Oil Review Middle East issue 4 2012 by Alain Charles Publishing

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Vol 15 Issue Four 2012

Oil Review Middle East - Volume 15 - Issue Four 2012

UK ÂŁ10, USA $16.50

PDO to invest heavily in EOR Sudan seesaws as dispute continues The unstoppable rise of natural gas Extending field life Utilising lubricants to reduce downtime

Qatar - business is booming for the king of gas

Improved measurement technologies for LNG How information management puts you in control of operational success

See us at the show

www.oilreview.me

One of the worldâ&#x20AC;&#x2122;s largest oilfield service groups, Petrofac has carved out a special niche for itself in the Middle East. See page 46.

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Vol 15 Issue Four 2012

Contents UK £10, USA $16.50

PDO to invest heavily in EOR Sudan seesaws as dispute continues The unstoppable rise of natural gas

Columns

Extending field life Utilising lubricants to reduce downtime

News

Qatar - business is booming for the king of gas

Improved measurement technologies for LNG How information management puts you in control of operational success

Analysis

See us at the show

Sudan Recent fighting has damaged oil facilities in the south. What does the future hold?

Profile

One of the world’s largest oilfield service groups, Petrofac has carved out a special niche for itself in the Middle East. See page 46.

German oil and gas company Wintershall is looking to expand in the Middle East.

ars

Qatar’s gas sector holds the key to the state’s future development. Image courtesy of Qatar Petroleum

Exploration & Production 20

Developments The latest exploration and production news from around the region.

Editor’s note

Gas 28

Analysis BP’s latest Energy Outlook report forecasts future energy trends up to 2030 and highlights the growth of natural gas.

News The latest project and contract news from the regional gas sector.

Petrochemicals 36

Interview

Sanjeev Sisaudia, CEO of Gulf Petrochem Group discusses the company’s expansion plans for its refining business, and much more.

Exhibitions and Conferences 40

SPE POCE

Meeting global energy demand is the secondary theme for this year’s SPE Production & Operations conference/exhibition in Qatar.

Middle East Petrotech

l na gio re ctor e th s se 7 9 ing ga 19 rv & Se oil nce si

Established in 1996, Middle East Petrotech attracts thousands of visitors. All aspects of refining and related activities are being addressed this year.

Profiles

FOUNDED BY QATAR Petroleum, the multipurpose development of Ras Laffan Industrial City is already renowned as the world’s largest concentration of industries and services based on natural gas. It sits almost on top of the North Field, the single largest non-associated gasfield anywhere. Two huge LNG producers, Qatargas and RasGas, are located sideby-side adjacent to the world’s busiest LNG exporting port. Shipping-related engineering and services businesses are proliferating. And light industry facilities in the neat surrounding township are growing fast, too. Behind the City’s ambitious development plans lies a 20-year Master Plan which involves a complete overhaul of the already modern port facilities and all necessary support services. A moratorium continues in place on future development of gas exploitation, which means no more LNG trains are expected to be announced at present, but debottlenecking is proceeding actively at some of the older trains to increase export capacity even further as global demand increases – and Qatar’s reputation for reliability does the same. With further LNG developments on hold because of the North Field moratorium and the GTL industry getting close to capacity output, Ras Laffan’s gas-based industries are now reaching a plateau, and the focus ahead of 2022 is shifting towards further infrastructure development, services and a range of completely new support industries.

Petrofac

One of the world’s largest oilfield service groups, Petrofac has carved out a niche for itself in the region.

Qatar Petroleum

Measurement Technologies

Profile

After breaking LNG records in recent years, Qatar Petroleum continues to expand.

Ras Laffan Business is booming in the world’s largest cluster of gas-related activities.

Technical Focus 60

Innovations Introducing some of the latest available technologies for the oil and gas sector.

Lubricants

The importance of lubricants in the oil and gas sector should not be underestimated, particularly as they reduce valuable downtime.

Extending Field Life

A novel power generation technology from Maersk Oil could provide new solutions for enhanced oil recovery and unlocking stranded gas fields.

The measurement of LNG volume in ships’ tanks requires great accuraxcy.

Dr Amer Tarraf, managing director of sensor specialist Baumer Middle East FZE, outlines the company’s regional aspirations.

Information Technology 79

Data Management

Dirk Drozd, senior VP of Aveva Middle East, explains how information management puts you in control of operational success.

Arabic Section 4 10

Exploration & Production Analysis

Managing Editor: David Clancy Editorial and Design team: Bob Adams, Andrew Croft, Prabhu Dev, Immanuel Devadoss, Ranganath GS, Prashant AP, Genaro Santos, Zsa Tebbit, Nicky Valsamakis and Julian Walker

Publisher: Nick Fordham

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Production: Donatella Moranelli, Nasima Osman, Nick Salt, Jeremy Walters and Sophia White Email: production@alaincharles.com Subscriptions: Email: circulation@alaincharles.com Chairman: Derek Fordham Printed by: Emirates Printing Press, Dubai © Oil Review Middle East ISSN: 1464-9314

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Oil Review Middle East Issue Four 2012 3

News

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RAK Petroleum reports 2011 profit

HB Rentals awarded three regional deals

RAK PETROLEUM HAS announced full year net profit for 2011 of US$4.27mn, making it the third consecutive year that the UAE company has been profitable. “During 2012, the company has entered a new phase with our transformation into an energy investment company with exposure to 17 licenses in seven countries across the Middle East-North Africa region,” Bijan Mossavar-Rahmani, chairman of the board of directors and chief executive officer of RAK Petroleum, said in a statement. Following the merger of RAK Petroleum’s operating subsidiaries into DNO. RAK Petroleum now assumes a proportionate share of DNO’s profit and loss in its own financial results. Taking into account the company’s 30 per cent share of DNO International’s profit in 2011 of US$35mn, RAK Bijan Mossavar-Rahmani Petroleum’s net profit from operations was US$55.5mn.

HB RENTALS HAS signed three new deals in the Middle East worth over US$1mn in 2012. Michael Bradley, director of sales and business development at HB Rentals said: “The new contract wins are testament to our growing success across the GCC and the Middle East since establishing our presence here just over a year ago. We are delighted to have won such significant contracts.” Hercules Offshore awarded HB Rentals a six to 12-month contract for its Amber Jack self-propelled jack-up barge. The deal will see the company provide four, eight-man accommodation modules including service provision from installation to power generation and sewerage system. The second new contract award is from Abu Dhabi-based National Petroleum Construction Company (NPCC) and comprises a six-month rental agreement for four accommodation modules including modular stairways and walkways. The final contract was awarded by MacDermott International. The scope of the contract includes accommodation modules, toilets, offices for use as an emergency overnight shelter for the carousel deck of a barge currently moored in Dubai and will be working in Saudi Arabia. “Our focus moving forward will be continuing to deliver outstanding quality of product as well as service to our customers, ensuring that we remain the accommodation specialists of choice in the region. We are confident that the year ahead will hold a continued stream of business opportunities and we look forward to announcing further deals in the months to come,” Bradley added.

Kuwait Energy agrees investment deal

Oil exports from Iraqi Kurdistan halted

KUWAIT ENERGY HAS signed an investment agreement with private equity manager Abraaj Capital that will see a private equity fund used to make strategic investments in the Kuwaiti oil company. Abraaj Capital’s investment, through its APEF IV fund, will enable Kuwait Energy’s ongoing growth and development plans and facilitate its emergence as a regional independent exploration and production (E&P) company. Commenting on the transaction, senior partner and co-head of large cap private Eequity, Abraaj Capital, Ahmed Badreldin, said: “The growing E&P sector presents unique opportunities in the MENA region and the potential of independent sector champions such as Kuwait Energy has not been fully exploited. Through this investment, Abraaj Capital will support Kuwait Energy’s growth and expansion.” Executive chairman, Kuwait Energy, Dr Mansour Aboukhamseen commented on the deal, "Through this new partnership with Abraaj Capital, we will be strongly positioned to realise our growth plans, which we are confident, will help us emerge as the leading independent E&P company in the region.” Kuwait Energy currently has a diverse portfolio of oil and gas assets across production, development and exploration phases, with regional operations in Egypt, Iraq, Yemen andOIL Oman. The ME company is also focused exploration, 523_AGG REVIEW AD_(AW) ol.ai 1 on 1/26/12 1:17 PM production and development of oil and gas reserves in Ukraine and Russia.

THE KURDISTAN REGIONAL Government (KRG) has halted oil exports from the start of April claiming that the central government in Baghdad had not made payments to companies working in Northern Iraq since May 2011. In a statement the Ministry of Natural Resources (MNR) said: “After consultation with the producing companies, the Ministry has reluctantly decided to halt exports until further notice. There have been no Tensions in Iraq are rising payments for 10 months, nor any indication from federal authorities that payments are forthcoming.” The MNR added that production will be diverted to the local market for processing and refining to generate an alternative source of cash flow for the producing companies. “Once this non-payment situation has been resolved we will do our utmost to increase exports above the target of 175,000 bpd included in the 2012 Iraq budget," the ministry added.

4 Oil Review Middle East Issue Four 2012

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News

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Schlumberger sees strong growth in oilfield services SCHLUMBERGER REPORTED A rise in its Q1 profit of US$1.3 billion, a 38 per cent increase from US$944 million last year The quarterly results benefited from strong growth in oilfield services in the Gulf of Mexico, North Africa and the Middle East, in response to climbing crude prices. Schlumberger CEO Paal Kibsgaard said in a company statement: "Our firstquarter results showed good progress driven by global exploration and deepwater activity, underpinned by strong execution and operational excellence." Oilfield services segment revenue was US$9.9 billion, a 22 per cent increase year-on-year boosted by strong double-digit revenue growth in all three sections of reservoir characterisation, drilling as well as production. Schlumberger's sales fell to US$10.61 billion from US10.97 billion a year ago which can be considered as 'normal seasonal drop' but its distribution revenue increased four per cent sequentially and 19 per cent year-on-year to hit US$713mn, helping it sustain its international margins. The company's WesternGeco business contributed significantly to the increase. Schlumberger's performance in international markets remained strong, held up by high oil prices in the quarter. Its drilling rigs outside the US and Canada during the quarter increased 1.2 per cent to 1,189 and with the company believing the drilling activity to remain robust, is expected to climb more than 10 per cent this year, Looking ahead, the oilfield service provider said, "Oil demand in 2012 appears to have stabilised, and supply continues to be limited by weak nonOPEC performance and narrow spare capacity margins. These effects should limit any oil-price decline."

Iraq expands Basra oil terminal IRAQ HAS OPENED a second single-point mooring system (SPM) off the coast of Basra that expands the oil terminal’s exporting capacity by a further 900,000 bpd, an official said. The head of the South Oil Company (SOC), Dhia Jaffar, said in a statement that the first oil tanker berthed at the new SPM and began loading crude oil in mid-April. The second SPM raises capacity at the Basra oil terminal, Khor al-Amaya, to 3.6 million bpd but neither of the two SPMs is expected to be running at full capacity in the immediate future. Iraq is aiming to build five SPMs at its southern ports to expand export capacity ultimately to 8mn bpd. A first SPM was completed in early March helping to boost exports to 2.31mn bpd for March, the highest since 1990. The extra port capacity is allowing Iraq to sell more of its increasing oil output. Iraq said its southern exports averaged 1.92mn bpd in March.

Iraq’s Khawr Al Amaya oil platform

India to import more oil and gas from Qatar

PDO to invest heavily in EOR projects

INDIA IS LOOKING to increase imports of crude oil and liquefied natural gas (LNG) from Qatar in the future, according to the country’s oil minister. Jaipal Reddy, oil minister of India, was quoted by Dow Jones as saying: “India imported 5.6mn [metric] tonnes of oil from Qatar in 2010-11 (fiscal year). In the years ahead, with our energy requirements growing, we will look for larger quantities of LNG, crude oil and LPG.” Reddy added that India had not specified yet the amount of extra supplies Petronet currently imports 7.5mn of LNG from Qatar that would be needed. “Qatar has been our trusted, friendly supplier, so we are seeking more supplies.” The report quoted Dr Mohamed bin Saleh al-Sada, minister of energy and industry of Qatar, as saying that Qatar was indeed “reviewing” its commitment on energy supplies to India. “We would like to continue and widen our relations.” Petronet LNG, India’s main LNG importer by volume, recently stated that it was seeking additional LNG supplies from Ras Gas. A K Balyan, managing director of Petronet, said the company was talking to Qatar about getting an additional 2-3mn tonnes a year. The company currently imports 7.5mn tonnes of LNG from Ras Gas under a long-term supply contract that was originally signed in 1999 and amended in 2006.

PETROLEUM DEVELOPMENT OMAN (PDO) has said it will invest US$20 billion over the next five years and continue its focus on Enhanced Oil Recovery (EOR) projects. PDO will embark on a five-year investment programme that will see US$4 billion invested each year in number of oil and gas projects, which includes its EOR activity. Speaking at the OGWA conference in Muscat, PDO managing director Raoul Restucci said, “Oman had entered a new stage of unconventional gas and tight oil exploration.” Restucci explained that EOR was a very important part of PDO’s operations and that company had become a global leader in EOR processes, having focusing on it much earlier than other NOCs. Restucci stated that PDO’s portfolio included “three EOR projects – Harweel, Qarn Alam and Marmul already completed and on production.” “There will be more and more EOR production as we go forward,” he remarked. A big part of EOR is a focus on introducing new technologies. Thanks to the introduction of polymer flooding at its Marmul reservoir over the last two years PDO has seen production hit new levels and in 2011 Marmul’s production was the highest it has ever been in its 30 year history. Next year PDO will commission the Al Amal steam project, which will produce 20,000 bpd, and Al Khalata as a pilot project in the second half of 2014. According to Restucci, EOR projects are capable of producing ‘incredible volumes’. The economics remain most attractive and all PDO EOR projects continue to pass stringent investments tests at very low prices to ensure robustness and sustainability. Oil production from EOR was 3.5 per cent of PDO’s total production in 2011 and should reach 25 per cent by 2012. It will account for 33 per cent of the NOC’s total production by 2025. “It is a very exciting and challenging time for Oman’s oil and gas scene,” Restucci concluded.

