead platform. The multiphase pump installation on the field, which began production in the mid1980s, was designed to sustain production at its current level. The implementation of short-term development projects on the field consisted of the installation of electrical submersible pumps (ESP) and a multiphase pump (MPP) at selected well head platforms (WHP). The majority of multiphase pumps in operation today are based on twin screw pump technology. These self-priming pumps are hydraulically balanced and of a double volute design. The possibility of speed variation by means of variable frequency drives offers a wide operating envelope. Twin screw multiphase pumps are available for flow rates up to 5,000 m3/h (755,300 bpd) and differential pressures up to 150 bar (2,175 psi). The pumps are designed to handle high gas volume fractions (GVF) and to tolerate gas slugs with 100 per cent GVF.

Cost-effective technology Engineers working on the UAE project proposed multiphase pumps as a costeffective technology to transport multiphase fluid via a single pipeline, instead of separating oil, water and gas at gathering stations and exporting oil and gas through separate pipelines to central production facilities. Multiphase pumps are essentially a means of adding energy to the unprocessed well stream, which enables liquid/gas mixtures to be transported over longer distances without the need for prior phase separation.

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Cutaway of a high pressure multiphase pump (Image: Leistritz Pumpen GmbH) Pumping the multiphase fluid directly to the central processing facility eliminates the requirement for separators, heater treaters, pumps, compressors and storage tanks at the in-field gathering stations and offers a range of advantages, including the reduction of installation space requirements due to less equipment. It also offers a reduction of operation and maintenance interfaces due to less equipment, and a reduction of manpower, as MPP installations prove to be suitable for remote control and require no permanent manning. Further arguments for the installation of multiphase pump technology include the debottlenecking of existing flow lines by maximising the throughput, as well as the integration of low and medium pressure wells into a high-pressure manifold/separator. Additional benefits include the integration

of marginal fields or remote tie-backs to existing facilities, segregated production schemes of medium and low pressure wells by using dedicated multiphase pumps, and production restoration of dead wells by reduction of the well back pressure. The technology offers the maximum utilisation of existing production facilities on a declining field by adding production from remote wells, as well as the elimination of flaring and gas recovery by boosting the unprocessed well stream to central separation facility and the reduction of unstable flow regimes in multiphase pipelines to higher superficial velocities. Multiphase pumps are designed to operate with variable suction pressures. This is a major advantage over conventional separation systems featuring compressors which are designed to operate solely at a pre-determined fixed inlet pressure level.

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Technology ď&#x192;§

Wellhead platform installation For the installation of the multiphase pump on the UAE project the operators chose production facilities on a wellhead platform with six wells. There were three low pressure wells intermittently flowing or not flowing at all due to the high pressure from the remaining wells into the common manifold. It was therefore considered technically and commercially feasible to install a multiphase pump at the wellhead platform connecting the low pressure wells. The multiphase pump system which is now installed on the wellhead platform consists of the following components: 6 The pump skid with the multiphase pump, the electric motor, the lube and seal oil system, an automatic filter, the liquid management system, the on-skid piping with motor operated valves and the on-skid instrumentation. 6 The air conditioned and pressurised control container for the VFD, PLC etc. 6 The transformer. 6 The low-voltage distribution board (LVDB). The space available for the installation of the multiphase pump system on the wellhead platform represented a major challenge. Due to the small surface area for the equipment, the skid had to be designed as compact as possible. Since there were no close limitations in the equipment height it was possible to install pump and drive above the liquid management system in order to reduce the width of the skid. Another challenge was the small space provided for the transformer. However, finally a manufacturer was found that could meet both the project specification and the required footprint. Hydrogen sulphide, chloride Due to the H2S concentration and the high chloride content of the produced water, all wetted parts of the pump and the further skid components are made from duplex

Multiphase Pump Skid on the Multiphase Pump Test Bed (Photo: Leistritz Pumpen GmbH) P & ID of conventional and multiphase concepts (Image: Leistritz Pumpen GmbH) stainless steel, meeting the requirements of NACE MR0175. The casing insert (liner) is wear-resistant coated with StelliteÂŽ. The pump shafts are also sealed by double acting, balanced mechanical seals in back-toback arrangement. In case of slug flow, the liquid management system provides sufficient liquid seal to the area between screw tips and casing insert to guarantee uninterrupted production. Pump bearings, timing gears and the mechanical seals are lubricated and cooled by a combined lube and seal oil system which is also accommodated on the pump skid. The automatic filter protects the pump internals from wear and damages by solids travelling with the multiphase fluid from the wells. Before shipment to the UAE, the pump skid and all accessories were extensively tested on the multiphase pump test bed of the pump and system manufacturer and the premises of the selected sub-vendors. All

tests have been witnessed by the representatives of the end customer. The multiphase pump skid was successfully commissioned during the Q3 2008. A new production manifold was installed to separate the flow between the high pressure and the low pressure flowing wells. The low pressure wells are connected to the suction line of the multiphase pump, resulting in a reduction in back pressure for the weak wells and, hence, a considerable increase in production. Project completed When the project started a couple of years after the turn of the century, there was limited experience with multiphase pumping technology in the Middle East. The application presented serious challenges in view of the design for the restricted space available and the selection of the construction materials. After almost four years of operation, the installation can be considered a success by the operator, manufacturer and supplier of the Multiphase Pump System. â&#x2013;

Issue 6 2014

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 Communications & IT

Harnessing the benefits of the

Intelligent Field Deploying the new technologies and work practices relating to the Intelligent Field can help oil companies to achieve their goals, says Andrew Dennant. VERY OIL COMPANY has goals related to increasing profits, decreasing costs and improving safety. And every oil company executive knows that one definition of insanity is to keep repeating the same set of actions and to expect a different outcome. That is why oil companies around the world, including those in the Middle East, are harnessing new technologies and work practices in the form of the Intelligent Field to help them achieve their goals. Although the Intelligent Field is often presented in terms of its new technologies, it is important to remember that these are only a part of the story. They both enable and require operators to work in new and different ways in order to effect the step-change in efficiency that the Intelligent Field promises. Changes of this magnitude are, by necessity, journeys and it is the role of management to keep its people moving along these journeys and continue to drive change. The Intelligent Field changes the way that production companies work. Multidisciplinary teams identify and attack challenges in parallel, with real-time data on which to base their decisions. The location of the team is the best place to put it, whether that is adjacent to the process or not. And this requires us to be mindful of how we assemble these teams – how we take advantage of both the experience of older personnel and the tech-savvy, databased approach of younger team members to ensure that the team delivers the optimal outcome. The result of all of these changes in the way that we work is that we can plan, proactively, how to optimise a field’s operations, rather than reacting to situations in a way that minimises their impact. The Intelligent Field gives visibility to critical operating data in time to make a difference to the business – it is a technical solution to resolve a business issue. It allows users and equipment in remote locations to play a part in optimising the

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Issue 6 2014

Andrew Dennant, oil and gas director for the Middle East & Africa, Emerson Process Management

The Intelligent Field changes the way that production companies work” whole of the value chain and to measure the effect of the decisions that are implemented. The Intelligent Field is implemented in phases, over time, with a methodology that touches on technology, software, organisation design and business process design.

Essential elements Some observers have confused the implementation of a consolidated control room with the building of an Intelligent Field. The Intelligent Field will likely include an Integrated Operations Command Centre,

but it will be built on an architecture that reflects the ISA 95 or Purdue Model. Reliable devices are needed to measure process parameters, and these need to be connected to control and safety systems with transmitters and infrastructure that allow the communication of process and device diagnostics. Smart control systems keep process values close to set points and alarm when there is a deviation, allowing people to concentrate on exceptions, rather than logging and analysing data. Higher-level applications for production planning and optimisation take data from a variety of sources and put it into context to allow humans to make intelligent decisions – there is no Intelligent Field without humans in the loop, and there is no Intelligent Field without quality data. Links to the business system, to monetise the decisions that are made, is the final element that makes the Intelligent Field complete. Essentially this allows teams to make decisions that maximise the profit per day, rather than the production per day, and to understand the impact of their decisions in the short, medium and longer term. One of the keys to implementing the Intelligent Field is the implementation of role-based Key Performance Indicators that are aligned with, and cascaded from, the organisation’s goals. These should be visible and updated by the system in real-time to allow teams at every level to create action plans informed by current data. The Intelligent Field delivers benefits to all parties – operators, partners and service companies – who use improved data and knowledge management, enhanced analytical tools, real-time systems and more efficient business processes to work together more effectively and in better alignment. ■ Andrew Dennant is oil and gas director for the Middle East & Africa at Emerson Process Management

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 Innovations

Honeywell’s new software can boost production performance by up to five per cent HONEYWELL PROCESS SOLUTIONS has launched Digital Suites for Oil and Gas, a new set of software and comprehensive services, which can help energy producers boost production performance by three to five per cent while improving operational safety. Digital Suites for Oil and Gas is a fully integrated offering, but each suite is also available separately, letting customers address the specific issues they face. The six suites are operational data, process safety, production surveillance, equipment effectiveness, production excellence and operational performance. The new offerings combine Honeywell’s field-proven technologies with new software and implementation methodologies delivered through its new oil and gas center of excellence, which was recently established to better serve Honeywell’s customers in the upstream oil and gas industry. Digital Suites for Oil and Gas is said to work seamlessly with Honeywell’s complete line of integrated control and safety systems, instrumentation, and industrial products, and can be easily integrated into any multi-vendor environment. The production improvements, which have been validated through customer testing, are driven by a combination of better productivity, higher uptime and more efficient remote operations, and can produce a return on investment in as little as six months, according to the company. Ali Raza, vice-president, Honeywell Process Solutions, said, “Upstream oil and gas producers tell us they have access to more real-time data than ever, but access to that data alone is not enough to improve performance — you also need digital

The software can meet the challenges like safer operations and insightful decisions with datadriven solutions that are ready for new operations or integrated into existing production environments intelligence to make sense of all the data being collected. “Digital Suites for Oil and Gas turns data into digital intelligence that helps operators make critical decisions faster by capturing, managing and analyzing the right production information.” The software can meet the challenges like safer operations and insightful decisions with data-driven solutions that are ready for new operations or integrated into existing production environments. Digital Suites for Oil and Gas software also helps to ensure that essential safety procedures perform as designed, operators are fully trained, alarms are managed and enforced, and production performance is instantly available to detect and mitigate potential events. These solutions make collaboration through remote operations a reality, helping to manage the number of local personnel, especially as the upstream industry moves farther offshore into higher-risk conditions.