6 Oil Review Middle East Issue Four 2012

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News

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Exxon excluded from Iraq’s next oil auction

AlMansoori hosts oilfield open day

IRAQ RELEASED ITS official list of approved bidders for the fourth round of auctions for Iraqi oil fields and excluded oil giant ExxonMobil from the list. The auction is scheduled for May and 47 companies have been approved, including UAE investment fund Mubadala and Dragon Oil, a rapidly expanding oil explorer majority-controlled by Dubai’s ENOC. The reason for the barring of ExxonMobil was because of an earlier oil deal it agreed with the Kurdish regional government (KRG) which angered officials from the central government in Baghdad who maintain that all oil contracts must be approved by the oil ministry The government called on Exxon to cancel its deal with the KRG completely but Exxon announced in March that it had only frozen the agreement. The Petroleum Contracts and Licensing Directorate (PCLD) said in a statement that Iraq was offering 12 large exploration blocks of an average size of 6,500 sq-km for bidding. Winning companies, or consortia of companies, will carry out exploration, appraisal, development and production activities within the 12 Contract Areas. “We are looking forward to welcoming all participating companies in Baghdad. The fourth licensing round will be conducted in a transparent and public manner and according to the same procedures as the first three rounds,” said Abdul Mahdy Al-Ameedi, director general of the PCLD. For the next licensing auction, Baghdad insists on offering service contracts that pay companies a fixed fee for the amount of oil they produce. The fourth oil and gas bid round has been delayed twice before and is expected to add some 10 billion barrels of oil and some 29 trillion cubic feet of gas to Iraq's reserves.

ABU DHABI'S AlMansoori shows off its services at ALMANSOORI this year's open day Specialised Engineering held its 9th annual open day at its Mussaffah base at the end of March. AlMansoori's CEO Nabil Alalawi joined more than 1,000 service and industry clients for what is fast becoming a key event in the region’s energy calendar. A range of AlMansoori’s partner organisations attended the event including Camcon Oil, Claxton, HyrdraTech, SledgeHammer, Seal-Tite International, StreamFlo, The Reach Group and Ulterra. The day provided an opportunity for Alalawi to thank employees, suppliers and partners of the company for their support over the past 12 months. During the open day, Alalawi said: “The business has gone from strength to strength and we are looking forward to another successful year ahead. In the last year we have made some significant strategic alliances, grown the business, entered new markets and made improvements in terms of QHSE.”

Baker Hughes Q1 profit falls

Endress+Hauser eyes Saudi market

BAKER HUGHES’ FIRST quarter profit for 2012 has fallen to US$379 million from US$381mn for the same period in 2011. The oilfield services company has blamed increasing costs in the US for the fall, but said that its international performance was more encouraging. Its revenue climbed 18 per cent to US$5.36 billion for corresponding Q1 periods for 2011 and 2012, but its operating margin declined to 11.7 per cent from 14.1 per cent for the same periods. International revenue for Q1 was US$2.2 billion, up by US$291mn compared to 2011 figures, www.bakerhughes.com while the company’s operating profit was US$295mn for the quarter – an increase of US$66mn on the same period last year. Baker Hughes president and CEO, Martin Craighead, said, “It is clear that the overall market is experiencing pricing pressure that is likely to extend throughout 2012. “Our performance in the international markets was strong,” he added. Baker Hughes senior vice president and chief financial officer Peter Ragauss added, “Our final results are better than expected due to strong activity in Africa and the Middle East.” During the first quarter of 2012 the firm started work on its first integrated operations contract in Iraq, which Craighead said he expected to see further growth from throughout the rest of the year.

OIL REVIEW SPOKE to Endress+Hauser Group, COO Michael Ziesemer, after the inauguration of the company’s new sales centre in Saudi Arabia about how the opening represented a big step forward for Endress+Hauser Arabia. Ziesemer discussed the significance of opening a dedicated office in Saudi Arabia which will be located in Al Khobar. The company has two other offices located in Riyadh and Jeddah. “It is very important since it is showing to all people in the market our dedication to the development of the business in the Kingdom of Saudi Arabia,” he explained. Endress+Hauser’s business in the Kingdom has been steadily growing even before the company founded Endress+Hauser Arabia at the beginning of the year. The demand from customers to talk and interact directly with manufacturers meant that the company has been looking for a while to establish a sales presence in Saudi. The new division is a joint venture between Endress+Hauser Group and local company Anasia (Abudawood Group). “We have worked together with Anasia for more than 10 years and this is set to continue. We appreciate very much the development of the market by Anasia. The relationship to Sheikh Anas Abu Dawood and to Anasia was, is and will be very important to us,” said Ziesemer. The Middle East is seen as strategic region for Endress+Hauser and according to Ziesemer Saudi Arabia is top of the list and globally it is one of the leading hydrocarbon markets. “We see big investments as well in Qatar, Abu Dhabi and in Iraq,” he added. The company already has a sales office in Qatar and support offices in Dubai and Abu Dhabi. There are also a number of resident engineers based around the region. Ziesemer suggested that Iraq would most likely see the next dedicated Endress+Hauser sales centre. Ziesemer concluded: “We see huge investments in the oil and gas, and petrochemical markets and these industries will be our main focus.”

8 Oil Review Middle East Issue Four 2012

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News

Executives Calendar 2012 MAY 2012 20-23

Middle East Petrotech 2012

MANAMA

www.mepetrotech.com

20-23

MEPIPES 2012 (Oil & Gas Pipelines in the ME)

ABU DHABI

www.theenergyexchange.co.uk

18-21

Global Water Oil & Gas Summit

DUBAI

www.cwcoilgasandwater.com

4-7

EAGE

COPENHAGEN

www.eage.org/event

4-8

World Gas Conference

KUALA LUMPUR

www.wgc2012.com

5-8

Caspian Oil & Gas

BAKU

www.caspianoil-gas.com/2012

13-14

IADC World Drilling Conference

BARCELONA

www.iadc.org

18-20

Iraq Petroleum 2012

LONDON

www.cwciraqpetroleum.com

STAVANGER

www.ons.no

JUNE 2012

AUGUST 2012 28-31

Offshore Northern Seas

SEPTEMBER 2012 3-6

Erbil Oil & Gas Exhibition

ERBIL

www.erbiloilgas.com

24-26

SAOGE 2012

DAMMAM

www.saoge.org

OCTOBER 2012 2-5

KIOGE 2012

ALMATY

www.kioge.com

8-11

Gastech

LONDON

www.gastech.co.uk

NOVEMBER 2012 11-14

ADIPEC 2012

ABU DHABI

www.adipec.com

19-22

Offshore Southeast Asia

SINGAPORE

www.osea-asia.com

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

Weatherford Q1 profit soars WEATHERFORD INTERNATIONAL HAS reported that first quarter profit for 2012 more than tripled compared to the same period in 2011 to hit US$190mn. The jump in profit was helped by higher revenues in North America and the expectation is of strong results from the Middle East later in the year. Its Q1 2012 revenue increased to $3.6 billion, up by 26 per cent from $2.86 billion during the first quarter of 2011, the company said in a statement. North America revenue for Q1 was up by 29 per cent compared to the first quarter of 2011 and international revenue increased by 23 per cent over the same period. Q1 revenue in Middle East and North Africa (MENA) declined by US$70mn, but its operating income was US$14mn, am increase of 39 per cent on the same period last year. Weatherford www.weatherford.com president and CEO, Bernard Duroc-Danner, said he expected "MENA to improve in the second half of 2012, from both a top line and margin standpoint. We believe most startups in Saudi, Kuwait and Iraq will be successfully initiated." He added that Iraq "will evolve into an operation of improving profits as the year unfolds." Duroc-Danner was less hopeful about a return to profitability in North Africa. "We do not anticipate an improvement in North Africa, Libya, Algeria until late in the year or perhaps 2013.”

12 Oil Review Middle East Issue Four 2012

Jotun targets Saudi’s oil and gas industry JOTUN PAINTS, A leading producer and distributor of paints and powder coatings, is making an extra effort to focus its business on meeting the demands and requirements of Saudi Arabia’s oil and gas industry. Jotun has vast experience in marine protection and powder coatings and has developed an extensive range of products for protection in some of the world’s most demanding environments, particularly offshore oil exploration. The growing demand in the Kingdom for protective coatings has been the driving force behind Jotun’s strategy to develop newer and highly efficient powder coatings. The company spends heavily on research and development which has resulted in the production of advanced formulations that offer resistance to corrosion and severe abrasion. This push for a Applying Jotun's protective coating to a tank in Saudi stronger presence in the oil and gas segment is being led by the company’s protective coatings division, which focuses on the development, manufacture and supply of coatings to meet the challenging needs of the oil and gas sector. Through this division the company is able to provide maximum internal and external corrosion protection as well as temperature resistance. This is very important in the oil and gas industry which operates under some of the most extreme weather conditions. Jotun Paints feels it has positioned itself to meet the fast-changing global challenges of this technically demanding sector and believes it can be part of Saudi’s oil and gas industry growth.

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Some oil facilities may have suffered damage during the recent fighting

Analysis

Key oil facilities may have been damaged during the recent conflict in Sudan.

Sudan seesaws as

dispute continues O

N 10 APRIL 2012, the South Sudanese Army occupied a disputed oil field at Heglig in Sudan's South Kordofan state. On 17 April, Sudan carried out airstrikes on targets in South Sudan's Unity state, which the United Nations (UN) said resulted in at least eight civilian deaths and 22 injuries. The next day, President Bashir called for the 'liberation' of South Sudan under the current leadership. We assess that the statement is probably aimed at appeasing domestic dissension over the loss of Heglig to South Sudan rather than a genuine call to launch a prolonged war. On 21 April, the South withdrew from Heglig after Sudan deployed its much-superior air power to retake the oilfield, which has halted production and has suffered collateral damage according to its operator Greater Nile Petroleum Operating Company.

Key allies Sudan's two major pipelines, Petrodar (running from Palogue to Port Sudan) and the Greater Nile Oil Pipeline, (running from the Heglig and Unity fields to Port Sudan) both cross the North-South border and risk being damaged. Since then Sudan has launched air strikes on the Southâ&#x20AC;&#x2122;s oil-rich town of Bentiu, while South Sudanese proxy forces have launched attacks in Talodi, in Sudan. The two sides fought a civil war from 19832005 and South Sudan will be reluctant to return to all-out war. It will also be keen to avoid isolating key allies such as the US and European Union. Furthermore, its decision to halt oil production means it will struggle to pay militia forces it has co-opted from Sudanese sponsorship.

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Reluctance within Sudan for all-out war is exemplified by a January statement by 700 military officers who warned the government against such a move and demanded national reforms. Instead, Sudan is more likely to rely on proxy forces in border areas, with any ground incursions limited to the northern states of South Sudan. Most fighting is likely to be localised along the border region. Sudanese air strikes are likely to focus on military and rebel positions in northern parts of South Sudan (Unity, Upper Nile and Jonglei states).

Sudan is more likely to rely on proxy forces in border areas However, risks of air strikes on the South Sudanese capital, Juba, would rise in the coming weeks if Heglig is not recaptured. A further trigger for strikes on Juba would be an offensive by SouthSudanese-backed-SRF rebels on the Sudanese capital Khartoum; such risks will rise in the threemonth outlook. Furthermore, SRF rebels in Sudan are likely to intensify attacks in South Kordofan and Blue Nile states, raising collateral risks to energy, transport and humanitarian operations around Nuba Mountains, Kadugli and al-Kurmuk. These include the Roseires Dam on the Blue Nile.

movement toward Khartoum is likely to be impeded by aerial bombardment by the Sudanese Air Force. This would increase the likelihood of the rebels seeking to cut power supply from the Roseires Dam or halt oil flows through oil pipelines. However, the aim of such actions would be to disrupt supplies in order to put pressure on the NCP, but not inflict major damage on assets that the rebels themselves would later rely on if they succeed in seizing power. Despite the Sudanese military's air superiority, SRF rebels are likely to use support from South Sudan and weapons smuggled from Libya and captured from Sudan, which include MANPADS. In September 2011, we noted that the success of any rebel move against Khartoum and the ruling NCP would rest on the creation of a broad-based political movement. On 14 March 2012, the SRF alliance (SPLM-N and Darfuri rebels including JEM), formed a committee with influential members of the opposition, namely the Democratic Unionist Party (DUP) and National Umma Party (NUP), to coordinate efforts towards regime change. Previously, in May 2008, a convoy of around 100 vehicles from the Darfur-based JEM rebel group successfully reached Omdurman, adjacent to Khartoum, to launch an attack that was repelled by the army after a day of heavy fighting. We assess that the SRF is unlikely to suspend activity until presented with negotiations to create a government of national unity. â&#x2013;

Major damage An escalation of fighting between the North and South will probably be used by Sudanese rebels to attack the Sudanese capital Khartoum, forcing the Sudanese military to fight on two fronts. Any

Exclusive Analysis Ltd is a specialist intelligence company that forecasts commercially relevant political and violent risks worldwide. For additional information, visit www.exclusive-analysis.com

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Analysis

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Worldwide upstream oil and gas M&A unconventional resource spending reaches peak FUELLED BY NATIONAL oil companies and international buyers making acquisitions in North American shale gas, shale oil and tight oil basins, global transactions involving unconventional oil and gas resources reached a record high US$75 billion in 2011, according to the IHS Herold 2012 Global Upstream M&A Review, which was released by information and analytics provider IHS. This figure represents 48 per cent of total 2011 worldwide upstream merger and acquisition (M&A) spending “Cross-border buyers, led by Asian-based investors, continued to stream into North American unconventional resource plays

through asset partnerships and select corporate deals, with a bullish view on potential LNG exports to the Asia-Pacific region in the coming decades,” said Christopher Sheehan, director of energy M&A research at IHS. “In 2011, high crude oil and international gas prices were juxtaposed against persistently depressed North American natural gas prices, leading to a 15-year high in deal counts outside North America.” Total global upstream M&A transaction value, including corporate mergers, fell 30 per cent from an all-time high in 2010, which was driven by massive asset divestiture programs. Corporate deal value in 2011 rose 19 per cent

to more than US$58 billion, including BHP Billiton’s US$15 billion takeover of unconventional resource-focused Petrohawk Energy, the first upstream corporate merger greater than US$10 billion since the ExxonMobil-XTO deal in late 2009. Sheehan noted the deal flow also increased in all regions outside the U.S. and Canada as international investors pursued the prolific oil discoveries that have occurred in recent years in regions such as deepwater Brazil and Africa. In Australia, the coal seam gas-to-LNG market consolidated further, and evolving markets such as Iraq’s Kurdistan region welcomed new entrants through M&A.

Global energy leaders to discuss future of gas at Gastech 2012 LEADERS REPRESENTING THEIR governments and the international energy community will come together later this year to tackle key challenges and examine the role for gas in the future energy mix. The Gastech 2012 Conference Programme will highlight the major issues that are defining what has been termed the ‘Golden Age for Gas’, with key technical and commercial sessions. Led by the most influential business leaders and engineering experts from across the supply chain, the presentations will focus on a range of topics that impact the direction the industry is headed. www.gastech.co.uk Japan, the world’s largest consumer of liquefied natural gas (LNG), features prominently this year, with special papers examining the impacts that last year’s tsunami had both commercially and technically on the Japanese gas industry. The Japan Gas Association fly to London to deliver a case study on the Sendai LNG terminal – damaged by the tsunami – plus Gastech will welcome papers reviewing the global impact Japan’s decision to step down its nuclear programme will have on the supply and demand of gas. One highlight paper will be delivered by the Tokyo Gas

16 Oil Review Middle East Issue Four 2012

Company, who will present their vision and predictions for the global gas market outlook in 2020. Gastech also focuses on the impacts that low prices in North America are having on gas monetisation, and one key debate will be the role of LNG versus GTL (gas-to-liquids) as producers of gas seek new, more diverse revenue avenues other than their traditional power generation customers. Commenting on the conference programme, Gavin Sutcliffe, head of content for Gastech said: “This year’s programme reflects the incredible pace of change afoot in the global gas community as consumption of LNG continues to grow, Asia drives demand post-Fukushima, shale resources in China, Argentina and Eastern Europe are developed, and credit squeezes continue to impact infrastructure and project developments. “As organisers of one of the world’s most respected industry programmes, our role is to bring the global gas industry together to discuss and debate exactly how gas can move forwards and evolve in a world where the fuel choices between fossil, nuclear and renewables remain undecided by many international governments.”

S04 ORME 4 2012 Analysis 2_Layout 1 03/05/2012 14:16 Page 17

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Analysis

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While German oil and gas company Wintershall has been busy expanding its operations in the past few years across Russia, northern Europe and South America, it has also been keeping a firm eye on its activities in the Middle East

Growing in the

Gulf B

ACK IN MAY 2010 the firm signed an MoU with Abu Dhabi National Oil Company (ADNOC), Abu Dhabi’s stateowned oil company, to develop a sour gas field within the Emirate, marking the company’s return to the UAE. Two years later, Wintershall finds itself in the process of negotiating a technical evaluation agreement with ADNOC before entering into the development of the field. Wintershall executive director for exploration and production, Martin Bachmann, says these negotiations are looking positive and that the firm expects the talks to come to a conclusion before the end of 2012. Its entrance into the Abu Dhabi market was of an unconventional nature and followed a proposal to develop a large sour oil field — Wintershall’s proposal, Bachmann says, was not the one ADNOC was not looking for. “ADNOC turned around and said that they liked the way we approached the bid and liked our capabilities, and they invited us to look at a different opportunity,” says Bachmann. Despite Wintershall’s previous involvement in an Offshore Dubai production project several years ago, Bachmann describes the company’s activities in Abu Dhabi as representing its first “tangible” project in the UAE. With a fully-staffed team already operational in Abu Dhabi, the company appears confident in the direction its UAE activities are moving. “This team has started preparations for drilling and we’re very confident that we will get going very soon in this regard,” remarks Bachmann.

Sensible targets Along with its adventures in Abu Dhabi, Wintershall is continuing its long association in Qatar, where it has invested more than US$200mn over the last 15 years. “At the moment we’re focused on exploration in Qatar and we’re spotting several exploration wells in the area,” notes Bachmann. If recent exploration attempts in the country prove successful, Bachmann says that the firm would not shy away from further investment as part of its plans for growth; he notes, however, that the firm is attempting to grow sensibly, rather than aggressively — especially when it comes to its Middle East activities. “We’ve grown very strongly in the last couple of years in our established areas, such as Argentina, the Netherlands and Russia,” he remarks. “But beyond that we are looking towards the

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Wintershall has invested more than US$2mn in Libya over the past five years

“We are looking towards the Middle East and we’re currently preparing the projects for growth in the period from 2015 and beyond.” Middle East and we’re currently preparing the projects for growth in the period from 2015 and beyond,” he notes.

Post-war regeneration Bachmann describes the Arab world as not the easiest place in which to find new opportunities. “Bahrain in a very small country so the number of projects is limited there and in Saudi Arabia

there is simply no access to the types of fields we would be looking for as it’s already in the hands of Saudi Aramco,” he says. “One country we would definitely consider working in if the opportunity popped up is Oman, and we’ve also looked into heavy oil opportunities in Kuwait, which is a market that is beginning to open up. “We find Algeria difficult and we find the market in Egypt a difficult one to get in – especially as we do not want to go into deepwater drilling. “We have, however, made a very strong commitment to Libya and if there were additional opportunities to invest in Libya, we would certainly pursue those,” he comments. The company has overcome the difficulties of working in a country that has undergone a civil war and resumed operations there in October of last year. To date, the company has rebuilt its production levels in Libya up to 60,000 barrels per day (bpd),

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but has stated that its immediate aim is to increase production within the country to pre-revolution levels of 100,000 bpd. “The focus is to re-establish pre-war production and there is a clear agreement among all players, including other oil producers and the state, to achieve this as fast and as efficiently as possible,” says Wintershall Libya general manager Dr Uwe Salge. Wintershall chairman of the board of executive directors Rainer Seele even describes Libya as a “test case” for the firm’s corporate activities in the Arab world, and says that Wintershall’s commitment to the North African country should make it more attractive to potential partners across the region. But despite announcing increasing profits for 2011 at its recent annual press conference, the company’s overall production levels fell by 15 per cent, which Seele cites as being mainly due to the Libyan crisis. “Our activities in Libya have always been long-term and our contacts [within the country] date to before the Gaddafi era,” says Bachmann. “There remain certain restrictions on some of the infrastructure, which still needs to be overcome, but once that’s running smooth again the next stage will come and that stage is to continue development work in the fields that have been interrupted by the unrest,” he adds.

Innovation and investment Wintershall may have invested more than US$2mn in Libya over the past five years, but Bachmann says that what makes the firm so attractive to potential partners in the Arab world is its ability to bring from Germany innovative technology and experience of working on sour gas sites. “I think what sets us apart is technology on the one hand and our ability to demonstrate what we’re already doing on the other hand,” he remarks. “Chemical Enhanced Oil Recovery (EOR) is one area in which we excel and, of course, we have our mother company BASF behind us with its huge chemical resource capacity.” Bachmann says the firm is quite advanced in the tight gas arena, and it is also able to boast about its Schizophyllan project, which uses a fungus-derived biopolymer for EOR polymer injections in reservoirs. Wintershall appears well placed to fill part of the resulting void that is being created by the changing requirements of the Middle East’s oil and gas fields. “What’s becoming increasingly more obvious in the region is that projects in countries such as the UAE and Qatar now require companies that can go after the more difficult hydrocarbons,” Bachmann remarks. “Previously, Abu Dhabi left a lot of its sour gas fields alone, but now there is a real shortage of gas in Abu Dhabi so they require help with that from companies with the technical expertise,” he states. Wintershall may be busy in its traditional markets, but its innovative and technical abilities, combined with its record for efficiency, could see it becoming a much sought-after partner in the Arab world over the next few years. ■ Wintershall has rebuilt its production levels in Libya by 60,000 bpd

Oil Review Middle East Issue Four 2012 19

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Afren makes discovery in Northern Iraq AFREN HAS ANNOUNCED that the high impact Simrit-2 exploration well, located on the Ain Sifni PSC in the Kurdistan region of Northern Iraq, has discovered a significant oil accumulation based on the results of drilling, wire line logs and sidewall core sampling. The objective of the Simrit-2 exploration well is to test the western extent of the Simrit anticline. The well has reached the prognosed total measured depth of 3,700m (3,697m true vertical depth). Preliminary analysis of data collected during and following drilling indicates that the well has encountered an estimated 409m of net oil pay in Cretaceous, Jurassic and Triassic age reservoirs (an estimated 312m of this pay is interpreted as containing light oil). No oil water contact has been established in the target reservoirs. As there are continuing strong hydrocarbon shows to the current depth of 3700m, Afren and operator Hunt Oil Middle East plan to run casing at the current depth and continue drilling to a new total depth of circa 3,800m to test additional zones of prospectivity. Once drilling operations have concluded a comprehensive well testing programme will be undertaken across multiple reservoir intervals, after which the drilling rig will be mobilised to the East Simrit Prospect to drill the Simrit-3 exploration well. Afren has a 20 per cent interest in the Ain Sifni PSC and is partnered by Hunt Oil Middle East (60 per cent. and operator) and the Kurdistan Regional Government (20 per cent). The successful result of the Simrit-2 exploration well represents a second major exploration success for Afren this year, following on from the Okoro East discovery offshore southeast Nigeria. The scale of the oil column that has been intersected suggests that the Simrit structure and surrounding prospects elsewhere on the Ain Sifni PSC have the potential to be transformational for Afren'.

Egypt discovery for Kuwait Energy KUWAIT ENERGY HAS announced a new exploration success with its West Ahmad-1X oil well, located in Area A in the Gulf of Suez, Egypt, adjacent to the Shukheir North West Field. Kuwait Energy is the operator of the concession, in which it holds a 70 per cent working interest. The remaining 30 per cent interest is held by Petrogas E&P, of Oman. The West Ahmad-1X well encountered oil in the Kareem formationand initial tests showed a production flow rate of 1,250 barrels of oil per day (bopd). This is the fourth exploration success in the Area A concession, and the 17th discovery in Egypt for Kuwait Energy since 2008. www.kuwaitenergy.com.kw Kuwait Energy Chief Operations Officer, Mohammad Alhowqal, said: 'This is another great success in a mature field that has been producing since 1960. Our new oil discoveries in Area A have significantly increased gross production in the area from 2,800 to 7,250 bopd since commencing operatorship in 2008. We look forward to continued success and to reaching the maximum potential of this field.' Egyptian operations contribute the largest share to Kuwait Energy’s current production. The 2011 production level excludes the four discoveries made in the Abu Sennan concession.

Shah Deniz enters new development phase

Tethys increases Oman production

THE SHAH DENIZ consortium has reached an important milestone and approved the decision to commence Front End Engineering and Design (FEED) on the estimated US$25 billion Shah Deniz Stage 2 project. The Shah Deniz Stage 2 project will bring gas from the Caspian Sea to markets in Turkey and Europe, opening up the 'Southern Gas Corridor'. Achieving this important milestone allows the consortium to maintain its target for first gas exports around the end of 2017. The project is set to produce 16 Bringing gas from the Caspian to markets in Europe billion cubic meters of gas per year. The entry into FEED represents the start of a key phase in the project during which engineering studies will be refined, further wells will be drilled, commercial agreements will be finalized and key construction contracts will commence. During the FEED phase of the project, the Shah Deniz consortium will finalize its selection of export routes across Turkey and into Europe. This Stage 2 development of the Shah Deniz field, which lies some 43 miles (70-km) offshore in the Caspian, is expected to include two new bridge-linked production platforms; 26 subsea wells to be drilled with two semi-submersible rigs; 500-km of subsea pipelines built at up to 550 meters of water depth; a 16 bcma upgrade for the South Caucasus Pipeline (SCP); and expansion of the Sangachal Terminal.

TEST PRODUCTION FROM the Early Production System (EPS) on Blocks 3 and 4 onshore the Sultanate of Oman continues and amounted in March 2012 to 361,394 barrels of oil, corresponding to 11,658 barrels of oil per day (BOPD). Tethys’ share of the production, before government take, amounts to 30 per cent of the total, or 108,418 barrels. Long term production tests have been carried out on wells from both the Saiwan East oil field on Block 4 and the Farha South oil field on Block 3. Production rates continue to vary depending on test programme design and a v a i l a b l e capacity. Tethys has a 30 per cent interest in Blocks 3 and 4. www.tethysoil.com Partners are Mitsui E&P Middle East B.V. with 20 per cent and the operator CC Energy Development S.A.L. (Oman branch) holding the remaining 50 per cent. Tethys Oil is a Swedish energy company focused on identification and development for production of oil and natural gas assets. Tethys’ core area is the Sultanate of Oman, where the company is the second largest onshore oil and gas concession-holder with licence interests in three onshore blocks.

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DNO completes drilling of Tawke well DNO announced that it has completed drilling of the Peshkabir-1 exploration well in the Kurdistan Region of Iraq and is preparing to test observed oil shows across three potentially producing intervals. Full and sidewall cores suggest a continuous hydrodynamic column within the cretaceous interval and the additional shows in the jurassic and triassic are the first encountered by the company at lower depths in the Tawke license. The Peshkabir-1 well was designed to probe a large undrilled feature west of the currently producing Tawke field. It reached total depth of 4,092 meters, the deepest well yet for the company in Iraq. The well was spud in September 2011. Wireline logging and coring operations are underway and will be followed by a minimum of five planned flow tests, two in the Triassic, one in the Jurassic and two in the cretaceous. In providing further updates on drilling and other operations across its portfolio, the company announced that the Tawke-15 well, drilled and completed in the cretaceous in 2011 but previously shut in due to low productivity, has now tested 7,000 barrels of oil per day following a justcompleted workover operation. The well has been connected to the existing pipeline and processing facilities, further boosting Tawke field deliverability. A third well, the Tawke-14 well is drilling ahead of schedule at over 5,906 feet (1,800 meters). The well is located within the northern flank of the field and is another of the planned 2012 wells designed to confirm and delineate the potential of the cretaceous in an untested up-structure location. The well is expected to reach a total depth of 8,743 feet (2,665 meters) in Q2 of 2012." "Operations on the Tawke field continue according to plan and we are on track to increase capacity to 100,000 barrels of oil per day by the end of 2012,” said company spokesman.