Cygnus offers underwater solutions to tackle corrosion and leaks IN MARINE AND shipping industry where steel corrosion is a constant challenge, Cygnus ultrasonic thickness gauges play a major role in providing a solution to this challenge. The Cygnus Multiple-Echo technique can measure the remaining metal thickness through protective coatings. However, this measuring technique can sometimes be difficult to achieve when measuring on extreme front face and back wall corrosion and round bars such as anchor chain links. This is why Cygnus has introduced Single-Echo, using twin-crystal probes into their product range providing users with the flexibility to alternate between the two with Cygnus DIVE. Cygnus DIVE is a wristmountable underwater thickness gauge. The DIVE has a number of key new features that include twin-crystal probe option to assist in taking measurements on uncoated material e.g. anchor chain links, extremely corroded steel and plastic outfall and dredge pipes; Measurement Stability Indicator (MSI) that shows when a reading in single-echo mode is stable by turning the thickness reading from red to yellow; a super bright AMOLED display, easily viewable by both the diver and his camera; and updated topside and reporting software allowing measurements and A-Scans to be displayed on the surface and data logged topside.

Seatronics adds Teledyne RD Instruments’ products to its sales portfolio in the Middle East AN ACTEON SUBSIDIARY and marine electronic equipment sales and rentals firm Seatronics has partnered with Teledyne RD Instruments to sell its marine measurement and navigation products in the Middle East and South America. Seatronics will sell Teledyne RD Instruments’ Acoustic Doppler Current Profilers (ADCPs) exclusively in Saudi Arabia, UAE, Qatar, Oman and Bahrain; and represent the company for Doppler Velocity Logs (DVLs) non-exclusively in Qatar, Saudi Arabia, Oman and Bahrain. Harry Maxfield, vice-president, sales and marketing at Teledyne RD Instruments, said, “We hope this enhanced working relationship will enable us to build upon Seatronics’ presence and reputation in regions that can be challenging for us to address due to time zone differences.” Adil Ali, international product sales manager

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Issue 6 2014

Cygnus Hatch Sure Leak Detector

A buoy with Teledyne RD Instruments workhorses long ranger ADCP at Seatronics, added that this partnership will enable their existing and potential clients to gain a higher level of pre-purchase technical advice and post-sale support in the regions the agreement covered.

The ability of the diver to wear Cygnus DIVE on his arm or wrist is a big advantage, said Graham Haines, sales director at Cygnus. Ultrasound can also be used for checking the weather tightness of hatch cover seals on bulk carriers. Cygnus Hatch Sure ultrasonic hatch cover leak detection system comprises a powerful ultrasonic transmitter with 19x40KHz elements is placed within the ships hold. This fills the hold with ultrasound and any that escapes (through gaps in damaged areas of the seals) can be detected by the operator on deck using a sensitive receiver/listening device, locating areas that might leak in heavy seas or rain.

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RELIABILITY IN OIL WELL CEMENTS Oil Well Cement (OWC) produced by Oman Cement Company

(S.A.O.G) under accurate temperatures is an obvious choice for oil well cementing worldwide and now it is ready to face the challenges of highly specialized arctic and horizontal cementing:

● Conforms to the American Petroleum Institute (API) specification – 10A Class-G- (HSR), Class-B- (HSR) and Class-A- (O) grades. ● Tested and used by worldwide cementing companies ● Easy to disperse resulting in considerable cost savings ● First choice of major oilfield companies ● Exported to GC Countries, Iraq, Yemen, Libya, Sudan, Tanzania, Turkmenistan, Ethiopia, Pakistan, India and Syria. Oman Cement manufacturing facility operates on world class quality management system ISO 9001 and environmental management system ISO 14001. Quality control is online and laboratory automation systems consist of online x-ray spectrometers and robotic samplers, linked to process controllers and a raw mill proportioning system. OCC has an enduring commitment to customer satisfaction, continual improvement and a stronger foundation for tomorrow. Winner of His Majesty’s Cup for the Best Five Factories in the Sultanate of Oman for 10 times.

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Oman Cement Company (S.A.O.G) Corporate Office: PO Box 560, Ruwi, PC 112, Sultanate of Oman Tel: +968 24437070 Marketing: Ext 145 / 444 Fax: +968 24437799 Email: admin@omancement.com Website: www.omancement.com

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 Innovations

Emerson’s variable speed solutions enhance beam pumps in lift process EMERSON INDUSTRIAL AUTOMATION’s Powerdrive FX four-quadrant drive, in combination with an LSRPM synchronous magnet-type motor from the company’s Dyneo range, has been instrumental in the increasing numbers of wells using beam pumps RRP (reciprocating rod pumps). RRPs have a particular operating cycle whereby power is actually produced 15 per cent of the time and this power had to be dissipated through bulky braking resistors. However, using the patented, compact, fourquadrant, C-Light Powerdrive FX, these issues are negated. According to the company, numerous concerns over fixed speed RRPs are driving demand for variable speed solutions. These include pump-off, which will likely occur if production is too high (incorrect pulley-belt ratio). Secondly, pulley-belt ratio adjustment is required frequently in young and new wells. Other concerns over fixed speed pumping include the limitation of monitoring possibilities and potential difficulties in detecting fluid pound. Furthermore, too many motors on the same electric network can cause a lagging power factor, driving the need for capacitor banks.

Powerdrive FX four-quadrant drive in combination with an LSRPM synchronous magnet-type motor In contrast, variable speed technology allows pumping speed to be adjusted to field requirements, thus avoiding field work and the interruption of production. Further advantages include the ability to correct the oilfield’s power factor without the need for capacitor banks, while it also provides soft starting, torque limitation and constant speed. For instance, there is no need for additional resistors – the power generated is fed back naturally to the power supply like with a line contactor in fixed speed. The harmonics are 25 per cent lower than a conventional six-pulse solution independent of

Schlumberger launches industry-first photorealistic reservoir geology service SCHLUMBERGER’S QUANTA GEO service is the industry’s first micro resistivity imager that produces oriented, photorealistic, core-like images of the formation in wells drilled with oilbase mud (OBM). Interpretation of the images identifies geological features andalso predicts reservoir trends in 3D with what the company says is a high degree of certainty. It is the inaugural member of the new Quanta Family reservoir characterisation services, which employ new measurement physics to deliver highest accuracy, workflow-ready downhole measurements for direct use in refining reservoir models. Launched at the Offshore Northern Seas Annual Conference and Exhibition in August 2014, the physics of the Quanta Geo service’s high-resolution array of 192 microelectrodes overcomes the electrically resistive barrier imposed by OBM. The unique articulated caliper and independently applied pads enable downlogging at up to 1,097 metres per hour, which significantly reduces rig time while mitigating operational risk and delivering data assurance. The service is combinable with most other Schlumberger wireline openhole tools. Hinda Gharbi, president of Wireline at Schlumberger, said, “The Quanta Geo service provides photorealistic images that can be used to condition and constrain reservoir models, enabling our customers to better understand their reservoirs and make confident decisions.”

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The Quanta Geo service provides photorealistic images that can be used to condition and constrain reservoir models The company said that using the Schlumberger Techlog wellbore software platform, data acquired by the Quanta Geo service is easily rendered, creating an image of 0.24 in resolution that resembles a whole core. Geologists interpret these images in the same manner that they would perform continuous core description, with the added benefit that these images cover a longer continuous interval and are precisely oriented. This enables extraction of key reservoir parameters such as the structural dip, or the identification of sand body type, extent and orientation. The Quanta Geo service has been field tested in more than 50 wells in deepwater, unconventional and carbonate environments in a variety of regions.

the load, while a better power factor means that Powerdrive FX also offers significantly lower line current. Other advantages of Powerdrive FX include easy installation either outdoors or indoors, and a rugged design featuring tropicalised boards and a resin-treated line choke. In addition, Powerdrive FX eliminates the requirement for technicians to visit the site to retrieve well data, set speeds and reset any faults. Full production optimisation will rely upon pairing a Powerdrive FX with an LSRPM synchronous magnet-type motor from the Dyneo range. Over a cycle, the torque profile of a RRP averages 50 per cent of the nominal torque of the motor. In comparison with an induction motor, the higher efficiency of Emerson’s Dyneo LSRPM over a wide speed and load range will lead to significantly reduced electricity consumption. Other benefits include its advanced design, which saves on maintenance through longer bearing life and reduced lubrication intervals. Furthermore, not only is the LSPRM motor smaller and lighter than a standard induction motor, it is also proven technology that does not require servicing any differently.

Mirage Machines expands office in UK ENERGY SECTOR PORTABLE machine tool manufacturer Mirage Machines has expanded its headquarters in Derby, UK, in response to the rising demand it has experienced for its pipecutting and flange facing technology. With new office premises measuring 464.5 square metres adjacent to its existing engineering headquarters, the site at Enterprise Way includes fullscale technology engineering, fabrication, maintenance and R&D departments producing machines used across the international oil and gas, and petrochemical industries. Richard Silk, managing director of Mirage Machines, commented, “We have ramped up our manufacturing operations to meet that demand for our machines in exploration and production, maintaining our reputation for producing technology of the highest quality, with performance and reliability the cornerstones of our business.” Mirage Machines designs and manufactures technologies for applications including drilling and tapping, flange facing, hot tapping and line stopping, line boring, milling and gantry milling, orbital milling, and pipe and casing cutting.

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 Innovations

Tendeka’s new hydraulic fracturing system with real-time frac monitoring and analysis TENDEKA, COMPLETIONS SYSTEMS and services provider to the upstream oil and gas industry, has launched FracRight, a complete heel-to-toe hydraulic fracturing system. Integrated with Tendeka’s real-time DTS monitoring and QuestTM software suite, the system enables the collection and analysis of stimulation data in unconventional reservoirs. According to the company, the FracRight system is a fully integrated frac sleeve solution for selective multi-zone stimulation in open hole or cased hole applications. It enables The FracRight system is a fully integrated frac sleeve solution for selective multi-zone stimulation in open hole or cased hole applications

the installation of multiple sleeves for each stage to be fractured, optimising stimulation efficiency and production. The sleeves are shifted open by pumping a ball from surface allowing for subsequent stimulation of the selected stage either from a single sleeve or a cluster of sleeves. The FracRight system can be integrated with Tendeka’s real-time distributed fibre optic stimulation monitoring service to provide more effective evaluation and management of multizone completions. The system gathers the information required to measure, model and optimise the stimulation treatment and subsequent flow back and production profile. Ken Miller, vice-president of North and South America of Tendeka, said, “Our experience and track record in the US frac market has led to the development of the FracRight stimulation monitoring system, which will enhance fracture performance and efficiency. “Capturing the real-time data from the FracRight system allows our clients to verify isolation integrity, analyse the individual characteristics of each production interval and make critical adjustments in the frac operation. The result — completion operations are optimised while minimising costs and mitigating risk.” He added that the system can also be used in conjunction with Tendeka’s QuestTM software suite for the analysis and presentation of the stimulation and production data.

Paradigm releases advanced engineering suite PARADIGM’S LATEST VERSION of its integrated suite of well planning and drilling engineering applications Sysdrill 10 has been integrated with Peloton’s WellView corporate database for drilling and well operations, and includes a new jar placement module based on technology acquired from Cougar Drilling Solutions. The release reportedly offers significant engineering enhancements to the product’s existing well planning, torque and drag, hydraulics, casing design, cementing and well control modules. The new jar placement module allows calculation of optimal jar locations based upon the jar operating parameters, drilling parameters, and the well trajectory. The integration with Peloton offers solution for well planning, drilling engineering, daily reporting and data management throughout the well lifecycle. Drillin g engineers can send a fully engineered Sysdrill well design to WellView, and during drilling operations, data captured in MasterView can be used in Sysdrill to perform engineering analysis to monitor drilling and prevent NPT events.

SOSS expands manufacturing factory in the Middle East

New locking solutions

SOSS NOW HAS the largest steel drum manufacturing factory in the Middle East with the newest state of the art technology and equipment; on an average it can manufacture 60 drums per hour, enabling the company to continue servicing its customers in all locations. SOSS has been in SOSS is strategically located in Dubai existence since 1993. Strategically based in Dubai, SOSS began operations in the Middle East and Asia as an independent supplier of pr oducts to the oil and gas industry. The company’s tenacity and focus on quality has led to its expansion from a small supplier of steel/plastic drums, cans and industrial and construction chemicals, to a reputable chemical stockiest and supplier for the oil and gas industry, with branch offices today in India, Iraq and China. Consistent with its growth, SOSS has added diversity to its product range and upgraded its facilities and procedures to comply with the strictest demands from its clients. Today the company caters to oil and gas, industrial and construction customers with a vast and varied product range across a range of industry segments. It has exclusive signed agreements and contracts with a number of international manufacturers. The company’s warehouse facilities in Dubai and Iraq are fully geared to cater to the region of Iraq, Middle East and Africa. The logistic positioning of its warehouses and storage areas in Dubai ensures the quick and timely delivery of materials so as to cater to any urgent customer requirements. Currently SOSS has a small facility for manufacturing caustic solutions, which are mixed and transported to many locations in the UAE and GCC.

VINGCARD ELSAFE, THE pioneer and world leader in electronic security solutions, has products installed in more than 42,000 properties worldwide, securing in excess of seven million rooms and providing security wherever people sleep away from home. The company provides local service and support in 170 countries. VingCard electronic locking system solutions include the latest RFID contactless electronic locks compatible with the main ISO standards: ISO 14.443A (MIFARE), ISO 14.443B, ISO15.693, NFC (Near Field Communication) / BLE (Bluetooth), and also the most reliable wired or wireless RF-online solutions. VingCard Elsafe has initiated a growing trend towards minimising locks with our Essence RFID. Our new Allure takes the minimalistic "invisible lock" concept one step further. Elsafe provides the only ULlisted (1037) in-room safe series on the market today in keypad and RFID/RFonline models, like the new SENTINEL II and Infinity II series range. Orion by VingCard Elsafe provides an intelligent environment friendly energy management solution that reduces energy cost.

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 Innovations

Thrustmaster launches dynamic vessel converter for offshore operations THRUSTMASTER’S PATENTED PORTABLE Dynamic Positioning System (PDPS) consists of modular, deck mounted azimuthing thrusters with separate hydraulic power units and a DP control van interfaced and ready to go. The whole system can be quickly installed dockside without dry-docking and without extensive modifications to the vessel. According to the company, it is ideal for upgrading derrick barges, pipe lay vessels, cable lay barges, accommodation vessels, FPSOs, heavy lift vessels, and more. As offshore operations move to deeper waters, one can upgrade the anchor moored vessels to DP-1, DP-2 or even DP-3 to meet and exceed the standards set by any classification PDPS Installed on Versabar VB 10,000 — a society, the company added. barge-mounted dual truss system with the This vessel opportunity can be ready to go ability to perform single-piece topside in no time with power ranges from 225kW to floatovers and retrievals of up to 10,000 tonnes 2,250kW (300HP to 3,000HP), DP Systems, controls and deck mounted or internal skid hydraulic power units. The portable thrusters are mounted on deck using a minimum amount of deck space. They use direct hydraulic drive to the propeller. The variable speed hydrostatic drive motor is in the lower foot of the thruster directly in line with the propeller shaft. This direct hydraulic drive eliminates the need for right angle gear transmissions and drive shafts used on other thrusters. Best suited for vessels between 30 to 180 metres in length, PDPS can be provided per DPS-0 to DPS-3 requirements of any classification society.

Flowserve’s new bearing gard can reduce contamination in pumps PROVIDER OF FLOW control products and services Flowserve has introduced its new Bearing Gard bearing isolator. One of the major causes of pump downtime is contamination of the bearing lubrication system. The new Flowserve bearing isolator can significantly reduce this contamination, in part due to the addition of static shut-off technology. Flowserve has also developed a faster manufacturing process to provide sameday manufacturing and shipping, even on custom bearing isolator orders. An optimised oil collection chamber works to keep oil inside the bearings and off the ground. Flowserve bearing isolators support pumps serving chemical processing, petrochemical, biofuel, corn processing, pulp and paper, oil and refining, power, water and wastewater, mining, etc. The Bearing Gard bearing isolator was launched at the 2014 Turbomachinery and Pump Symposia in Houston, US, in September.

Hempel’s new HEMPADUR AvantGuard® primers redefine anti-corrosion GLOBAL COATINGS SUPPLIER Hempel have just announced the launch of HEMPADUR AvantGuard®, a portfolio of three new anti-corrosive zinc primers. Based on unique, patented AvantGuard® technology, HEMPADUR AvantGuard® coatings provide better anti-corrosion protection than zinc epoxies without AvantGuard®. Zinc coatings are used to protect industrial structures and equipment in C4 and C5 corrosive conditions, where saltwater and high humidity corrode unprotected steel. Based on new, patented AvantGuard® technology, HEMPADUR AvantGuard® activated zinc primers are developed for a range of industries and applications, from offshore oil and gas platforms to wind turbines. Pernille Lind Olsen, group protective product director at Hempel, commented, “AvantGuard® is perhaps the biggest change in anti-corrosive The HEMPADUR AvantGarde series was developed for applications including offshore oil and gas platforms

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Issue 6 2014

technology since zinc coatings were first introduced during the 1960s. The technology gives customers strong anti-corrosion performance in a coating that has high mechanical strength.” AvantGuard® uses hollow glass spheres and a proprietary activator to activate more zinc in the coating, ensuring a significantly higher galvanic effect than zinc primers without the AvantGuard® technology. The technology also enables barrier and inhibitor protection, and so combines three protective effects in one. Furthermore, the unique formulation improves the coating’s mechanical strength, which is essential for applications with, for example, extreme temperature and humidity fluctuations. “In a standard zinc epoxy protective system, the zinc primer is the weakest mechanical point and, as a result, cracks can form in the coating as the steel expands and contracts under extreme conditions,” said Josep Palasi, Hempel R&D director. “AvantGuard® zinc coatings are different as the glass spheres and sub-products that result from the unique zinc activation process stop micro-cracks as soon as they form. This, we can say, makes the coating self-healing.” The increased protection and durability has been proven in extensive Hempel tests, including salt spray tests (ISO 12944 part 6), cyclic corrosion tests (ISO 20340 - NORSOK M-501 revision 6) and thermal cycling resistance tests (NACE cracking test and Hempel’s welding test). HEMPADUR AvantGuard® primers can be applied using the same application techniques as standard zinc epoxies. “In our tests, HEMPADUR AvantGuard® shows a high tolerance to different application conditions, such as high temperatures and humidity, and we even see high crack resistance when the coating is applied with an excessive dry film thickness,” Pernille Lind Olsen said. The HEMPADUR AvantGuard® series currently includes three different zinc primers and was released worldwide on 23 September 2014.

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 Innovations

NETZSCH wins Global Product Leadership Award in Progressive Cavity Pumps for Oil and Gas NETZSCH HAS won the 2014 Global Product Leadership Award in Progressive Cavity Pumps for Oil and Gas, its second Frost & Sullivan best practices award since 2011. Frost & Sullivan notes that NETZSCH has developed innovative technologies that aid end users with current challenges. The company, which has been making cavity pumps for over 60 years, collaborates closely with customers, enabling it to design products that meet their specific requirements, whether in up-, mid- or downstream applications. Together with joint venture partner Heishin in Japan, NETZSCH says it has 28 per cent of global market share of these pumps. Oil and gas is a critical process industry, as it cannot afford downtime. Hence, the reliability and quality of a pump are particularly important. NETZSCH uses advanced testing facilities to ensure all pumps perform satisfactorily before being installed on site. It has dedicated consulting, technical and spare-parts teams to provide the best customised solution for each application. Importantly, too, service and maintenance contracts are proactive, rather than reactive. The company’s global presence, with its extensive distributor network, enables it to provide around-theclock services and ensure that downtime is minimised. Technicians document every aspect to make sure the products are serviced on time. To enhance the cost effective-ness of its pumps, NETZSCH has Frost & Sullivan global vice-president of best automated the practices Jeffrey Frigstad presenting the process to make award to NETZSCH Pumps & Systems standardisation and managing director Felix Kleinert documentation easier.