Iran commissions third Azadegan rig

Bapetco expands Western Desert drilling BADR EL DIN Petroleum Company (Bapetco) has concluded the drilling of two new developmental wells in its Western Desert concession area as part of its development plan for the 2011-2012 fiscal year. Egypt Oil and Gas reportedly has learned that one of the new wells, dubbed BED-128, was drilled using the EDC-52 rig to the depth of 10,420 feet, with drilling costs reaching US$3.320mn. The new oil-producing well has been added to the company’s overall production numbers. The other well, named SITRAB-18, was drilled using the EDC-72 rig to a depth of 11,530 feet. Costs of the operation amounted to US$2.75mn. During the previous fiscal year, Bapetco successfully drilled 34 wells, and the company is looking to drill 44 exploratory and developmental wells in the current fiscal year 2011-2012 in order to boost total production of crude oil and natural gas. The company’s production rates during the month of February 2012 stood at 1,126,540 barrels of crude oil and 2,118,393 cubic feet of natural gas. Badr El Din Petroleum is a joint venture company between the Egyptian General Petroleum Corporation (EGPC) and Royal Dutch Shell.

Iraq wants BP to revive Kirkuk field BP IS LOOKING closely at a project to revive Iraq's northern Kirkuk oil field, industry sources said, as Baghdad aims to strengthen its position in a dispute with semi-autonomous Kurdistan over ownership of northern Iraqi fields. Executives from the UK major paid a visit to the giant oil field and met with Iraqi officials in Kirkuk at the end of March. The trip followed initial soundings from Iraq's Oil Ministry to BP about the ageing oil field, which is suffering from massive declines.

THE NATIONAL DRILLING Company of Iran has put into operation the third drilling rig at the North Azadegan oil field, southwest of the country. The company plans to launch four drilling rigs at the oil field, according to Shana news agency. The Azadegan oil field is located close to the Iraqi border. The field holds around 33.2 billion barrels of in-situ oil deposit, of which 5.2 billion barrels are recoverable. Oil Minister Rostam Qasemi said in August 2011 that the Iranian government should consider plans for the development of joint oil fields in the border areas with Iraq. The government should increase the budgets for the development of joint oil fields, Qasemi added. The oil industry's infrastructure needs more than 500 trillion rials (about US$41 billion) of investment to achieve objectives of the 20-Year Outlook Plan, which ends in 2025, Qasemi was quoted as saying. Al Shahristani

Tunisian well disappoints Chinook CHINOOK ENERGY ANNOUNCED that the BJA 2 exploration well, located on the Sud Remada permit onshore Tunisia, was plugged and abandoned on April 15, 2012 after reaching a total depth of 1,702 metres. The Ordovician reservoirs were encountered structurally lower than forecast and were wet. The BJA 2 well fulfills all outstanding exploratory drilling commitments on the permit and the partners will incorporate the well results before proposing the next exploration location planned for later this year or early 2013. The Foradex 14 drilling rig will begin moving to the TT16 horizontal development well on the Bir Ben Tartar (BBT) Concession within the next 10 days. The TT16 well is the first horizontal test on the BBT field and is planned to have a 1,000 metre horizontal section followed by an eight stage completion. Drilling and completion operations are expected to commence within 25 days and be completed in June. Partners in the BJA 2 well and the upcoming TT16 horizontal well are Chinook (86 per cent), through an indirect wholly-owned subsidiary, and Cygam Energy (14 per cent), through its subsidiary.

22 Oil Review Middle East Issue Four 2012

'BP is actively considering Kirkuk, provided the economics work,' said an industry source. 'But it's very early days; there are no negotiations.' Iraqi Deputy Prime Minister for Energy Hussain alShahristani is in London recently to attend an energy conference. Baghdad is understood to be keen to have the British oil major positioned in northern Iraq to counter the recent controversial move by US major ExxonMobil into Kurdistan, according to Western diplomats and Iraqi industry sources. The Kurdistan Regional Government (KRG) and Baghdad are locked in a long-running feud over oil and land rights. 'The central government has introduced a new element - the BP factor - which raises the level of debate over Kirkuk,' said an Iraqi oil executive. Baghdad was furious last year when ExxonMobil announced an exploration deal with the Kurds. It considers any oil contracts struck with the KRG to be illegal. Baghdad threatened to bar Exxon from future deals and even to reconsider its role at Iraq's southern West Qurna-1 oil field.

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Amended concession agreement offshore RAK DNO INTERNATIONAL HAS signed an amended concession agreement with the Government of the Emirate of Ras Al Khaimah, RAK Gas and Dahan Petroleum granting Dahan exploration rights to certain outlying areas of the Saleh concession in exchange for Dahan covering the cost of DNO International's and RAK Gas' participation in such exploration program. Dahan has 12 months to conduct a technical review of existing data and to acquire 3D seismic data, following which it can elect to drill, at its sole risk and expense, an exploratory well in the acreage surrounding, but not including, the Saleh field. The amended concession agreement provides that DNO International would have a 16 per cent carried interest in such exploratory well. Dahan has the option to drill additional exploratory wells in the designated areas with DNO International retaining the option to continue its 16 per cent carried interest on each such well or to participate instead at 40 per cent on a paying basis. The ownership participating interests and other fiscal and operating terms of the concession area containing the Saleh field remain unchanged, with DNO International holding 70 per cent and RAK Gas the remaining 30 per cent. 'We are pleased that Dahan is enthusiastic about the offshore potential of the Emirate of Ras Al Khaimah and will conduct an exploration programme designed to give us a fresh look at the area surrounding the Saleh field,' said David Thorpe, General Manager of DNO Ras Al Khaimah. 'If a discovery is made, we intend for it to be tied back to our existing platform and pipeline facilities, enhancing the commerciality of the planned Saleh re-development project,' he added.

Extension granted in Kazakhstan TETHYS PETROLEUM HAS received permission for the extension of the Akkulka exploration contract in Kazakhstan where the company is currently appraising the high potential Doris oil discovery and also where it has several exciting exploration targets. The key points are: 6 Two year extension to comprehensively appraise Doris commercial oil Tethys talks of â&#x20AC;&#x2DC;exciting discovery and enable further high opportunitiesâ&#x20AC;&#x2122; impact exploration on the Akkulka in Kazakhstan Block; 6 Retention of exploration prospects recently identified using the recently interpreted 3D and 2D seismic data; 6 Several prospects identified on seismic data including Dodone, Daphne and prospects at Triassic level where oil shows have already been encountered; 6 New Resource report due May 2012 including Doris and recently identified prospects; 6 Next appraisal/exploration well to spud mid-year to target channel sand system and high potential Dyna sand prospect; 6 Additional exploration/appraisal prospects have been identified using the recently interpreted 3D and 2D data. This data has led to the identification of a number of other attractive exploration prospects at the Doris reservoir levels and other horizons. All these will be included in the new resource report.

Gulf Keystone happy with Shaikan-4

BP raises Oman gas reserves estimate

AN EXTENSIVE WELL testing programme, commenced in December 2011 after Shaikan-4 had drilled to a total depth of 3,387 metres. Preliminary results of the drilling operations were a significant contribution to the new data used by Dynamic Global Advisors (DGA), independent Houston-based exploration consultants, to calculate an addition of over three billion barrels of gross oil-inplace volumes for the Shaikan discovery announced in November 2011. In the course of the Shaikan-4 well testing programme the company has conducted seven well tests in all target formations in the Triassic (Kurre Chine-A, Kurre Chine-B and Kurre Chine-C), Jurassic (Butmah and Lower and Upper Sargelu) and Cretaceous (Chia Gara). Additionally, the Company has performed an acidization and retest www.gulfkeystone.com of the Sargelu formation interval as part of the well completion process. As a result of the Shaikan-4 well testing programme, the company has achieved total maximum aggregate flow rates of 24,000 barrels of oil per day. Following the conclusion of the Shaikan-4 well testing programme, the well is being completed as a producer and will be tied to the Shaikan-1 and Shaikan-3 Extended Well Test facility.

BP HAS RAISED its estimates of the gas reserves potential of its Block 61 concession in central Oman to a staggering 100 trillion cubic feet (TCF). This figure represents a three-fold jump over the company's previous estimate of 30 TCF, making the concession -- which holds the prodigious Khazzan-Makarem gasfields - potentially one of the richest gas blocks in the Sultanate. Furthermore, if proven to be commercially exploitable, Block 61 could yield massive volumes of natural gas that will fuel Oman's industrial and economic development well into the future. Confirming the revised estimates of the block's gas reserves potential, Daniel Blanchard, BP Oman's new General Manager, said: "The block potentially has 100 TCF based on our studies." He attributed the jump from the previous estimate of 30 TCF to a "better understanding of the block, better understanding of the deep reservoirs, and continuing interpretation of the seismic data that we have." Speaking to the Oman Observer, Blanchard said BP Exploration (Epsilon) Ltd - Oman Branch, continued to make excellent headway in appraising the potential of the Khazzan gasfield currently the focus of the international oil major's efforts. "The Khazzan project is progressing very well. We are going through a series of internal reviews on the project development, and also in parallel, having conversations with the government around the commercial negotiations as well. On both fronts, we are making great progress, and this is very positive for the company, and a very positive project for the Sultanate of Oman." BP is investing hundreds of millions of dollars during the current exploration and appraisal stage in targeting gas trapped in tight rock at depths ranging from 4,500 to 5,000 metres. Appraisal gas currently being produced by BP as part of its Early Well Testing (EWT) programme is pumped into the government gas grid.

24 Oil Review Middle East Issue Four 2012

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Lukoil now active at West Qurna-2

Northern Iraq success for Western Zagros

LUKOIL STARTED PRODUCTION drilling and construction of a key production facility, namely a Central Processing Facility, at the West Qurna-2 field in Iraq recently. Abdel Karim al-Luaibi, the Iraqi Oil Minister, and also the heads of the Basra province, Iraq's South Oil Company, LUKOIL Overseas and of the major contractor companies Baker Hughes and Samsung Engineering all participated in the festive ceremony dedicated to the occasion. As part of this drilling project, 23 directional wells will be constructed. Drilling operations will occur simultaneously at five well pads by means of state-of-the-art diesel electric units with a bearing capacity of 450 tons, which allows workers to drill wells as deep as 5,000 meters without equipment remounting. The units are specially modified to be promptly relocated within the well pads under the cluster slider rig scheme. Later the drilling operations will be conducted at the other four well pads with similar units. The Central Processing Facility will be constructed along with the facilities for well pads infrastructure development and oil gathering lines, as well as the water and power supply systems, shift camp and a number of other infrastructure and support facilities. 'We have opened the active field development stage today. Upon reaching the production volume of 150,000 barrels per day LUKOIL will receive the right to reimburse expenses and receive remuneration. After the initial expenses are reimbursed, the project will turn into a self-financing entity. The total investments in the full-scale project implementation will come to around USD 25 billion,' Vagit Alekperov, OAO LUKOIL President, said. The West Qurna-2 field, discovered in 1973 with the help of Soviet geologists, is the world's second largest undeveloped field with recoverable oil reserves of around 14 billion barrels. The field, covering an area of 340 sq-km, is located 65-km to the north-west of Basra, a major seaport.

CANADA-BASED OIL EXPLORER WesternZagros Resources said it discovered more oil in the Kurdamir-2 well in the Kurdistan region of northern Iraq, sending the company's shares up 10 per cent. The company raised its estimate for mean contingent resources by 400 per cent to 147mn barrels of oil, and for mean prospective resources by about 300 per cent to 1.2 billion barrels of recoverable oil at the Kurdamir-2 block's Oligocene reservoir. Contingent resources refer to potentially recoverable oil from www.westernzagros.com known accumulations that may not yet be viable for commercial development. Prospective resources refer to potentially recoverable petroleum from unknown accumulations that a company can drill from an oilfield. WesternZagros, which along with other junior explorers such as Longford Energy is active in Iraq's Kurdistan region, said the Kurdamir-2 well encountered a 118-meter light oil column with no interference of water. â&#x20AC;&#x2DC;The oil reservoir of the Kurdamir structure extends further than the area previously assessed,â&#x20AC;&#x2122; said Simon Hatfield, WesternZagros's Chief Executive Officer.

Sea Dragon discovers oil at Al Baraka

Iraq could triple output in six years

SEA DRAGON ENERGY announced that the West Al Baraka-2 exploratory well, the first well of the 2012 drilling campaign, was successfully drilled to a total depth of 4,070 feet in the basement. The West Al Baraka structure is located nine kilometers to the southwest of Al Baraka oil field. The WAB-2 well encountered oil shows in the Abu Ballas sand and the Six Hills F reservoirs, both zones are productive in Al Baraka oilfield. Petrophysical analysis indicated oil saturations in www.seadragonenergy.com the primary target being the Abu Ballas sand. The Six Hills F sand was perforated and tested but was found wet. A bridge plug was set at 2,230 feet and the Abu Ballas sand was selectively perforated in the interval 2,085-2,164 feet. The well was tested for a short period and 37 degree API oil was recovered at surface with no water. The Abu Ballas sand is productive in Al Baraka oilfield and requires hydraulic fracturing stimulation to improve productivity. In order to establish the well productivity, a decision was made to release the rig and work on designing an appropriate hydraulic fracturing program. Two previously drilled wells on the structure also encountered oil shows in the Abu Ballas Formation but were not tested. The forward plan is to integrate the WAB-2 well information with the recently reprocessed seismic to finalize mapping of the West Al Baraka structure, estimate reserves, develop an appraisal program and apply for a development lease.

IRAQ, WHICH IS currently producing more than three million barrels of crude oil per day, will increase its capacity of production to more than 10mn barrels a day in the next six years. "This is to assure the world market that there is sufficient crude for them," Iraqi Deputy Prime Minister for Energy Hussain Al Shahristani said at a special briefing after the inaugural meeting of the U.S.-Iraq Joint Co-ordinating Committee on Energy at the Department of Energy, Washington, DC, recently. "We'd like Iraq to be considered as a dependable long-term supplier of world energy needs, whether oil or gas, and there should not be concerns of shortages in the supply in the near future," he told reporters. Shahristani said Iraq would make a decision and announce before the year-end its production targets for the coming years. Iraq's energy chief said the government had developed infrastructure to enable it to handle more exports to the world market. Iraq has already signed 12 contracts for its 12 oilfields and three gas fields, which together have the potential to drill about 12mn barrels per day. "Iraq is called upon to cater for the world energy needs in the coming years, and it is expected that the world will need more energy, more hydrocarbon energy, in the coming two to three decades, and Iraq is uniquely positioned to be able to provide the world with its incremental energy needs. That's why we have invited the international oil companies to work with us to develop the Iraqi resources, and the work has started based on the contracts which they signed two years ago. And the production is already increasing, and so are our exports," Shahristani said. Many countries in the Middle East and in Europe are looking towards Iraq to cater to their gas needs. Shahristani made it clear that "Iraq is very much interested to be a partner and a supplier of gas to not only our Arab neighbors but also to the European countries and the world at large."