NOV Mono highlights success of its Universal Parts offering NOV MONO HAS revealed that sales of its range of Universal Parts for progressing cavity (PC) pumps have increased by a margin of 122 per cent over the past nine years. The company’s precision-made Universal Parts have been designed to be suitable for most other brands of PC pumps, with the range containing a variety of components that help keep plants NOV Mono has increased sales of and processes up and running at its Universal Parts offering over the peak efficiency. NOV Mono’s past nine years by 122 per cent Universal Parts range includes precision-engineered parts that fit into most PC p ump brands, and have been thoroughly tested, engineered and manufactured to the highest possible standards. “The dramatic growth in sales has been impressive by any standards,” remarked Simon Lambert, Mono commercial director – UK, Europe, Africa, Middle East and Central Asia. “It also underlines the increasing value that customers place on having quick and reliable access to highquality, proven part s for their PC pumps.” NOV Mono, a division of US-based National Oilwell Varco, comprises a group of companies offering a range of products and services, including progressing cavity pumps, artificial lift systems, industrial mixers, heat exchangers, grinders, screens and aftermarket replacement parts. The company first began manufacturing progressing cavity pumps in 1935 and industrial mixers in 1952, and last year acquired Robbins and Myers. “Customers are increasingly demanding a spares solution that offers quality, reliability and easy availability, and the growing popularity of our Universal Parts range shows that it offers exactly that,” Lambert added. Mono also provides fully-assembled rotating units for certain product ranges, which include a rotor, stator, joint kit, coupling rod, plug-in shaft and mechanical seal or gland packing, removing the requirement for onsite assembly and offering limited installation times.

Cylingas showcases advances in storage terminals at Abu Dhabi event ENOC SUBSIDIARY CYLINGAS used its platform at the second Annual Tanks Management Summit in Abu Dhabi to highlight the latest advances in tank management, which included its selection of centrifugal pumps for terminals. Cylingas, a UAE-based company with 40 years experience in engineering, fabrication and construction, is among the leading providers of EPC services to the industrial and energy sectors, and has plans in place to expand its geographic presence in The Cylingas team at the second Annual Tanks Management Summit in Abu Dhabi key markets throughout the GCC region. At the event in Abu Dhabi, Cylingas engineering manager Jyoti cleaning and maintaining roof tanks, as well as new solutions in Swarup shared experiences of ‘Selecting Centrifugal Pumps’, end-to-end tanks and terminal systems. highlighting the definitions and classifications, performance curve, “As a key player in the sector, Cylingas presented our learnings in affinity laws, specific speed and cavitation, suction energy, viscosity the industry that can help strengthen the operational efficiency of and multi-pump operations, among other topics. our partners and clients.” Cylingas chairman of board, Saif Al Falasi, said, “The second The Abhu Dhabi summit focused on regional challenges and Annual Tanks Management Summit was an important event that opportunities in the maintenance and optimisation of hydrocarbon highlighted international best practices for the storage terminal storage terminals and was attended by oil and gas professionals, sector, and put the spotlight on technological advancements in consultants and contractors.

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 Innovations

Sulzer strengthens presence in Saudi Arabia SULZER HAS SIGNED an agreement to acquire a 75 per cent stake in Saudi Pump Factory with with Nabil Al Hashim, founder of the company, for US$37.5mn and establish local production joint venture Sulzer Saudi Pump Company (SSPC). The pump and valve manufacturing firm is located in Riyadh with a workforce of 170 employees and with achieved sales of approximately US$26.7mn in 2012. According to Sulzer, this acquisition is in line with its focus on the oil and gas, power and water key markets as these are major sectors of Saudi Arabia’s fast growing economy. SSPC will be the first complete manufacturing facility in Saudi Arabia for a global pump manufacturer of API pumps, serving one of the largest oil and gas markets worldwide. The 25,000 square metres facility in Riyadh produces all types of centrifugal pumps to API and ASME standard and will be part of Sulzer’s global manufacturing network, focusing on the oil and gas, power and water markets. This setup will reportedly enable Sulzer to serve its Saudi Arabian and GCC customers from a local base.

The pump and valve manufacturing firm is located in Riyadh

Bowtech Product’s newest addition to LED family SUBSEA VISION SYSTEMS manufacturer Bowtech Products has launched LED-S-Series lamp, which is a smaller, 10,000 lumen ‘baby’ version of 20,000 lumen LED-V-Series underwater floodlight. Having an output of up to 10,000 lumens with a beam angle of 80º in water (narrower angles are available, according to Bowtech Products) the lamp is ideal for illuminating large areas for HD viewing tasks. Manufactured in corrosion-resistant hard anodised aluminium with an acrylic window, the lamp is rated to operate at 6,000 metres ocean depth. The LED-S-Series lamp is now available as either 100-120Vac or 130150Vdc, with a selection of connectors and connector positions available.

Lamprell celebrates successful rig business in 2014 THE OIL AND gas construction and engineering group Lamprell 160 drilling rigs over the next 12 months. It estimates that much of this announced it has experienced strong operational performance this year, demand is expected to be generated by Saudi Aramco and includes having successfully delivered a number of technically-challenging and renewals of some incumbent units. major projects. So far in 2014 Lamprell has delivered two jack-up drilling However, following the record number of rigs ordered in 2013 – which rigs to the National Drilling Company (NDC), the are expected to enter the market over the next 12 NDC 3 ‘Qarnin’ and NDC 4 ‘Marawwah’, as well months – Lamprell has noted a recent softening in as a new self-propelled jack-up vessel, named the rig market. According to a company Lamprell has delivered two jack-up drilling ‘Hydra’, to the offshore vessel provider Seajacks. representative, a significant number of jack-ups rigs to the National Drilling Company this This year has also seen Lamprell complete the are being built to specification in China and old year, including the NDC 4 ‘Marawwah’ largest and one of the most complex rig jack-up drilling units are rarely scrapped; they are conversion and refurbishment projects in the either refurbished or converted for non-drilling company’s history, delivered to its client functions, such as maintenance or Millennium Offshore Services. Among the accommodation units. operational achievements reached on this Whether the market is looking to build new technically-challenging project was a world-class jack-up rigs or convert and upgrade old units, safety record. Furthermore, the UAE-based Lamprell is positioned to benefit from new company has secured two major contract awards projects by leveraging its key strengths, such as from leading drilling firms, Ensco and Shelf its high-build quality, timely delivery, strong safety Drilling. Both deals involve Lamprell constructing record, commitment to reliability, working two LeTourneau 116E jack-up rigs for both collaboratively with clients, skilled workforce and companies, while the contract with Ensco, the its strategically-located facilities. world’s second largest jack-up operator, has the Lamprell has been operating in the Middle East option of constructioning two more. According to since the mid-1970s and for the first two decades Lamprell, signing the deal for the new projects it focused on small offshore energy sector with Ensco is a significant win, as Ensco has projects, ranging from repair and modification of previously concentrated its new building drilling rigs, accommodation modules and land activities in the Far East. camps, to the overhaul of rig machinery. A Lamprell representative said both contracts In the late 1990s, the company diversified into affirm its place among the world’s leading jack-up the new build construction market for the builders and reflect the quality of the build, offshore oil and gas sector and then, later, into efficient production, and safety procedures in the renewable energy sector, constructing selfplace at the company’s fabrication facilities, propelled, self-elevating liftboats and wind farm which are based in the UAE. installation vessels. Over the last seven years, The company explained that the current Middle Lamprell has successfully delivered a total of 22 East jack-up fleet numbers around 148 drilling units new build jack-up rigs, including nine Super 116E and analysts have predicted an increase of up to jackup drilling units.

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RIG COUNT ď&#x192;§

Middle East & North Africa The Baker Hughes Rig Count tracks industry-wide rigs engaged in drilling and related operations, which include drilling, logging, cementing, coring, well testing, waiting on weather, running casing and blowout preventer (BOP) testing.

Country

Land

THIS MONTH OffShore Total

VARIANCE From Last Month

LAST MONTH Land OffShore Total

Land

LAST YEAR OffShore Total

Middle East ABU DHABI DUBAI IRAQ JORDAN KUWAIT OMAN PAKISTAN QATAR SAUDI ARABIA SUDAN SYRIA YEMEN TOTAL

21 0 94 0 34 59 20 2 89 0 0 4 232

9 2 0 0 0 0 0 5 19 0 0 0 35

30 2 94 0 34 59 20 7 108 0 0 4 358

0 1 5 0 0 1 -3 1 10 0 0 0 15

23 0 89 0 34 58 23 2 78 0 0 4 311

7 1 0 0 0 0 0 4 20 0 0 0 32

30 1 89 0 34 58 23 6 98 0 0 4 343

19 0 80 0 30 45 21 2 64 0 0 4 265

8 0 0 0 0 1 0 7 19 0 0 0 35

27 0 80 0 30 46 21 9 83 0 0 4 300

47 45 11 0 103

0 11 1 0 12

47 56 11 0 114

-2 -9 3 0 -8

49 45 8 0 102

0 10 0 0 10

49 65 8 0 122

46 47 15 3 111

0 11 0 1 12

46 58 15 4 123

North Africa ALGERIA EGYPT LIBYA TUNISIA TOTAL

Source: Baker Hughes

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Project Databank Compiled by Data Media Systems

OIL, GAS AND PETROCHEMICAL PROJECTS SAUDI ARABIA Project

Facility

Budget ($ US)

Country

Status

AJOC - KJO - Expansion of Khafji Crude Production Facilities (Hout Field Onshore & Offshore)

Oil Production

Neutral Zone

1,522,000,000

Construction

Kuwait Gulf Oil Company (KGOC) Gas and Condensate Export System

Condensate Refinery

Khafji

2,000,000,000

Construction

Luberef - Lubricants Refinery Expansion

Lube Oil

Yanbu

1,000,000,000

Construction

Maaden - Sabic - Mosaic Waad Al Shamaal Mining City/ Phosphate City Balance Downstream Plant