26 Oil Review Middle East Issue Four 2012

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Gas

BP’s 2012 Energy Outlook 2030 forecasts future energy trends for the period 20112030 and highlights the growing rise of natural gas as a less carbon-intensive fuel in the global energy mix and the region’s key role in supporting this rise

The unstoppable rise of

natural gas G

LOBAL ENERGY DEMAND is likely to grow by 39 per cent by 2030, or 1.6 per cent annually, almost entirely in non-OECD countries. During this time natural gas is projected to be the fastest growing fossil fuel globally at a rate of 2.1 per cent annually. The BP report suggests that demand for gas will primarily come from non-OECD countries which will account for 80 per cent of global gas demand growth with Asia and the Middle East the two fastest regions. China will play a major part in the demand for gas and the country will contribute 23 per cent to the global demand increase. Gas use in China in the period will grow rapidly by 7.6 per cent annually so that by 2030 gas usage in the country will be 46 Bcf/d, equal to that of the EU in 2010. BP says it expects to see steady progress in longstanding efforts to displace oil with gas and to improve the efficiency of energy use within the region. Saudi Arabian, Iraqi, and regional production of gas-related liquids will dominate supply growth as the region’s share of global oil supply rises to 34 per cent by 2030. On the gas supply side the main regional contributors to growth will come from the Middle East region which BP forecasts will see 26 per cent of global growth by 2030. Liquefied Natural Gas (LNG) will represent a growing share of gas supply. Global LNG supply is projected by BP to grow 4.5 per cent annually to 2030, more than twice as fast as total global gas production and faster than inter-regional pipeline trade. LNG will contribute 25 per cent of global supply growth from 2010-30, compared to 19 per cent for the period 1990-2010.

28 Oil Review Middle East Issue Four 2012

Non-OECD countries will drive natural gas growth

Proven reserves The world had 6,609 Tcf of proved gas reserves in 2010, which BP claims is sufficient for 59 years of

Global energy demand is likely to grow by 39 per cent by 2030, or 1.6 per cent annually, almost entirely in non-OECD countries

production at current levels. Unconventionals remain to be appraised in detail globally, but current estimates suggest that they could be as much as double this R/P ratio. In fact, unconventional gas will play a more dominant role in the global energy mix, especially in North America and Asia where unconventional reserves will play an increasing role. North America’s production by 2030 will be dominated by shale gas and coal bed methane (CBM) with both gases set to account for 63 per

S07 ORME 4 2012 Gas Feature_Layout 1 03/05/2012 14:20 Page 29

cent of production. The sustained growth of shale gas raises the possibility that North America could export LNG by 2030 of 5 Bcf/d. China will be Asia’s main market for unconventionals as gas production in the country is projected to grow 6.1 per cent annually with shale gas and CBM likely to contribute 46 per cent to the growth. But China will see have a rising need for imports which will only be met by expansion of LNG and pipeline projects.

Oil constitutes 74 per cent of the region’s energy production, but will drop to 67 per cent by 2030 as gas production expands Outside North America, unconventionals are still in their infancy, according to BP. But in the long term they are expected to play a growing role but only after technical and regulatory hurdles have been overcome. BP does not see any major unconventional production in Europe until 2020.

Middle East’s key role The region’s role in global oil markets is set to increase considerably as gas supply rises in the future to meet domestic demand. The growing

The supply of natural gas in the region will rise

energy demand will be driven by the oil and gas needs of the industrial sector for petrochemicals and the expansion in energy-intensive LNG production. The region continues to rely on oil and natural gas for nearly all of its energy demand. The continuation of long-standing efforts to displace oil consumption with gas (to sustain oil exports) will continue to boost gas’ market share from 21 per cent in 1970, to 48 per cent in 2010, and 55 per cent in 2030, according to BP. Currently oil constitutes 74 per cent of the

region’s energy production, but will drop to 67 per cent by 2030 as gas production expands. But this will not stop the expansion of oil supply between 2010 to 2030, which is expected to expand by 10 Mbd. Gas production is set to increase by 41 Bcf/d. In the region, Saudi Arabia and Iraq will dominate the oil supply growth and in gas production the market will be driven by Qatar, Iraq and Saudi Arabia. Importantly, BP expects the region’s share of global supply will increase to 34 per cent for oil and to 18 per cent for gas (from 29 per cent and 14 per cent today). While there are large supply increases in both oil and gas, the impact on the region’s exports differs between the two fuels. Middle East oil exports currently supply 22 per cent of global demand. This share is set to rise to 25 per cent by 2030. For gas exports, the region only accounts for 2 per cent of global demand today and this will only increase to 3 per cent in 2030, as incremental growth is consumed locally. If the development of gas resources fails to materialise, additional oil will be required to fill the void. BP’s 2012 Energy Outlook 2030 stated: “Failure to develop gas resources and/or to improve oil intensity will weigh on the region’s ability to deliver the expected supplies to global oil markets.” ■

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Aramco's Karan Gas Project gets a head start

AMEC wins ADGAS contract

SAUDI ARAMCO'S FIRST non-associated offshore gas field development Karan Gas Project successfully started operations at its gas processing facilities in Khursaniyah seven weeks ahead of schedule. The completion of the project ahead of time is another milestone for the Karan Gas Project as the Kingdom seeks to produce more gas to run power plants and save crude for export. With a fully functional gas-treating train and a sulfur recovery train, the Second Phase of the project is almost complete. "The Khursaniyah Gas Plant (KGP) can now process one billion standard cubic feet per day (scfd) of nonassociated gas from the Karan offshore field," Aramco said in a statement. During the First Phase, the offshore gas was processed at KGP's existing associated gas processing facilities but the new gas trains are now solely dedicated to processing the gas internally. The company hopes to add two additional gas trains by the second quarter of 2012 that will bring the gas processing capabilities at KGP to 1.8 billion scfd. At the Karan offshore field, one tie-in platform and three production platform complexes are ready, with a fifth platform scheduled to be operational in the third quarter of 2012. The platforms are remotely operated and controlled from Khursaniyah. From the tie-in platform, the gas is sent, via an underwater trunk line, to the onshore processing facilities at Khursaniyah. Hydrogen sulfide, carbon dioxide and water are removed from the feed gas stream in the gas-treating trains. The hydrogen sulfide and carbon dioxide are directed to the sulfur recovery unit where the hydrogen sulfide is converted to elemental sulfur. Aramco had started producing about 400 million scfd of gas from Karan last July to help meet the local fuel demand.

ABU DHABI GAS Liquefaction Ltd (ADGAS) has awarded international engineering specialists AMEC an emission reduction contract for its flaring and emission reduction operation. The project management Flaring consultancy (PMC) service deal will cover the Front End Engineering Design (FEED) phase of ADGAS's project at its Liquefied Natural Gas facilities on Das Island, UAE. "I am delighted that we are able to support ADGAS in delivering an important project in one of AMEC's strategic growth regions," said AMEC Middle East, Africa and CIS vice president Alan McLean. "This award recognises not only our PMC capabilities, but also our world-class emissionsreduction expertise." The agreement, for which the value has not been disclosed, was awarded for a 10-month period and would see ADGAS further reduce carbon dioxide and sulphur dioxide emissions at the LNG plant on Das Island.

Shah gas field project on schedule THE SHAH FIELD development is on track to be completed by 2014 and it will help meet the UAE’s growing gas demand, said the CEO of Abu Dhabi Gas Development Company (Al Hosn Gas). CEO Saif Al Ghafli, said that the Shah gas field development was “one of the most ambitious sour gas projects ever commissioned” and confirmed that it was on track for completion in 2014, reported Gulf News. The upstream sour feed gases, along with the volumes of processed gas and produced sulphur, will set a new global benchmark for the gas processing and sulphur recovery industry, according to Al Ghafli. The project will involve construction of several gas gathering systems, new gas and liquid pipelines, and processing trains. The development is expected to produce significant amounts of condensate and NGL [natural gas liquids]. When the field is operational it expects to deliver gas at a rate of 200 bcf/year.

The Shah sour gas project will help meet local demand for gas

The Shah field development will contribute to UAE’s supply side which will help meet increasing demand for gas. Abu Dhabi has been getting its gas supplies through the Dolphin gas pipeline, which is set to continue.

Iran offers US500mn for Pakistan gas pipeline IRAN HAS OFFERED US$500mn, double its earlier offer, to help Pakistan finish building a planned cross-country gas pipeline between both countries. Pakistan and Iran in 2010 agreed to build a 2,775 km pipeline between Assaluyeh in southern Iran to Pakistan. Of the total, 900 km will run in Pakistan's territory and the estimated cost to build this section is around US$1.5 billion. Iran had initially offered to provide US$250mn for the project but has now doubled this to help the project develop faster. "Iran is willing to raise its offer to speed up start of the project," the Pakistan petroleum

32 Oil Review Middle East Issue Four 2012

ministry official was quoted by Fars News Agency as saying. The proposed cross-country pipeline has been in state of limbo since the Industrial and Commercial Bank of China in March backed away from funding the project. Pakistan also approached Russia's Gazprom in March to invest in the pipeline project. Pakistan's Petroleum and Natural Resources Ministry has issued pre-qualification of engineering, procurement, construction and commissioning tender for the project. Pakistan has itself been under pressure from the US to abandon the Iran gas pipeline project,

but has maintained that it will pursue it as it is vital to meeting the country's energy needs. Pakistan is facing a severe gas shortage and has so far been unwilling to give up the 1 Bcf/d of gas Iran has agreed to supply it through the pipeline. Iran and Pakistan are also due to hold negotiations soon on the supply of 70,000-80,000 bpd of Iranian crude to Pakistan. For Pakistan, the crude supply deal will help boost the operating rates of its refineries from the current 65 per cent to 70 per cent of capacity. Pakistan imports around 220,000 bpd of crude oil, with Kuwait, Saudi Arabia and Qatar its main suppliers.

S08 ORME 4 2012 Gas News_Layout 1 03/05/2012 14:26 Page 33

005

Gas

S08 ORME 4 2012 Gas News_Layout 1 03/05/2012 14:26 Page 34

Two Omani LNG firms could merge

Lebanon delays gas licensing round

OMAN’S GOVERNMENT IS looking at the possibility of merging two of Oman’s LNG firms, Oman LNG and Qalhat LNG, into one company that would boost Oman's LNG brand worldwide. Any potential merger would not only cut costs, but could also address perceptions of competition between the two state-owned LNG firms. Oman LNG was formed in 1994 to run two gas liquefaction trains at its Sur plant and Qalhat LNG was formed in 2003 to run the plant's third train. CEO of Oman LNG, Dr Brian Buckley, was quoted by Muscat Daily as saying that, “the government of Oman has approached the shareholders of the two companies on the possibility of merging the management of the two companies. There have been some preliminary evaluations of this proposal that are now being considered by the shareholders of Oman LNG and Qalhat LNG.” He added, "The government has expressed its interest in identifying potential synergies in such a merger, such as reducing costs and presenting a more united LNG face to the outside world." Buckley explained that current agreements with importers will remain unaffected by any potential merger. "The government and the two companies have given assurances to the existing buyers of LNG from Oman that any merger of the management of the two companies will in no way affect the commitments made under their long-term sales and purchase agreements with Oman LNG and Qalhat LNG," he noted. Major long-term overseas buyers of Oman LNG's gas are Korea Gas Corporation, Osaka Gas of Japan and Itochu Corporation. Overseas buyers from Qalhat LNG include Spain's Union Fenosa Gas, Mitsubishi Corp and Osaka Gas.

TENDERS FOR OFFSHORE exploratory drilling in Lebanon has been delayed again but seismic tests suggest increasingly large potential gas reserves, according to the country’s energy and water minister. Lebanon had aimed to launch tenders for exploration drilling by the end of March but that has been pushed back till later in the year. The minister Lebanon potentially has a Gebran Bassil large amount of gas offshore wants to establish an oil and gas oversight committee first before issuing any exploration tenders. According to Reuters, Bassil stated that delays in establishing an administrative state oil body were holding up plans to launch the tenders. He did not set a new target date for the licensing round. Twenty-seven companies have bought seismic surveys of the coastal waters, and a number have expressed interest in drilling including UK’s Cairn Energy and Genel. “Between the 2-D and the 3-D surveys we confirmed additional quantities three to five times higher in the survey areas. There is a high possibility of very promising commercial quantities of gas,” Bassil said.

Dolphin Energy issues tender for gas plant contract DOLPHIN ENERGY HAS issued a tender for an Engineering, Procurement and Construction (EPC) contract to upgrade compression facilities at its gas plant in Ras Laffan Industrial City, Qatar. The Abu Dhabi-based company confirmed that a number of firms had responded to the invitation and that a few had already been shortlisted. The EPC tender follows Dolphin's successful US$1.3 billion bond issue. "The move will help ensure the continuous supply of natural gas to the United Arab Emirates and Oman by increasing the overall reliability and availability of Dolphin's gas compression facilities," the company said in a statement. The Dolphin gas project Dolphin Energy has already awarded a contract to Rolls Royce Dresser to supply three new gas compressors with gas turbine drivers. The company denied media reports that it would increase throughput to 3 billion scf/day in 2015, claiming that "such reports were entirely incorrect". Dolphin Energy is a joint venture that transports gas from Qatar's offshore North Field via a subsea pipeline to the UAE and Oman.

34 Oil Review Middle East Issue Four 2012

BP raises gas reserves estimates at Block 61 BP HAS RAISED its estimates of the gas reserves potential of its Block 61 concession in Oman, according to BP Oman's general manager. The UK oil giant now believes that the potential gas reserves could be nearer 100 trillion cubic feet (TCF) which is three times as much as the original estimate of 30 TCF. Confirming the revised estimates of the block's gas reserves potential, BP Oman's general manager, Daniel Blanchard, said: "The block potentially has 100 TCF based on our studies," quoted Oman Daily Observer. The Block 61 concession holds the Khazzan and Makarem fields. Both fields have gas in place ranging from 70 to 130 trillion cubic feet. The full field development of the resource, if it goes ahead, will involve drilling around 300 wells. The first phase of the project will target reserves of up to eight trillion cubic feet with first gas delivered in 2016. With full field development, BP would look to achieve production of around 1.2 billion cubic feet of gas per day – equivalent to about a 33 per cent increase in domestic supply. Blanchard attributed the jump from the previous estimate of 30 TCF to a "better understanding of the block, better understanding of the deep reservoirs, and continuing interpretation of the seismic data that we have." BP has been operating a pilot Extended Well Test (EWT) at Khazzan since March 2011, helping to demonstrate the potential of a much larger scale development. Appraisal gas currently being produced by BP as part of its EWT programme is pumped into the government gas grid. "The EWT is strictly there to test different parts of the reservoir, so it's not a production focused operation. Maximum production out of four wells that we've been producing is 20-30 million standard cubic feet per day. Our target is testing the various wells and getting a deeper understanding of the reservoir and reservoir quality," Blanchard added.

S09 ORME 4 2012 Petrochemicals_Layout 1 03/05/2012 14:36 Page 35

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 by worldwide cementing companies • Easy to disperse resulting in considerable cost savings • Used by major oilfield companies such as: Petroleum Development of Oman (PDO), Schlumberger, Halliburton & Occidental • Exported to GC Countries, Iraq, Yemen, Libya, Sudan, Tanzania, Turkmenistan, 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 the 10th time.

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Petrochemicals

S09 ORME 4 2012 Petrochemicals_Layout 1 04/05/2012 10:56 Page 36

Oil Review spoke to CEO, Gulf Petrochem Group, Sanjeev Sisaudia, about the company’s expansions plans for its refining business and oil storage terminals in the UAE and its growing global reach

Providing refined products to a

global audience G

ULF PETROCHEM GROUP was founded in 1998 and specialises in oil refining, oil storage terminals and oil trading & bunkering. “Our core competencies lie in oil and as such, our key focus will remain on growth and expansion across various verticals of the oil industry,” said Sisaudia. Gulf Petrochem does not trade crude oil and instead focuses on refined products such as naphtha, fuel oil and bitumen, with some of the products produced from its two refineries which together have a capacity of 500 tonnes a day.

Target markets The company has established a strong global reach and already has a presence in South Asia, Far East Asia, Africa and Europe. The company intends to “move ahead with global expansion plans through trading offices in Geneva, India, Singapore and UAE,” explained Sisaudia. The trading offices allow the group to seek opportunities in global markets and the company is aggressively expanding towards Asian, African and other global growth markets, according to Sisaudia. China, Hong Kong and South East Asia are particularly attractive markets for Gulf Petrochem because of the huge demand for petroleum products in the Asian region. Sisaudia talked about the importance of the UAE and Gulf region which “remain significant to our long-term growth plans.” Gulf Petrochem has established an office in Dubai to better attract and pursue opportunities in the UAE and across the region. Europe is also a target market with the Geneva trading office catering to the European and Russian markets.

Refining growth On the refining side of the business the company operates a 60,000-metric tonne facility in the Hamriyah Free Zone in Sharjah which is capable of storing various grades of oils. Sisaudia stated: “We are planning to expand our refinery capacities in Hamriyah in terms of storage and we are also considering coming up with similar refining facilities at other locations.” There are also plans to build a new 4.5km pipeline from the main Hamriyah port to its storage terminal, which would allow it to take

36 Oil Review Middle East Issue Four 2012

delivery from larger ships that are restricted to the deeper harbour further out. The refining business is important and allows the UAE firm to work with a wide spectrum of feedstock and finished products, which are not only sold locally but are also sold to other markets in the region, South Asia and Far East. The other main expansion project that Gulf Petrochem is working on is the upgrade of its storage terminal in Fujairah with the first phase of its 1.2 million cubic meter storage terminal is on track for completion in September 2012. “We will focus on our Fujairah Oil Terminal during the second half of 2012. The terminal will help us leverage the strategic location and infrastructure of Fujairah to better serve our clients in the region,” said Sisaudia.

The company has established a strong global reach and already has a presence in South Asia, Far East Asia, Africa and Europe

The storage terminal under construction at Fujairah will consist of 112,233 sqm, which includes up to 73,269 sqm of expansion capability. It currently offers a capacity of approximately 350,000 cubic meters. The first phase will expand the storage capacity to 412,000 cubic meters. And future expansions will further expand the capacity to 1.2 million cubic meters. The two oil terminal berths off Fujairah port together offer seven berths for large tankers and 12 berths for small tankers. Terminal 1 has a maximum draft of 14 meters and a wharf length of 847 meters. The second terminal has a maximum draft of 18 meters and a wharf Sanjeev Sisaudia length of 1,400 meters.

Sisaudia added that, “Fujairah is very important in our growth plans because of its strategic location and infrastructure. Its geographical location makes it an important area for the business.”

Global trading “A comprehensive global growth strategy in place that will leverage our network of strategic storage spaces to engage into bulk trading of petroleum products on a global scale,” stated Sisaudia. Oil trading operations are run out of the company’s main trading offices in Dubai, Mumbai, Delhi and Singapore and are an integral part of the company’s global growth strategy. Sisaudia sees “immense growth potential for oil trading in the region.” Gulf Research Centre research suggest that the GCC will continue to grow in importance as

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The company finalised a lease agreement with West Ports, Malaysia to construct an oil terminal in Port Klang, Malaysia with a capacity of 150,000 cubic meters of Edible Oil and Fuel Oil for Bunkering. It is set to be competed by Q4 2012.

Sisaudia concluded: “This year, Gulf Petrochem will be focusing on the challenges of keeping up with the pace of our rapid expansion, managing the diverse global workforce and the changing economic and political conditions across the globe.” ■

Gulf Petrochem's refinery in Sharjah

Oil Review Middle East Issue Four 2012 37

Petrochemicals

an economic and trading hub and by 2020 the GCC is expected to become a US$2 trillion economy, exporting nearly a quarter of the world’s oil. “This is one of the reasons why we have established an office in Dubai as the city’s strategic location gives us greater flexibility to expand our oil trading business and to better serve our customers in the region,” added Sisaudia. Gulf Petrochem is also looking to expand its bitumen, base oil and bunkering business. It provides a bunkering service to ships calling into UAE ports. Currently, Gulf Petrochem and its subsidiaries cater to various ports in UAE and India with plans to forge into various global markets. “With our focus on the bunkering business and its rapid growth, we are considering acquiring new vessels this year,” said Sisaudia. Alongside the expansion projects going on in the UAE the company is also focusing on their other on-going terminal projects in Pipavav, India and Port Klang, Malaysia. The oil and gas terminal at Pipavav port in Gujarat is also under construction with initial capacity of 318,000 cubic meters comprising Fuel oil, CBFS, Marine Diesel Oil, Bitumen, RPO. It is expected to be commissioned by Q4 2012.

Petrochemicals

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Aquatech to demineralize Saudi plant

Iraq seeks to privatise refineries

AQUATECH, A GLOBAL specialist in water purification technology for industrial and infrastructure markets, has won an order for a demineralizing plant for IBN Rushd, a Saudi Arabia Basic Industries Corporation (SABIC) affiliate petrochemical facility, in Yanbu, Kingdom of Saudi Arabia. The technology supplied by Aquatech is a mixed bed demineralizer of 130 cubic meters per hour capacity. The plant will treat desalinated water and convert it to demineralized water for downstream use as boiler feed water. The treated water will have 0.1 Msiem/cm conductivity, and silica levels of less than 0.1 ppm. This is a repeat order for Aquatech, which had supplied a similar plant of three mixed bed units for the same facility in 1995. As part of the expansion plans, the two new units supplied by Aquatech will be consolidated with the earlier units. The plant is expected to be completed around early 2013. Aquatech has recently worked with several SABIC affiliates, including United Petrochemicals, PetroKemya, and Sharq. "This project demonstrates our wide range of water purification solutions and our expertise in the industrial sector," said Vikrant Sarin, Manager - Technical & Business Development (Industrial Solutions), Aquatech Eastern (FZE). This recent win further consolidates Aquatech's presence in the oil and gas, chemicals and petrochemicals arena, particularly in Asia, where the company is executing several projects in these sectors throughout India, the Middle East, and China.

IRAQ IS LOOKING to gradually privatise its oil refineries and to attract investment in new plants around the country, its deputy oil minister said recently. Domestic demand for fuel is rising fast in Iraq as in other major Middle East oil exporters such as Saudi Arabia. Baghdad, which is boosting its oil production, is also pushing ahead with downstream expansion to end costly fuel imports. "We would like to see the Wanted private sector increase its role," investors Deputy Oil Minister Ahmad Al Shamma said at a conference in London. "You shouldn't have the ministry of trade buying and selling commodities; it's out of date." He added: "We are looking to complete renovation of old refineries and privatise them gradually. That's the ultimate goal." Demand for products coming from refineries is growing fast, both internationally and at home, the deputy minister said. "Domestic demand is increasing rapidly. People are driving around at midnight, when a few years ago there was an effective curfew at 6pm." Through improvements at existing refineries, Iraq aims to increase its capacity to 610,000 bpd by the end of 2012 from 567,000 bpd in 2011, Al Shamma said. Its target for next year is 750,000 bpd.

Bahrain Refinery sees record production BAHRAIN REFINERY REPORTED an overall annual output of 96.026mn barrels last year exceeding the projected production by 50,000 barrels despite the ongoing unrest in the Kingdom. The National Oil and Gas Authority (Noga) released the updated figures in its annual report for 2011. Bahrain's annual imports of Saudi crude oil for refining topped 79.263mn barrels last year. The annual output of crude oil from Abu Sa'afa field topped 53.936mn barrels last year.

The Noga 2011 statistical survey also reported an output of 15.516mn barrels from Bahrain Oil Field. Tatweer Petroleum Company has succeeded in increasing the output of crude oil from Bahrain Oil Field by up to 50 per cent since its inception in 2009. The Gulf Petrochemicals Industries Company reported an all-time high output of urea. The Bahrain National Gas Company's output of propane, butane and naphtha also soared by 4.3 per cent compared with 2010 results.

Bahrainâ&#x20AC;&#x2122;s refining plans have been unaffected by the unrest

Overall local sales of oil by-products topped 8.787mn barrels, with airport sales reaching 4.604mn barrels.

Sabic starts work on technology centre SAUDI BASIC INDUSTRIES Corporation (Sabic) has begun work on a US$100mn technology centre in Shanghai, focusing on alternative energy and new materials for the construction and auto sectors. Sabic's chief executive Mohamed Al Mady said the centre would focus on helping design and create next generation alternative energy vehicles. It is part of a wider expansion that includes a polycarbonate production complex in Tianjin, a city in northeastern China as part of its joint venture with Sinopec, Asia's biggest refiner. The company, which manufactures fertilisers, metals and polymers, has seen strong sales and solid profits on the back of higher oil prices. Sabic is one of the world's largest chemical producers and its investments in China are part of a bigger energy partnership that includes a buildup of jointly run refineries as well as petrochemicals plants. The development of China's electronics, automotive, building

38 Oil Review Middle East Issue Four 2012

materials and new energy sectors is boosting demand for polycarbonates and other engineering plastics. China produced only 220,000 tonnes of polycarbonate in 2010, importing most of the 1.13mn tonnes consumed by its industries. Even as China's growth slows, its national economic plans call for nurturing various 'new industries' such as renewable energy and electric vehicles. 'Material sustainability is key to the creation of new applications across industries,' Saudi Prince Saud bin Abdullah bin Thenayan Al Saud said during the Shanghai groundbreaking ceremony. The new research centre, in Shanghai's developing research hub of Kangqiao, will share Sabic's research, design and production capacity with Chinese industries, he said. With environmental sustainability in mind, the centre will be built with the highest global green standards in line with the guidance by the Leadership in Energy and Environment Design Gold Certification.

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vulnerability to the frequent fluctuations in crude oil prices. This exposure to economic instability has driven many countries to attempt to diversify their sources of income by establishing petrochemical industries. Diversification away from oil is key

The regionâ&#x20AC;&#x2122;s basic petrochemical industry was boosted at the start of the decade when producers began receiving ethane feedstock at subsidized prices, which led to lower production costs, making the Middle East the hub of the global basic petrochemical industry. Continuous government support has seen foreign investments welcomed and higher efficiency achieved through the integration of petrochemical operations with

refinery operations previously under government control. During 2000-2011, the basic petrochemicals capacity in the Middle East reached 46.61 MMtpa, growing at a CAGR of 11.1 per cent. A strong basic petrochemical industry will serve as a feedstock provider for the downstream industry, with its cost advantage directly transfered to the downstream industry. The focus on the downstream petrochemical industry will also help the Middle East to offset the competition it faces from China in the basic petrochemical market, which is currently suffering from over-capacity. The Middle Eastern plastics processing industry will be a big winner from its drive to diversify its economy. While the region has a thriving plastic resin production market, its plastic processing industry is very small and scattered. To encourage domestic processing, many countries in the region plan to start cluster programs, which will allow plastics processors to establish a unit in a polymer park.

Oil Review Middle East Issue Four 2012 39

Petrochemicals

Oil loses out to plastics as region diversifies THE MIDDLE EAST is seeking a gradual movement away from its dependency on oil and gas production to diversify its economy and create a positive environment for the development of its plastics industry, according to a new report by industry intelligence company GlobalData. The new report* suggests that the region has been witness to the emergence of an impressive petrochemicals industry in the last decade, which is now the most competitive in the world thanks to its lowcost feedstock advantage. However, the region is now taking steps to establish a stronger downstream petrochemical industry, attempting to replicate this previous success in order to achieve even higher profits. The region has long sought diversification in its economies, which are extremely dependent on oil production and exports. Many countries derive a significant portion of their gross domestic product (GDP) from petroleum exports, and dependency on the oil sector has led to their

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SPE POCE

Meeting global energy demand is the secondary theme for this year’s SPE Production & Operations conference/exhibition in Qatar.