Petrochemical Plant

Ras Al Khair

500,000,000

EPC ITB

Petro Rabigh Refinery & Aromatics Petrochemical Complex Expansion - Phase 2 (Overview)

Rabigh

5,000,000,000

Construction

Sabic - Mitsubishi Rayon - Lucite International Alpha 2 - Petrochemical (MMA & PMMA) Plants

Dimethyl Ether (DME)

Jubail

5,000,000,000

Construction

Sabic - Oil-to-Chemicals Plant

Oil Production

Yanbu

30,000,000,000

Feasibility Study

Sadara Chemical Company Jubail Integrated Refining & Petrochemicals Project (Overview)

Refinery

Jubail

20,000,000,000

Construction

SAMREF - Yanbu Oil Refinery Revamp Clean Fuels Project (Overview)

Refinery

Yanbu

2,000,000,000

Engineering & Procurement

Saudi Aramco - Arabiyah & Hasbah Offshore Development Program - Gas Processing Plant

Gas Processing

Manifa

1,500,000,000

Construction

Saudi Aramco Expansion of Khurais Oilfield

Oil & Gas Field

Eastern Region

3,000,000,000

EPC ITB

Saudi Aramco Fadhili Gas Plant

Gas Field

Eastern Region

3,000,000,000

EPC ITB

Saudi Aramco Jizan Export Refinery (Overview)

Refinery

Jizan

7,000,000,000

Construction

Saudi Aramco Liquefied Natural Gas (LNG) Receiving Terminal

Liquefied Natural Gas (LNG)

Jeddah

1,000,000,000

Feasibility Study

Saudi Aramco Riyadh Refinery - Clean Transportation Fuel

Isomerisation

Riyadh

2,500,000,000

Engineering & Procurement

Saudi Aramco Safaniyah Oil Field (Phase 2)

Oil & Gas Field

Safaniyah

500,000,000

Feasibility Study

Saudi Aramco Shaybah NGL - Recovery Unit (Overview)

Natural Gas Liquefaction (NGL)

Shaybah

6,000,000,000

Construction

Saudi Aramco Wasit Gas Field Development (Overview)

Gas Field Development

Dammam

6,000,000,000

Construction

Wafra Joint Operations Company Wafra Heavy Oil Field (Overview)

Steam Injection

Neutral Zone

800,000,000

Engineering & Procurement

Yanbu Aramco Sinopec Refining Company (YASREF) Yanbu Export Refinery (Overview)

Refinery

Yanbu

13,000,000,000

Construction

8/12/12 4:14 PM S20 ORME 6 2014 - DMS_Layout 1 19/26/2014 3:11 PM Page 107

Over

projects tracked major in over

".3-20($1 across , ).0 1$"2.01

Customizable Dashboard

Project Overview

Advanced Search

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NEW FEATURES Key Personnel

Market Forecast

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Industry News

8 312.,(7 !+$ 1'!. 0# 8 $11 &(-& ' 0(-& 0.)$"21 ,.-&12 .30 $,!$01 0.3/ 8 20$ , 300$-2 -#31206 $51 '0.3&' .30 1'!. 0# 8 .0$" 12 .#$+1 !6 $ 1(!(+(26 5 0# 2$1 8 .,/ 0$ .-20 "2.0 .0*+. #1 & (-12 "' 2'$0 8 $4$+1 .% $6 $01.--$+ 8 $$/$0 0.)$"2 (- -"(-& 2

Tel: +973 1740 5590 Fax: +973 1740 5591 info@dmsglobal.net www.dmsprojects.net

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Project Focus Compiled by Data Media Systems

Project Summary Project Name

Luberef - Lubricants Refinery Expansion

Name of Client

Saudi Aramco Lubricating Oil Refining Company (Luberef)

Budget ($ US)

1,000,000,000

Award Date

Q4-2012

Facility Type

Lube Oil

Status

Construction

Start Date

Q4-2009

End Date

Q1-2016

Location

Yanbu

Saudi Aramco Lubricating Oil Refining Company (Luberef) plans to expand its lubricants refinery in Yanbu, Madinah. The expansion of the refinery is expected to produce a new type of base oil known as type three, which will be used in high quality car engines. Upon completion, the capacity of oil lubricants will be doubled from 280,000 tonnes per year (tpy) to 560,000 tpy.

Project Status Aug 2014

Foundation works on the building, pipeline, equipment and structure of the main package is ongoing. The construction works are scheduled for completion in the fourth quarter of 2015.

May 2014

Construction works on the Vacuum Distillation Unit (VDU) package has been completed.

Mar 2014

Industry sources within Samsung Engineering have revealed that the construction works are currently 25 per cent complete.

Jan 2014

Construction works are ongoing as per schedule, with completion expected in January 2016.

Project Scope Saudi Aramco Refining Lubricating Company (Luberef) plans to expand its lubricants refinery in Yanbu. The expansion of the refinery would double the existing capacity of oil lubricants from 280,000 tpy to 560,000 tpy. Upon completion, the facility would be able to produce a new type of base oil. The oil produced will be oil of type three, which is used in car engines. The expansion of the lubricants refinery includes the following: - Construction of 23,000 barrel per day (bpd) Lube hydrocracker - Construction of offsites and utilities - Construction of supporting services such as a tank farm and additional storage

Project Finance Luberef was primarily established in 1978 as a 70:30 joint venture between the state owned Saudi Aramco and the US oil major ExxonMobil. In late 2007, however, Jadwa Industrial Investment Company acquired ExxonMobil's 30 per cent interest in the Saudi Aramco Lubricating Oil Refining Company (Luberef) to become the sole partner to Saudi Aramco in Luberef.

Project Schedules 4Q-2009

FEED ITB

4Q-2012

Engineering & Procurement

1Q-2011

FEED

1Q-2016

Completed

2Q-2012

EPC ITB

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‫ﺗﺤﻠﻴــــــﻼت‬ ‫ اﻟﺸﺮق ا وﺳﻂ‬- ‫اﻟﻨﺸﺮة اﻟﻨﻔﻄﻴﺔ‬