Meeting global

energy demand R

ECENTLY ANNOUNCED AS the event’s ongoing home, the SPE’s biennial International Production & Operations Conference & Exhibition (POCE 2012) runs from 14-16 May in the Qatar National Convention Centre. POCE alternates every other year with the Society of Petroleum Engineers’ PO Symposium in Oklahoma. With a huge programme of events in many countries SPE is easily the world’s largest international organisation for oil/gas engineers, managers, scientists and other professionals. Headquartered in Texas it operates locally out of Dubai (contact details below). All events including the associated specialised exhibition this year are being hosted by the local NOC, Qatar Petroleum – which of course has many international interests - and sponsored by Afren, ConocoPhillips, Saudi Aramco and Total. All take place under the patronage of the Energy & Industry Ministry and its head, HE Dr Mohammed Saleh Al Sada. The main conference theme – there will be nearly 30 technical presentations in all, precisely timetabled on the relevant “Schedule Overview” page of the website and detailed much further elsewhere – is listed as Production optimisation challenges. Total attendance of around 1200 delegates in all is confidently expected at the four simultaneous tracks arranged by SPE, which broadly cover: 6 Production optimisation 6 Process optimisation 6 Facilities management 6 HSEQ and sustainable development The whole three-day sequence of events including additional incorporated midway Poster Sessions is being chaired this year by the local NOC’s Director of Operations, Said Mubarak Al Mohannadi. The conference itself commences with a series of all-day training courses offered on the 13th; delegates pay fees according to their participation in a wide range of optional features like these which also include local field trips on this day. The six training themes on offer this year cover: 6 Introduction to geomechanics in E&P 6 Artificial lift systems overview 6 Maximising cased hole asset integrity 6 Basic oil field corrosion and control via chemical solutions 6 Well stimulation – Past, present and future challenges 6 Transient well testing

40 Oil Review Middle East Issue Four 2012

http://www.spe.org/events/poce/2012/

The neatest way to sum up the whole events’ multiple themes under the overall optimisation banner is to list and detail in brief the individual Panel Sessions which will front each major division of the active session days available. Most details of panellists appearing can be found on the website under ‘schedule/panel_sessions.php’ On the 14th these will cover ‘Redefining NOC/IOC/service provider relationships’ and ‘Human capital development’ (both in the pm slot). SPE points out in its pre-conference briefing material that relationships between service providers and client companies have been “redefined as the respective power and levers have been redistributed” by the change in market conditions. “Both production and service companies need to collaborate with universities and other educational institutions to attract new students … and further train and develop those who are already working in the industry.” This is a worldwide problem from which the Middle East is certainly not immune. Tuesday’s sessions will be on the optimisation sub-themes of ‘Strategies and technology for fasttracking field development’ (10.00hrs-11.30) and ‘Operations and maintenance strategies to optimise value’ (13.30-15.00hrs). This pair of sessions will examine the problems that arise from increasing reliance being placed on tight gas, shale gas and HPHT reservoirs, for which “technology is evolving quickly and bringing a new

dimension to overall drilling, completion and stimulation strategies” with a necessary emphasis as always on the multi-disciplinary approach. Other difficult operating environments will be addressed in the second of these sessions which will try to solicit the appropriate different approaches, techniques, tactics and strategies applied by both operators and service companies alike. The final day’s single panel session (am) will cover ‘Carbon management: Problem and opportunity’. This team will look at current global and regional efforts to regulate emissions of carbon dioxide and explore the technologies being developed to capture and store this greenhouse gas in a way that will not break the bank. The topics covered will include the recently developed unorthodox prospects for moving carbon around the world in converted LNG and LPG vessels, but all the traditional solutions such as on-site underground storage in depleted reservoirs will be dealt with, too. In short, if optimisation of either production or processing is your professional field within any branch of the oil and gas industries then this year’s SPE POCE events in Doha are the ones to attend, with the facility for choosing and paying for precisely the information package that suits your needs. ■

For more information visit www.spe.org/events/poce/2012 or call the Society in Dubai on +971 4 457 5800 (spedub@spe.org)

S10 ORME 4 2012 SPE - MEP_Layout 1 04/05/2012 10:34 Page 41

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S10 ORME 4 2012 SPE - MEP_Layout 1 03/05/2012 14:38 Page 42

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S10 ORME 4 2012 SPE - MEP_Layout 1 03/05/2012 14:38 Page 43

Established in 1996, Middle East Petrotech attracts over 3,100 visitors. All aspects of refining and related activities are being addressed at this year’s show

SPECIAL SUPPLEMENT MEP 2012

Leading downstream event

returns T

HIS YEAR’S EDITION of the biennial Middle East Petrotech Conference & Exhibition takes place in Bahrain from 20-23 May (the exhibition opens on the May 21st). As usual all aspects of downstream activities in and beyond the Gulf will be covered. Details of the technical conference were being finalised as we went to press (visit www.mepetrotech.com, more than 100 technical presentations are expected) but the key themes to be covered by the 8th Middle East Refining & Petrochemicals event will include: Refining and petrochemicals technologies: Local and global business opportunities abound, and their examination highlights the impact of globalisation in all downstream activities. Developments in downstream technology are designed to create added value. “To leverage these,” the conference organisers say, “the refining and petrochems industry demands suitable technologies for higher efficiency and lower energy demands, better utilisation of raw materials and equipment, improved corrosion control, and cleaner fuels/the environment. “New technologies, improvements in existing ones and proven process systems will provide the means to address the increased competitiveness experienced in the refining and petrochemical industries.” Investing in plants of the future: Population and more energy-intensive lifestyles will predictably lead to increased demand for fuels. So investing in downstream facilities brings challenges that the industry is constantly addressing. “The refining and petrochemical industry is always seeking investments in new and innovative technologies to gain a competitive edge and create additional value.” Locally and globally a large number of brand-new facilities are incorporating the latest technologies and “tweaks” that will provide advantages in product yield, higher reliability/availability, lower energy use and an altogether cleaner environment. Developing people utilising world-class HR processes: High product demand and industrial expansion in MENA coupled with an ageing workforce “results in the need for effective and innovative approaches for developing high performers throughout our organisations.” Key to

www.mepetrotech.com

The 2010 combined event attracted more than 120 exhibiting companies from 24 countries in all, with a total exhibition attendance of 2,400 success with this worldwide phenomenon will be the ability to transfer knowledge efficiently to the required large numbers of new local employees, over the next five years at least. New methodologies in operations, maintenance and engineering will be needed, involving new approaches to training, motivation, developing collaborative teamwork and appropriate leadership styles. Themes that will be discussed at this conference will include world-class HR processes, sharing of case studies and examples of best practice, and standards of HR development generally.

Downstream industry best practices in Health, Safety and the Environment: Effective HSE management systems are essential to the survival of any company involved in downstream activities or their supply. “A company’s most valuable assets are its people,” the organisers say. “In all areas voluntary performance improvement beyond compliance is becoming the rule rather than the exception … companies continue to strive for that ‘next level’ of performance. “You are invited to share best-practice approaches in all areas of HSE.” To support these major themes with their associated introductory plenary sessions there will be keynote speeches delivered by Bahrain’s Energy Minister and Kuwait Petroleum’s CEO; in addition a special appearance will be made by the well-known Futurist Dr Graeme Codrington, addressing delegates on ‘The new world of work’. Important addresses will be made by senior representatives of the local NOC Bapco, Saudi Aramco, Qatar Shell GTL, Honeywell Process Solutions and a host of other well known names from the industry, commerce and the downstream-related institutions.

Oil Review Middle East Issue Four 2012 43

S10 ORME 4 2012 SPE - MEP_Layout 1 03/05/2012 14:38 Page 44

MEP 2012

SPECIAL SUPPLEMENT The 2010 combined event attracted more than 120 exhibiting companies from 24 countries in all, with a total exhibition attendance of 2,400. In addition there were nearly 750 delegates who attended the technical conference. Attendees from the Kingdom itself and across the King Fahad causeway in Saudi Arabia where so much of Bahrainâ&#x20AC;&#x2122;s refining business emanates, outnumbered all the rest by a wide margin. Visitors expected this year include senior oil/petrochemical managers, engineers of all sorts, R&D specialists, project construction managers, safety and HSE personnel. Conference Chairman Abdulaziz M. Al-Judaimi, VP/Chemicals at Saudi Aramco, describes this yearâ&#x20AC;&#x2122;s events as the â&#x20AC;&#x153;most prestigious refining and petrochemicals conference and exhibition in the regionâ&#x20AC;?, an â&#x20AC;&#x153;exceptional networking, business and educational event [which] offers something for everyone interested in the future of the Middle Eastâ&#x20AC;&#x2122;s downstream hydrocarbon industryâ&#x20AC;?. Referring to the importance of downstream activities generally the organisers point out that globally a â&#x20AC;&#x153;long list of refining projects, totalling almost 9mn bpd of distillation capacityâ&#x20AC;? are currently slated, with the Middle Eastâ&#x20AC;&#x2122;s slice of this active engineering and construction business amounting to 1.6mn. The time frame cited for this is 2010-2015. Notable local announcements include no less than three brand-new plants across the border by Saudi Aramco (at Jubail, Yanbu and Jazan). In addition, SABIC and ExxonMobil are progressing an elastomers project at the first of these locations. Under the â&#x20AC;&#x153;expansionâ&#x20AC;? category they list phase II of the Kingdomâ&#x20AC;&#x2122;s Petro Rabigh complex, phases V/VI of Qafcoâ&#x20AC;&#x2122;s ammonia-based fertiliser expansion, and the nearby second phase of QPCâ&#x20AC;&#x2122;s Ras Laffan refinery. In the UAE, phase III of Borougeâ&#x20AC;&#x2122;s Ruwais is being progressed, while in the east Omanâ&#x20AC;&#x2122;s Octal Petrochemicals PET plant is being expanded. And of

Bapco's refinery

course Bapco itself is expanding its own refining operations. In short, as the organisers Arabian Exhibition Management point out, â&#x20AC;&#x153;This wave of investment in the Middle East is creating a wealth of business opportunities for suppliers and partners.â&#x20AC;? The eighth ME Petrotech, the 'ideal meeting place for the oil and gas industry', is where the latest technologies and innovations will be heard about first. â&#x2013;

Most details are on the website cited but for more information call Arabian Exhibition management/Allworld Exhibitions on +973 17 550033 or Overseas Exhibition Services on +4420 7840 2137

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S11 ORME 4 2012 Petrofac_Layout 1 03/05/2012 14:39 Page 45

S11 ORME 4 2012 Petrofac_Layout 1 03/05/2012 14:39 Page 46

Petrofac Review

One of the world’s largest oilfield services groups, Petrofac has carved out a special niche for itself in the Middle East.

A smooth operator consolidates

its regional presence T

HE UK-LISTED COMPANY, which now ranks among the FTSE 100, a measure if its impressive growth over the past decade, has paid special attention to the oil-rich Gulf region. And in recent years this has meant targeting new business potential in an emerging Iraq, where upstream business is now moving at pace. In 2010, it began working for Shell on the mighty Majnoon field development. The company is also part of a team working on an inspection, maintenance and repair job at the super-giant Rumaila oilfield. This field, dubbed Iraq’s ‘workhorse’, accounts for nearly half the nation’s crude oil output. Then, in February, Petrofac consolidated this growing position in Iraq by landing a US$330mn project for Gazprom at the Badra oilfield. The lump-sum engineering, procurement and construction contract - its first lump-sum EPC project in the country - is due to be completed in the second half of 2015. Petrofac’s senior management still see immense potential in this aspiring market.

“Iraq represents a sizeable market opportunity for Petrofac,” said Marwan Chedid, chief executive of the group’s Engineering, Construction, Operations & Maintenance (ECOM) division, after announcing the Badra contract, “and our Basra office is continuing to expand as we develop our presence in the country.”

Global presence But it is not just Iraq and the Gulf where this multinational operation has a presence in the Middle East region. In 2011, one of the company’s highlights was the completion of the Jihar gas plant in Syria,

Petrofac has also won praise among regional oil companies for supporting the advancement of local personnel Petrofac’s business offering spans the full spectrum of oilfield services

46 Oil Review Middle East Issue Four 2012

among other assignments across the wider North Africa region. Petrofac is ultimately, however, a global concern, with 31 offices around the world housing more than 15,000 employees. It’s an impressive track record for a firm that began in 1981 with just 25 staff. Since then, over 30-plus years, it has matured greatly, responding well to the changes and challenges of the world’s energy markets. The company’s seven operational centres perhaps reflect its general growth curve, with two located in the UK (Aberdeen and Woking) - the company remains very active in the North Sea two in the Gulf (Sharjah and Abu Dhabi), and the rest scattered across Asia (Chennai, Mumbai and Kuala Lumpur). These offices have aided the group’s push into additional energy markets such as Iraq, but many others as well including Turkmenistan in Central Asia, and Mexico, underlining its global presence, and ultimate roots back in North America. The original Petrofac founding company, in 1981, was established as a producer of modular plant in Texas.

High growth This realignment with high growth markets in the Middle East and Asia, underscores how the modern Petrofac has prospered since its origins. And business is still booming. For the year ending December 31, 2011, the company netted revenues of US$5.8 billion, up by a third on the previous year. Net profit also climbed 25 per cent to reach US$539.4mn. This year, the company said it expects to see net profit grow once more by at least 15 per cent, targets that will shore up its position among the energy services elite. Petrofac’s business offering also spans the full spectrum of oilfield services, making it well placed to support even the largest energy projects, which it is now doing in Iraq and beyond. A restructuring in 2011 split the group into two core divisions: Engineering, Construction, Operations & Maintenance (ECOM) and Integrated Energy Services (IES). The largest business segment, in terms of revenues, is onshore engineering and construction, which dominates sales. With a strong pipeline of new bidding opportunities, management are optimistic that this strong growth story will continue for some time yet.

S11 ORME 4 2012 Petrofac_Layout 1 03/05/2012 14:39 Page 47

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S11 ORME 4 2012 Petrofac_Layout 1 03/05/2012 14:39 Page 48

Petrofac Review

Petrofac is working throughout the region

Gulf focus Despite its global footprint, Petrofac has become synonymous with the Middle East’s oil-rich Gulf, where it continues to expand. For the most part in this core territory it remains business as usual, despite upheaval in some markets, notably Syria. Last year, for instance, the company continued its work on the huge onshore Asab oilfield project in Abu Dhabi, for the Abu Dhabi Company for Onshore Oil Operations (ADCO). The US$2.3 billion project spans a vast area measuring 40-km x 20-km, and faces key natural challenges such as the extreme heat, fog and frequent sandstorms, as well as tremendous logistical issues, with 14,000 on-site staff and contractors. The company is also active on the NGL4 integrated gas development project for ADCO. Indeed, one of Petrofac’s primary strengths is its strong relations with the region’s leading national oil companies, such as ADCO. It is also working closely with the likes of Qatar

Petrofac is ultimately, however, a global concern, with 31 offices around the world housing more than 15,000 employees Petroleum, where it is in the middle of a multi-year consultancy assignment.