‫اﻟﺴﻼﻣﺔ اﻟﺘﺸﻐﻴﻠﻴﺔ واﻟﺘﻐﻠﺐ ﻋﻠﻰ ا ﺧﻄﺎء اﻟﺒﺸﺮﻳﺔ‬ áeÓ°ùdGh áë°üdG äÉLQO π°†aGC ¤GE ∫ƒ°UƒdG §ØædG äÉcô°ûd ôª˘à˘°ùŸG ìÉ˘Ø˘µ˘dG ƒ˘g ,™˘bƒŸG ‘ .§°Sh’ C G ¥ô°ûdG á≤£æe ‘ πª©J »˘à˘dG RÉ˘¨˘dGh ,äÉcô°ûdG ∂∏J É¡¡LGƒJ »àdG äÉjóëàdG »g Éªa ?É¡«∏Y Ö∏¨à∏d √PÉîJG ºàj …òdG Ée ,ájÉ¡ædG ‘h ábÉ£dG πÑ≤à˘°ùe ø˘Y Ωƒ˘«˘dhÎH ¢ûà˘jô˘H ô˘jô`≤˘J ∫ƒ˘≤˘j ó¡°ûj ábÉ£dG ≈∏Y Ö∏£dG ¿GE , ábÉ£dG ∑Ó¡à˘°SG ™˘Ø˘Jô˘j ¿GC Qô˘≤ŸG ø˘e å«˘M ,kÉ˘YÉ˘Ø˘JQG ¿’C Gô¶fh .2035 ∫ƒ∏M ™e áFÉŸG ‘ 41 áÑ°ùæH »ŸÉ©dG π˘ °UGƒ˘ J §˘ °Sh’CG ¥ô˘ °ûdG ‘ á˘ bÉ˘ £˘ ∏˘ d á˘ é˘ à˘ æŸG ∫hó˘ dG êGôîà°S’ ájó«∏≤àdG ÒZ Iójó÷G ¥ô£dG ‘ ÉgQÉªãà°SG ÒaƒJ á«ªgGC ` äÉcô˘°ûdG √ò˘¡˘d á˘Ñ˘°ùæ˘dÉ˘H ` OGOõ˘J ,Oƒ˘bƒ˘dG Éªªa .™bƒŸG ‘ á∏eÉµdG áeÓ°ùdGh áë°ü∏d ádÉ©a á°SÉ«°S Gô˘eGC Èà˘©˘J á˘eÓ˘°ùdGh á˘ë˘°ü∏˘d á˘°SÉ˘«˘°S ¿GC ¬˘«˘a ∂°T ’ ´É£b ‘ á°UÉN á«ªgGC É¡d øµd ,áYÉæ°U …GC ‘ kÉ«¡jóH á«dh’CG äÉYÉæ°üdG äÉ«∏ªY πc ¿’C Gô¶fh .RÉ¨dGh §ØædG πeÉ©àJh ,™°SGh ¥É£f ≈∏Y äÉYhô°ûe Ö∏£àJ á«FÉ¡ædGh ¿ƒµj ób çOGƒ◊G §°ùHGC ¿ÉEa ,Iƒ£ÿG Iójó°T OGƒŸG ™e ∂dòch ,™bƒŸG ‘ Ú∏eÉ©dG OGôaÓ C d Iôeóe äÉ«YGóJ ¬d .á£«ÙG áÄ«Ñ∏d ô˘ ˘Jhh ÖjO{ ô˘ ˘Ø◊G êô˘ ˘H ‘ QÉ˘ ˘é˘ ˘Ø˘ ˘fG ô˘ ˘Ø˘ ˘°SGC ó˘ ˘≤˘ ˘a 11 IÉ˘ah ø˘Y 2010 ΩÉY ∂«˘°ùµŸG è˘«˘∏˘N ‘ z¿hõ˘jGQƒ˘g k ˘eÉ˘Y øe Ö©˘µ˘e Îe ∞˘dGC 780 ‹GƒM Üô˘°ùJ ó˘¡˘°Th ,Ó ióŸG Ió˘«˘©˘H ô˘FÉ˘°ùN ¤GE iOGC É‡ ,ô˘ë˘Ñ˘dG ‘ §˘Ø˘æ˘dG ÈcGC ø˘ e Ió˘ MGh ‘ ∂dPh ,á˘ £˘ «ÙG á˘ jÈdG IÉ˘ «˘ ë˘ ˘∏˘ ˘d IhÓY .IóëàŸG äÉj’ƒdG ïjQÉJ ‘ §ØædG Üô°ùJ äÉ«∏ªY ÒKÉC˘J z¿hõ˘jGQƒ˘g ô˘Jhh ÖjO{ Üô˘°ùà˘d ¿É˘c ,∂dP ≈˘∏˘Y ¢ûJôH{ iód IQÉØ◊G »∏¨°ûe áØ∏µJ ¤GE iOGC ÒÑc ‹Ée .äÉ°†jƒ©àdGh ∞«¶æàdG ‘ äGQ’hódG äGQÉ«∏e zΩƒ«dhÎH øe ºZô˘dG ≈˘∏˘Y ,RÉ˘¨˘dGh §˘Ø˘æ˘dG á˘YÉ˘æ˘°U ‘ çOGƒ◊É˘a äÉ«°ùæ÷G IOó©àe á∏eÉY Iƒb ™e πª©dG óæY ÉC°ûæJ »àdG äÓµ°ûŸG ∑GQOGE äÉcô°ûdG ≈∏Y Öéj ÒKÉCJ É¡d ¿ƒµj ób ,á«dhGC IQƒ°üH IÒ¨°U hóÑJ ób É¡fGC ¤GE á˘aÉ˘°V’EÉ˘Hh .á˘cô˘°û∏˘d …QÉ˘é˘à˘dG •É˘°ûæ˘dG ≈˘∏˘Y ÒÑ˘c QÉéØf’G πãe ;πFÉ¡dG QÉeó˘dGh äÉ˘«˘YGó˘à˘dG Èc’C Ék˘Ñ˘Ñ˘°S äÉ˘«˘∏˘ª˘©˘dG á˘eÓ˘°S çOGƒ˘M ô˘jô˘≤˘J ‘ AÉ˘L ÉŸ É˘≤˘ahh øY É°†jGC èàæj ób ,çOÉ◊G ¬æY ôØ°SGC Ée ìÓ°UGE áØ∏µJ è˘«˘∏˘N ‘ Ωƒ˘«˘dhÎH ¢ûà˘jô˘H ô˘ Ø˘ M êô˘ H ‘ çó˘ M …ò˘ dG OÉ–’G ø˘Y IQOÉ˘°üdG 2012h 2011 ÚeÉ©dG äÉfÉ˘«˘H) QÉ˘©˘°SGC ‘ ´lÉ˘Ø˘JQG á˘eÓ˘°ùdGh á˘ë˘°ü∏˘d á˘Ä˘«˘°ùdG á˘©˘ª˘°ùdG .∂«°ùµŸG çOGƒ◊G ∫ó˘©˘e OGR ,(RÉ˘¨˘dGh §˘Ø˘æ˘dG »˘é˘à˘æŸ ‹hó˘dG .íHôŸG …QÉéàdG •É°ûædG IQÉ°ùN IQƒ£Nh ÚeÉCàdG ‘ çOGƒ◊G GCƒ°SGC ¿ƒµj Ée GÒãc ,»°SÉ°SGC ƒëf ≈∏Yh ‘ 27 áÑ°ùæH ,2012 ‘ É¡H ácQÉ°ûŸG äÉcô°û∏d ,áà«ªŸG á«HhQh’CG ácô°ûdG ¢ù«FQ ÖFÉf ,õæ«Ñ«L …ófGC ìô°Uh OGô˘ a’CG ó˘ M’C ÉC˘ £˘ N ø˘ Y kÉŒÉ˘ f RÉ˘ ¨˘ dGh §˘ Ø˘ æ˘ dG ´É˘ £˘ b ´É˘LQGE ” ,∂dP ≈˘∏˘Y IhÓ˘Yh .»˘°VÉŸG ΩÉ˘©˘dG ø˘Y á˘FÉŸG `d ,§˘°Sh’CG ¥ô˘°ûdG ‘ () á«dhÎÑdG äGQÉ°ûà˘°SÓ˘d ‘ ´ƒ°VƒŸG Gòg ¢VGô©à°SG ” óbh .´hô°ûŸG ‘ Ú∏eÉ©dG çGóMCÉH á≤∏©àe ÜÉÑ°SGC ¤GE á∏eÉ©dG Iƒ≤dG øe 40 IÉah AGOGC ‘ ô¶æJ ÚeÉCJ ácô°T …GC{ :ÓFÉb zá«£ØædG Iô°ûædG{ iƒ˘≤˘dG á˘«˘LÉ˘à˘fGEh á˘«˘∏˘«˘¨˘°ûà˘dG IAÉ˘Ø˘µ˘dG IOÉ˘jR{ ô˘jô˘≤˘à˘dG áeÓ°S çóM ¤GE ô¶ædG ºàj Ée IOÉYh .äÉ«∏ª©dG áeÓ°S º««≤à˘d á˘∏˘«˘°Sƒ˘c á˘eÉ˘©˘dG äÉ˘fÉ˘«˘Ñ˘dG Ωó˘î˘à˘°ùJh äÉ˘cô˘°ûdG Èà˘©˘J √ò˘g π˘g - á˘eÓ˘°ùdG ≈˘∏˘Y ÒKÉC˘à˘dG ¿hó˘H á˘∏˘eÉ˘©˘dG ¿ƒµJh ,Iô£«°ùdG øY êQÉN IOÉŸ çÉ©ÑfG ¬fGC ≈∏Y á«∏ª©dG á˘ë˘°üdG Aƒ˘°S π˘é˘°S …GC) ∂dP ¿GCh É˘¡˘FGOGC IOƒ˘L ió˘e ,äƒ«dGE ∞«à°S √óYCG …òdG z?ájôëÑdG ∫ƒ≤ë∏d (ÉfÉaÒf) äÉ«∏ªY øe ,∫É©à°TÓd á∏HÉb hGC áeÉ°S IOÉe ` IOÉ©dG ‘ ` ‘ hGC ,ÚeCÉàdG •É˘°ùbGC IOÉ˘jR ¬˘æ˘Y è˘à˘æ˘j ó˘b (á˘eÓ˘°ùdGh .zá°ù°SƒDŸG á«£¨J ácô°ûdG ¢†aQ ä’É◊G ¢†©H äÉ˘°ù°SƒDŸG è˘eGô˘H ô˘aƒŸ äÉ˘«˘∏˘ª˘©˘dG á˘eÓ˘°S AGÈN ó˘MGC çGóM’CG √ò˘g π˘ã˘e ¿ƒ˘µ˘J É˘e GÒã˘c Gò˘¡˘d .≥˘aGôŸG ó˘MGC  ‫اﻟــﻌـﺪد اﻟﺴﺎدس‬

S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014 7:44 PM Page 113

S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014     7:44 PM Page 114

‫أﺧﺒــــــــــــــﺎر‬ ‫وﺳﻂ‬#‫ اﻟﺸﺮق ا‬- ‫اﻟﻨﺸﺮة اﻟﻨﻔﻄﻴﺔ‬

ً‫ﻣﺼـــــــﺮ ﺗـﻮﻗـــــﻊ ﻗـــﺮﺿـــﺎ‬ ‫ ﻣﻠﻴـﻮن دوﻻر‬٥٠٠ ‫ﺑﻘﻴﻤـــﺔ‬ ‫ﻣﻊ اﻟﺒﻨﻚ اﻟﺪوﻟﻲ‬

‫اﻟـﻨﻔﻂ اﻟﻌﻤﺎﻧﻴﺔ ﺗﻮﻗﻊ اﺗﻔﺎﻗﻴﺔ ﺗﺴﻬﻴﻞ اﻋﺘﻤﺎد‬ ‫ ﻣﻠﻴﺎر دوﻻر‬١^٨٥ ‫ﻣﺘﺠﺪد ﺑﻘﻴﻤﺔ‬ 1^85 áª«≤H Oóéàe OÉªàYG π«¡°ùJ á«bÉØJG ,á«fÉª©dG §ØædG ácô°T ,á«fÉª©dG ábÉ£dG QÉªãà°SG ácô°T â©bh OÉªàY’G π«¡°ùJ ôaƒàj ,á«bÉØJÓd É≤ahh .á«dhódGh á˘«˘ª˘«˘∏˘b’EGh á˘«˘∏ÙG ∑ƒ˘æ˘Ñ˘dG ø˘e 16 ™e »µ˘jô˘eGC Q’hO QÉ˘«˘∏˘e ºà«°Sh .»µjôeGC Q’hO ¿ƒ«∏e 850 áª«≤H äGƒæ°S 5 π«¡°ùJh ,»µjôeGC Q’hO QÉ«∏e 1 áª«≤H äGƒæ°S 3 IóŸ OóéàŸG .á«fÉª©dG §ØædG ácô°T iód ƒªædG á«é«JGÎ°SG ™e É«°û“ áeÉ©dG ácô°ûdG ¢VGôZ’C OÉªàY’G ΩGóîà°SG á«fÉª©dG §ØædG ácô°T iód âHÉãdG QÉ°ùŸG πé°S ‘ ‹ÉŸG ™ªàÛG á≤K øY È©J á∏eÉ©ŸG √òg ¿GE ácô°ûdG âdÉbh k °†a Gòg ,É¡H á°UÉÿG äÉcô°ûdG áYƒª›h §ØædG ácô°T âeÉb ∂dòc .áæ£∏°ù∏d ô≤à°ùŸGh »eÉædG OÉ°üàb’G øY Ó OÉ–G ™e »µ˘jô˘eGC Q’hO QÉ˘«˘∏˘e 2^8 áª«≤H ¢Vôb ™«bƒàH (∂HQhGC) á«dhÎÑdG äÉYÉ˘æ˘°üdGh ‘É˘°üª˘∏˘d á˘«˘fÉ˘ª˘©˘dG .QÉë°U ‘ É¡H á°UÉÿG IÉØ°üª∏d ™«°SƒJ á£N πª°ûJ äÉYhô°ûe IóY πjƒªàd ∂dPh ,2014 QÉjGC/ƒjÉe ‘ ±QÉ°üe ‘ AÉHô¡µdG äÉcô°T ™«ª÷ á°†HÉ≤dG ácô°ûdG »gh ,AÉHô¡µ∏d á°†HÉ≤dG ácô°ûdG É°†jGC §£îJ ,¬°ùØf âbƒdG ‘h óbÉ©àdÉH âeÉbh ,2015 øe ∫h’CG ∞°üædG ∫ƒ∏ëH äGóæ°S QGó°UGE øe »µjôeGC Q’hO QÉ«∏e 2^1 IOÉjõd ,áæ£∏°ùdG .á«dÉŸG äGQÉ«ÿÉH á°UÉÿG äGQÉ°ûà°S’G É¡d Éeó≤j »µd §≤°ùe ∂æHh ,¿ÉLQƒe »H »L ∂æH ™e

:‫ﻣﻔﻜﺮة رﺟﺎل ا ﻋﻤﺎل‬

‫ أﺑﻮﻇﺒﻲ‬.................................................................................. ‫ ﻣﺆﺗﻤﺮ “أوﺑﻴﺘﻮ” ﻟﻠﺴﻼﻣﺔ واﻟﻜﻔﺎءة‬............ ‫ ﻧﻮﻓﻤﺒﺮ‬٤ ‫ أﺑﻮﻇﺒﻲ‬.............٢٠١٤ ‫ ﻣﺆﺗﻤـﺮ وﻣﻌﺮض أﺑﻮﻇﺒـﻲ اﻟــﺪوﻟـﻲ ﻟﻠﺒﺘــﺮول ـ أدﻳﺒـﻚ‬............. ١٣ ‫ ـ‬١٠ ‫ دﺑﻲ‬................................................................................. ‫ ﻣﻠﺘﻘﻰ اﻟﻤﻮارد اﻟﺒﺸﺮﻳﺔ ﻟﻠﻨﻔﻂ واﻟﻐﺎز‬............. ٢٥ ‫ ـ‬٢٣ ‫ اﻟﺪﻣﺎم‬.................................... ٢٠١٤  ‫ اﻟﻤﻌﺮض اﻟﺴﻌﻮدي ﻟﻠﻨﻔﻂ واﻟﻐﺎز ـ‬............. ٢٦ ‫ ـ‬٢٤

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»µjôeGC Q’hO ¿ƒ«∏e 500 áª«≤H Ék°Vôb ô°üe â©bh ‘ ∫RÉæª∏d »©«Ñ£dG RÉ¨dG Òaƒàd ‹hódG ∂æÑdG ™e .ô°üe ‘ ‹hó˘dG ¿hÉ˘©˘à˘dG Iô˘jRh ,ÊGƒ˘g’EG AÓ‚ âdÉ˘bh á˘£˘N π˘jƒ“ ≈˘∏˘Y ¢Vô˘≤˘dG ó˘YÉ˘°ùj ±ƒ˘°S{ :ô˘ °üe á°UÉîHh ,∫õæe ∞dGC 850 π«°UƒJ ‘ ∫hÎÑdG IQGRh RÉ˘ ¨˘ dG á˘ µ˘ Ñ˘ °ûH ,ó˘ «˘ ©˘ °üdÉ˘ H á˘ «˘ Ø˘ jô˘ dG ≥˘ WÉ˘ ˘æŸG ‘ ô°üe Ωƒ≤J ±ƒ°S ,IQGRƒdG ¿É«Ñd É˘≤˘ahh .z»˘©˘«˘Ñ˘£˘dG 30 QGóe ≈∏Y ‹hódG ∂æÑdG ¤GE ¢Vô≤dG áª«b OôH .ΩGƒYGC á°ùªN IóŸ ìÉª°S IÎa ™e ,ÉeÉY øª«dGh ô°üŸ »ª«∏b’EG ôjóŸG ,ôaÉ°T è«ØJQÉg ∫Ébh RÉ¨dG ¤GE ∫ƒëà˘dG ¿GE{ :‹hó˘dG ∂æ˘Ñ˘dG ‘ »˘Jƒ˘Ñ˘«˘Lh OGóeGE ≈∏Y ∫ƒ°ü◊G ‘ ∫RÉæŸG óYÉ°ù«°S »©«Ñ£dG ¬«∏Y OÉªàY’G øµÁh ,o Gô˘©˘°S π˘bGCh Ék˘fÉ˘eGC ÌcGC RÉ˘¨˘∏˘d .z∫É°ùŸG RÉ˘¨˘dG Ö«˘HÉ˘fGC AGô˘°ûH á˘fQÉ˘≤˘e ,ÈcGC π˘µ˘°ûH 25 ô°üe ‘ ‹hódG ∂æÑ∏d á«dÉ◊G á¶ØÙG πª°ûJh Q’hO QÉ˘«˘∏˘e 4^9 á˘ª˘«˘≤˘H ó˘¡˘©˘J ‹É˘ª˘LÉE˘H É˘Yhô˘°ûe .»µjôeGC

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‫ﺗﺸﺮﻳﻦ ا ول‬/‫أﻛﺘﻮﺑﺮ‬

‫ أﻣﺴﺘﺮدام‬............................................................................................................ ‫وﻓﺸﻮر‬#‫ ﻣﻌﺮض ﻃﺎﻗﺔ ا‬............٢٩ ‫ ـ‬٢٨

‫ﻛﺎﻧﻮن ا ول‬/‫دﻳﺴﻤﺒﺮ‬

‫ اﻟﺒﺼﺮة‬............................................................................................................................. ‫ ﻣﻌﺮض اﻟﺒﺼﺮة ﻟﻠﻨﻔﻂ واﻟﻐﺎز‬.............٧ ‫ ـ‬٤

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‫ دﺑﻲ‬................................................................................................... ‫وﺳﻂ ﻟﻠﻨﻔﻂ اﻟﺨﺎم‬#‫ ﻗﻤﺔ اﻟﺸﺮق ا‬.............١٠ ‫ ـ‬٨

‫ اﻟﺠﺒﻴﻞ‬......................... ‫ﺳﺎﺳﻴﺔ‬#‫ اﻻﺟﺘﻤﺎع اﻟﺘﻘﻨﻲ ﻟﻠﺸﺮﻛﺔ اﻟﺴﻌﻮدﻳﺔ ﻟﻠﺼﻨﺎﻋﺎت ا‬............٥ ‫ ـ‬٣

 ‫اﻟــﻌـﺪد اﻟﺴﺎدس‬

‫ﺗﺸﺮﻳﻦ اﻟﺜﺎﻧﻲ‬/‫ﻧﻮﻓﻤﺒﺮ‬

S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014 7:44 PM Page 115

S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014 7:44 PM Page 116

CELEBR RATING 5 YEARS OF OFG G

TTH H OCTT 30 HU Bringing industry leaders toge ether for 5 years. The leading Oil & Gas networking event. We are honoured to invite you to o celebrate the 5th anniversaryy of OFG, which promises to be the best yet! The monthly networking event e takes place at Ruth’s ’s Chris Steak House, Dubai Marina. McDermott Mc ott, a llea eadin ding g EP EPC CI co company focus cuse ed o on n exec ecut utting ting com ompl ple ex off ffsh sho ore oi oil and d gas projectts worldwide, hosts the 52nd edition of OFG.

TTo o find out more about OFG and how to register please email ofg@ru uthschris.ae or call +971 50 709 1533

c d e r m ott



S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014    7:44 PM Page 117

‫أﺧﺒــــــــــــــﺎر‬ ‫ اﻟﺸﺮق ا وﺳﻂ‬- ‫اﻟﻨﺸﺮة اﻟﻨﻔﻄﻴﺔ‬

‫زﻳﺎدة اﻧﺨﻔﺎض أﺳﻌﺎر اﻟﻨﻔﻂ إزاء ﺗﻮاﻓﺮ ا"ﻣﺪادات وﺑﻂء زﻳﺎدة اﻟﻄﻠﺐ‬ Ék°VÉØîfG äó¡°T ób §ØædG QÉ©°SGC ¿GC ábÉ£∏d á«dhódG ádÉcƒ∏d …ô¡°T ôjô≤J ôNGB ôcP ≈˘∏˘Y ÊÉ˘ã˘dG ô˘¡˘°û∏˘d ¢VÉ˘Ø˘î˘f’G Gò˘g çó˘M ó˘bh .ÜGB/¢ù£˘°ùZGC ô˘¡˘°T ∫Ó˘N k GOÉ˘M .Ö∏£dG ≈∏˘Y IOÉ˘jõ˘dG A§˘H ™˘e ,ΩÉÿG §˘Ø˘æ˘dG ø˘e äGOGó˘e’EG Iô˘ah ÖÑ˘°ùH ‹Gƒ˘à˘dG ÌcGC §ØædG π©L É‡ ,§¨°†dG øe k Gójõe ` …ƒ≤dG ` »µjôe’CG Q’hódG ±É°VGC ∂dòc º¡°SGC â°†ØîfG ,∫ƒ∏jGC/ÈªàÑ°S øe øeÉãdG »Øa .iôNGC äÓª©H øjÎ°ûª∏d AÓZ ¤h’CG Iôª∏d π«eÈ∏d »µjôeGC Q’hO 100 øe πbGC ¤GE  ácô°ûd á«∏Ñ≤à°ùŸG âfôH QGôªà°SGh Oƒ©°üdG ‘ IóëàŸG äÉj’ƒdG êÉàfGE á∏°UGƒe ™e ∂dPh ,ΩÉY ÌcGC ióe ≈∏Y ¿ƒ«∏e 30 ƒgh É¡H ¢UÉÿG »ª°SôdG ¢Vô©dG ±óg øe ≈∏Y’C ∂Hh’CG áª¶æe êÉàfGE äÉYGô°üdG áFó¡J ¤GE Ò°ûJ äÉeÓY ájGC Qƒ¡X ΩóY øe ºZôdG ≈∏Yh .É«eƒj π«eôH â∏Xh ,kÉfRGƒàe ¿Éc »ŸÉ©dG §ØædG ¥ƒ°S ≈∏Y ÉgÒKÉCJ ¿ÉEa ,É«Ñ«dh ¥Gô©dG ‘ áÑ°TÉædG ÒZ .ôFGódG ∞æ©dG øe ºZôdG ≈∏Y Ék°TÉ©àfG ó¡°ûJ É«Ñ«d äGQOÉ°üa .áæcÉ°S QÉ©°S’CG ÊÉãd k GÒÑc ÉkØbƒJ ÒãJ ±ƒ°S ¥Gô©dG ∫Éª°T âMÉàLG »àdG á«eÓ°S’EG äÉ«°û«∏«ŸG ¿GC ô¡°T ∫ÓN ,∂Hh’CG áª˘¶˘æ˘e êÉ˘à˘fGE ¢†Ø˘î˘fG ó˘bh Gò˘g .∂Hh’CG á˘ª˘¶˘æÃ è˘à˘æ˘e ÈcGC ¢VÉØîfG ¤GE ∂dP ‘ ÖÑ°ùdG ™Lôjh ,Rƒ“/ƒ«dƒj ô¡°T ‘ ÉªY kÓ«∏b ÜGB/¢ù£°ùZGC áØ°üH …Oƒ©°ùdG OGóe’EG ‘ ,ÒN’CG ¢VÉØîf’G ¢ùµ©jh .»bGô©dGh …Oƒ©°ùdG êÉàf’EG Ö∏£dG ∂dòch á«µjôe’CG ôjôµàdG πeÉ©e øe äGOQGƒdG ≈∏Y Ö∏£dG ¢VÉØîfG ,á°UÉN

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‫اﻟـﻜـﻮﻳــﺖ ﻟـﻠﻄــﺎﻗــﺔ ودراﺟـﻮن أوﻳﻞ‬ ‫ﺗﻜﺘﺸﻔﺎن اﻟﻨﻔﻂ ﻓﻲ ﺑﺌﺮ ﻋﺮاﻗﻲ‬

 

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       S21 ORME 6 2014 Arabic Contents_Layout 1 9/26/2014 3:39 PM Page 118

‫اﻟﺸـــــــﺮق ا وﺳــــــﻂ‬

‫ﺗ ُﻌﻨﻰ ﺑﺎﻟﻨﻔﻂ واﻟﻐﺎز وﻣﻌﺎﻟﺠﺔ اﻟﻬﻴﺪروﻛﺮﺑﻮن‬

‫اﻟﻘﺴﻢ اﻟﻌﺮﺑﻲ‬ ‫أﺧﺒــﺎر‬ Ö∏£dG IOÉjR A§Hh äGOGóe’EG ôaGƒJ AGRGE §ØædG QÉ©°SGC ¢VÉØîfG IOÉjR »bGôY π≤M ‘ §ØædG ¿ÉØ°ûàµJ πjhGC ¿ƒLGQOh ábÉ£∏d âjƒµdG ‹hódG ∂æÑdG ™e Q’hO ¿ƒ«∏e 500 áª«≤H kÉ°Vôb ™bƒJ ô°üe Q’hO QÉ«∏e 1^85 áª«≤H Oóéàe OÉªàYG π«¡°ùJ á«bÉØJG ™bƒJ á«fÉª©dG §ØædG

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‫ﺗﺤﻠﻴﻼت‬ ájô°ûÑdG AÉ£N’CG ≈∏Y Ö∏¨àdGh á«∏«¨°ûàdG áeÓ°ùdG

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‫ﻧﺠﻠﻴﺰي‬#‫ﻣﻠﺨﺺ ﻣﺤﺘﻮﻳﺎت اﻟﻘﺴﻢ ا‬

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.‫ اﻟﻐﺎز اﻟﻄﺒﻴﻌﻲ اﻟﻤﺴﺎل‬،‫ اﻟﻤﻤﻠﻜﺔ اﻟﻌﺮﺑﻴﺔ اﻟﺴﻌﻮدﻳﺔ وأراﻣﻜﻮ اﻟﺴﻌﻮدﻳﺔ‬:‫ﺗﻘﺎرﻳﺮ ﺧﺎﺻﺔ‬ ......................................................................................................................................................................................................................................................................................................................................................

.‫ اﻻﺳﺘﺨﺮاج اﻟﻤﻌﺰز ﻟﻠﻨﻔﻂ‬،‫ اﻟﺼﺤﺔ واﻟﺴﻼﻣﺔ واﻟﺒﻴﺌﺔ‬،‫ اﻟﺘﻮﻇﻴﻒ واﻻﺣﺘﻔﺎظ ﺑﺎﻟﻌﺎﻣﻠﻴﻦ‬:‫اﺳﺘﻄﻼﻋﺎت‬ ......................................................................................................................................................................................................................................................................................................................................................

.‫ أﺗﻤﺘﺔ اﻟﻌﻤﻠﻴﺎت‬،‫ اﻟﺼﻤﺎﻣﺎت‬،‫ ﺗﺠﺪﻳﺪ أﺑﺮاج اﻟﺤﻔﺮ‬،‫ اﻟﻤﻜﺜﻔﺎت‬:‫ﺗﻜﻨﻮﻟﻮﺟﻴﺎ‬ ......................................................................................................................................................................................................................................................................................................................................................

.‫ ﺣﻘﻮل اﻟﻨﻔﻂ اﻟﺮﻗﻤﻴﺔ‬:‫اﻻﺗﺼﺎﻻت وﺗﻜﻨﻮﻟﻮﺟﻴﺎ اﻟﻤﻌﻠﻮﻣﺎت‬

ADVERTISERS INDEX Company ......................................Page ABB Automation L.L.C. ............................105 ABCO Middle East FZE ..............................46 AES Arabia Ltd. ............................................53 Al Khorayef Group ......................................27 ALAA Industrial Equipment Factory ......78 Alcatraz Interlocks BV................................69 All World Exhibitions................................110 AlMansoori Specialized Engineering ....71 Ansell Healthcare-Middle East................23 Aveva Solutions Limited............................57 BAPCO ............................................................17 Bauer Kompressoren GCC FZE ................31 BGH Edelstahlwerke GmbH......................59 Bredero Shaw Middle East Ltd.................13 CGG Services (SA) UAE ..............................81 CompAir Middle East ..............................119 Derrick Services (UK) Ltd. (DSL) ..............63 Dialight............................................................33 DMG World Media Dubai Ltd. (ADIPEC 2014) ........................................103 DMI International ........................................87 DMS Global WLL........................................107 Dresser Al Rushaid Valve & Instr. Co. Ltd. ..........................................32 Emerson Process Management ................7 Euroblast Middle East L.L.C.......................74 Europoles Middle East L.L.C. ....................91 Expotim International Fair Org. Inc (Basra Oil & Gas) ......................99 Ferguson Group Ltd.....................................87

Geyad for Industry and Contracting Co. Ltd...................................56 Global Pipe Company ................................43 Haimo International FZE............................91 Hart BV............................................................68 Hempel Paints Bahrain ..............................73 Hi-Force Ltd. ..................................................25 Hydratight Ltd. ..............................................33 IFP Training & Consulting Middle East SPC........................................55 Inmarco Industries FZC..............................82 Inova Geophysical Equipment Limited ..................................97 International Exhibition Services SRL (SAOGE 2014) ..........................................115 JESCO (Jubail Energy Services Co.) ........29 Jotun Paints UAE Ltd. (L.L.C.) ......................5 Kaeser Kompressoren FZE ........................75 Kohler Power Systems ..............................65 Lamprell Energy Limited............................19 LISEGA Arabia Ltd. Co.................................39 MABI AG ........................................................89 Magnetrol International N.V.....................37 Marelli Motori SPA ......................................79 Marine Services Co. Ltd. ............................87 Metscco Heavy Steel Industries Co. Ltd. ....................................35 National Pipe Co. Ltd. ................................86 Nexans ............................................................21 OKI Europe Limited ....................................77 Oman Cement Company ..........................93

Parker Middle East FZE..............................95 Raccortubi Middle East FZE......................61 Reed Exhibitions FZ L.L.C. (WFES 2015) ............................................113 Ruth's Chris Steak House (Fine Dining Ltd.) ....................................116 SABIC ..............................................................49 Sabin Metal Corporation............................47 Saga PCE Pte Ltd. ........................................45 Saudi Leather Industries Company Ltd. ............................................67 Saudi Power Transformers Company (SPTC)......................................101 Schlumberger Oilfield Mktg Comms........2 Schlumberger Technical Services Inc....11 Shree Steel Overseas FZCO ......................76 Spina Group Srl ............................................50 Starlink Oilfield Supplies & Services DMCC ........................................9 Sulzer Pumps Middle East ........................58 Suraj Limited ................................................51 T.D. Williamson, Inc. ................................109 Top Oilfield Industries Ltd. FZC..................9 Tratos Cavi S.p.A. ......................................117 UL ME FZCO ..................................................41 Unique Maritime Group FZC ....................48 VF Imagewear ..............................................83 VingCard Elsafe (Dubai)..............................60 Ward Leonard Electric Company, Inc.....85 Western Well Tools ....................................55

S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014 7:44 PM Page 119

‫‪S21 ORME 6 2014 - Arabic_Layout 1 9/25/2014 7:44 PM Page 120‬‬

‫اﻟـــــــﻮﺻﻮل إ‪ 8‬أﻓﻀﻞ درﺟــــــﺎت‬ ‫اﻟﺼﺤــﺔ واﻟﺴﻼﻣـﺔ ‪ 7‬اﳌﻮﻗـﻊ‬ ‫ﻫـﻮ اﻟـﻜـﻔﺎح اﳌﺴﺘﻤﺮ ﻟﺸﺮﻛﺎت‬ ‫اﻟﻨﻔﻂ واﻟﻐﺎز‪.‬‬ ‫ﻫﺬا ﺑﺎ&ﺿﺎﻓﺔ إ‪ 8‬آﺧﺮ ا ﺧﺒﺎر ﻋﻦ‬ ‫ﻗﻄﺎع اﻟﻨﻔﻂ واﻟﻐﺎز ‪ 7‬ﻣﻨﻄﻘﺔ‬ ‫اﻟﺸﺮق ا وﺳﻂ‪.‬‬