New partnerships As well as teaming up with the region’s biggest national oil companies, Petrofac has also formed a number of key strategic joint ventures with other partners. Last September, for example, it teamed up with China Petroleum Engineering & Construction Corporation (CPECC), the engineering and construction subsidiary of China National Petroleum Company (CNPC). The new entity, China Petroleum Petrofac Engineering Services (CPPES), is based in Sharjah,

and will support Chinese oil and gas companies working in the Gulf region. The two are already working together on southern Iraq’s Rumaila field, which is being jointly developed by BP and CNPC. Petrofac has also won praise among regional oil companies for supporting the advancement of local personnel in the Middle East, a key priority in major oil producing states such as Saudi Arabia. In the world’s biggest oil producing kingdom Petrofac supports a number of sponsorship programmes, a part of its corporate social responsibility agenda. Away from the Gulf, it is also investing in local talent in areas where it has a presence. Prior to the current turmoil in Syria, Petrofac established a state-of-the-art technical training centre for the oil and gas sector, the first of its kind in the country, with the intention of providing training to workers from the General Petroleum Corporation. With the company’s services in high demand, the partnership strategy is clearly paying off. ■

Petrofac celebrates Saudi graduates PETROFAC SAUDI ARABIA and the Asharqia Chamber of Commerce Training Centre in Dammam held a graduation ceremony on 31 March for 80 young Saudi trainees who have successfully completed the 2011-2012 training programme in human resources management fundamentals. Under Petrofac’s sponsorship the Chamber delivered the course to students, most of whom were high school graduates. Graduating student, and recipient of the award for superior trainee, Ibrahim Fouad Al Madloh, described the training as “very helpful because I will really add value to my employer’s company and help my colleagues.” Nouf Abdulkarim Abdulaziz Alfayadh received the award in the women’s group. Both were presented with i-Pads courtesy of Petrofac Saudi Arabia. Senior Vice President and general manager for Petrofac’s Saudi Arabia operations, Imad Shanan, noted “We are proud to sponsor this future generation of leaders and pleased to partner again with the Asharqia Chamber. In Saudi Arabia we are strongly committed to our corporate social responsibility agenda, and this programme supports our activities in that respect.”

48 Oil Review Middle East Issue Four 2012

Receiving the award for superior trainee is Ibrahim Fouad Al Madloh (centre) from Imad Shanan, senior vice president and general manager for Petrofac’s Saudi Arabia operations (left) and Bashar Ghrawi (right) home office manager.

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Oil Review Middle East Issue Four 2012 49

S12 ORME 4 2012 QP_Layout 1 03/05/2012 14:41 Page 50

The company is moving into more sophisticated downstream areas

QP Review

After breaking all the LNG records in recent years Qatar Petroleum is still firing on all cylinders.

The king of gas continues

to expand G

AS-RICH QATAR HAS weathered well the storm of the 2008 global financial crisis and its ripple effects thereafter. This tiny Gulf state - which will host the FIFA World Cup in 2022, just a decade from now remains one of the world’s fastest-growing economies, outstripping even mighty China. Behind this success is the nation’s vast gas pool, much of which sits in the offshore North Field, the world’s largest gas field, which straddles the border with Iran (where it is known as the South Pars field). Oil and gas exports account for about half of Qatar’s gross domestic product (GDP). The nation’s state-owned energy champion Qatar Petroleum (QP) has been instrumental in co-ordinating the development of this high value resource. Through its multiple subsidiaries - which span niches areas from drilling and services through to catering and insurance - it has pioneered in the export of liquefied natural gas (LNG) and other related areas. Increasingly, this includes moving into more sophisticated downstream areas, from refining and shipping, through to advanced petrochemicals. And it is generating continued wealth for the state and helping to consolidate Qatar’s position on the world map.

Cracking on The latest large-scale venture to get the go ahead from the group’s Doha headquarters is a new, mega-petrochemical complex in Ras Laffan Industrial City. It will be led by QP and Qatar Petrochemical Company (QAPCO) - a joint venture between Industries Qatar and Total of France - and includes a world-scale steam cracker, with the feedstock coming from natural gas plants in Ras Laffan. QP will hold an 80 per cent stake in the US$5 billion project, scheduled for completion in 2018, with QAPCO taking 20 per cent. It will produce 1.4mn metric tons per annum (MMTA) of ethylene, 850,000 metric tons per annum (KMTA) of high-density polyethylene (HDPE), 430 KMTA of linear low-density polyethylene, 760 KMTA of polypropylene and 83 KMTA of butadiene, mainly for high-growth emerging markets, such as Asia.

50 Oil Review Middle East Issue Four 2012

QP chairman and managing director, Dr Mohammed bin Saleh al-Sada - also the nation’s energy minister - called it “an important milestone” in the development of Qatar’s petrochemicals industry. “This mega-project is yet another major step in our progress towards sustainable development of Qatar’s vast hydrocarbon resources,” he said.

But not all of Qatar’s efforts are focused on export markets Downstream development The new QAPCO project is just the latest major downstream venture to be unveiled by QP. Sada said at the start of the year that Qatar will spend US$25 billion on expanding its domestic petrochemicals industry over the next decade.

There are plans to more than double the country’s annual petrochemicals production capacity from 9.2mn tonnes now to 23mn tonnes by 2020. Last December, Qatar signed a deal with Shell to develop a US$6.4 billion petrochemicals complex, also at Ras Laffan. It will produce mono-ethylene glycol and linear alpha olefin, mostly for export to Asian markets. Sada said at the time plans for additional petrochemical plants in Qatar were in the pipeline. QP is also expanding its footprint in overseas markets too with the company’s international arm, Qatar Petroleum International, recently forming a joint venture with Petrovietnam to build the US$4-billion Long Son petrochemical project in Vietnam. This year will also mark the full start-up of the flagship Pearl gas-to-liquids (GTL) project, in partnership with Shell. This mammoth undertaking - Qatar’s largest single foreign investment project ever pushes GTL technology into a new commercial stratosphere.

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QP Review

“Therefore, the projects' production would need to be curtailed,” Fitch stated in a research note. For Nakilat, a Hormuz closure would likely be classified as force majeure, which means charterers would be obliged to continue paying hire charges for at least 24 months, at which point the time charter might be eventually terminated. Debt servicing for all project firms should be secure for at least six months, the agency reckons, while insurance may provide some additional cover.

Domestic demand

www.qp.com.qa

LNG leadership But QP is perhaps best-known for its dominance in the LNG sector, where it has positioned itself as a clear market leader in recent times. Qatar now hosts multiple liquefaction trains, through various joint ventures with foreign partners, notably US super-major ExxonMobil. QP’s Qatargas and RasGas brands - both based in Ras Laffan Industrial City - are two names that are now synonymous with the global LNG trade. Qatargas, established in 1984, is the largest single LNG producer in the world, with an annual production capacity of 42mn tonnes per annum (mta). Just over a year ago, Qatar put the finishing touches to its huge LNG expansion plan crafted more than a decade earlier that has now left it with a combined production capacity of 77mn tonnes per annum. And business is booming: in 2011, a record number of LNG tankers loaded at Ras Laffan port. On December 28, the RasGas chartered vessel, ‘Simaisma’, became the 1000th LNG tanker to arrive in the port that year, loading a cargo of 146,000 cubic metres of chilled gas. The rise of Qatar’s gas export business has stimulated investment in associated areas too such as shipping and transport. The Ras Laffan port itself is a major accomplishment, with six operational LNG berths, making it the world's premier LNG export and loading facility. At times, all six berths are occupied with tanker vessels loading LNG cargoes for various destinations around the globe. Not surprisingly, QP’s gas shipping arm, Nakilat, is also now the world’s biggest LNG transporter. The company owns vessels in its own right and in partnership with other shippers - the ‘Simaisma’, for example, is owned jointly with another firm, Maran Gas Maritime.

52 Oil Review Middle East Issue Four 2012

Nakilat-owned vessels now represent about 16 per cent of the global LNG tonnage, with 54 ships of various sizes, including the giant Q-Flex and Q-Max classes, which were specially constructed to ship Qatar’s LNG to the far distant world markets. These ships are testimony to QP’s appetite to push the frontiers of energy technology.

But QP is perhaps best-known for its dominance in the LNG sector, where it has positioned itself as a clear market leader in recent times Qatar vulnerable While this boomtown economy shows no signs of slowing down just yet, there are potential threats to the country and to QP itself. Qatar’s big gas companies stand to lose most should there be any blockage in the narrow Strait of Hormuz arising from Iranian tensions, analysts reckon. According to ratings agency Fitch Ratings, any protracted closure would materially affect the operations of rated energy issuers, although debt servicing would not be affected in the short term because of significant cash reserves. RasGas and Qatargas are reliant on access to the Strait, while a large portion of Qatari LNG is also shipped through vessels owned by Nakilat, another Fitch-rated issuer. The severity of the impact of a closure of Hormuz on these companies would depend on its duration. While there are storage facilities at Ras Laffan offering some operational flexibility, these are not designed to cope with low-probability high-impact events, such as the closure of export routes.

Although this scenario is deemed low probability by experts it does remain an underlying threat, with tensions over Iran’s nuclear programme still running high. But not all of Qatar’s efforts are focused on export markets. While QP has triumphed in exploiting Qatar’s gas potential for the international market - and continues to generate added value for the economy through the move into more advanced downstream projects - it is also playing a key role in meeting rising local needs. Demand for energy in Qatar is tipped to grow rapidly over the next decade as a new airport and seaport are built, and as major initiatives are completed in the transport, health and education sectors. New facilities are also being built for the FIFA World Cup that will further drive demand. In January, QP teamed up with ExxonMobil for the Barzan gas project, which will play a major role in satisfying this rising domestic gas need. The drilling platform to supply the Barzan plant will be sited 80-km north-east of Ras Laffan Industrial City, with onshore and offshore facilities to be completed by JGC of Japan and Hyundai Heavy Industries of South Korea respectively. The Rasgas-led project is to be developed in two phases: Train 1 will come on stream in 2014, with Train 2 following in 2015. Together they will supply around 1.4 billion standard cubic feet per day of sales gas, much of which will be directed to the domestic power and water sector. When fully operational, the total offshore production from all RasGas facilities will reach 11 billion standard cubic feet per day (the equivalent of almost two million barrels of oil), making RasGas Qatar’s largest single gas producer.

Qatarisation But one of QP’s most important responsibilities domestically, however, is in providing employment to locals and to build the skills base needed to create a more sustainable oil and gas industry in the long-term. Much of Qatar’s gas sector has grown on the back of expertise from abroad, with large

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company from finance and business planning, human resources and corporate training to gas operations, research and technology, engineering and oil development.

Refineries boost In the refineries sector, QP is leading expansion work at the Laffan Refinery, to bolster local fuels production and provide additional products for export. Qatar’s first condensate refinery, the Laffan project started production in 2009, with a capacity of 146,000 barrels per day (bpd), with products including naphtha, kerojet, gasoil, and liquefied petroleum gas (LPG).

It utilises the field condensate produced from both Qatargas and RasGas facilities. A second refinery, Laffan Refinery 2, is expected to launch in 2016, to process an additional 146,000 bpd, effectively doubling output. Other Laffan Refinery shareholders include ExxonMobil, Total, plus Japanese companies Idemitsu, Cosmo, Mitsui and Marubeni. This, and other key initiatives, will generate further employment for locals, and provide additional fuels support to meet Qatar’s own growing needs. Critically, such expansion and development projects will help to underpin supply for the everhungry international energy market. ■

GDI leads Qatar drilling segment AS QATAR EXPANDS its upstream oil and gas industry, QP is moving fast to develop critical oil services infrastructure, including drilling support services. Its Gulf Drilling International (GDI) unit, formed as a joint venture with Japan Drilling Co., Limited, is already a leading supplier of rigs in the country, but looks set to expand its market presence further, with growth firmly on the agenda. In April, GDI placed an order for a new Pacific Class 400 jack-up rig with PPL Shipyard Ltd in

Singapore, the third jack-up order in 12 months. The US$250mn unit, scheduled for delivery in March 2013, will be able to operate in water depths of up to 400 feet and drilling to depths of 30,000 feet. According to GDI, it will be the most technologically advanced drill rig operating in Qatar, and will come with accommodation for 150 people. The order marks the next step of a US$875 million business expansion that will result in GDI

adding three new jack-ups, two land rigs and two jack-up accommodation barges to its fleet over the next three years. By 2014, the QP company will have eight offshore rigs in service, with five being of the ultra modern cyber variety, and six land rigs. Based on current rig counts, GDI’s share of the Qatar offshore market will exceed 50 per cent while its share of the onshore fleet will remain at 100 per cent.

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QP Review

numbers of expatriate workers still playing a vital role across all strands of the industry. QP now offers countless openings for Qatari university graduates, for its operations in Doha, Dukhan, Ras Laffan, Mesaieed Industrial City, as well as offshore, and has a full range of technical and scholarship programmes for high school graduates. Those under the programme study inside or outside Qatar to take up any of the covered degrees, which include most of the engineering disciplines such as electrical engineering, civil engineering, petroleum and gas engineering and mechanical engineering. Subsequent job openings stretch across all the disciplines within a large national oil and gas

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QP Review

10 years without lost time incidents

A significant milestone

Qatargas loads 1,000th cargo QATARGAS HAS ACHIEVED yet another significant milestone with the loading of the 1000th LNG cargo from the Common Lean LNG Storage and Loading Asset. The cargo, bound for Elba Island, Georgia, USA, was safely loaded from LNG Berth 4 on the Q-Flex LNG vessel “Al Khattiya” in March. The Common Lean LNG storage and loading facilities are built to store LNG produced from the six mega trains at Qatargas (Trains 4, 5, 6 and 7) and RasGas (Trains 6 and 7) and load Q-Flex and Q-Max ships in addition to conventional ships from Berths 4, 5 and 6 and the Qatargas ships loaded at LNG Berth 3 to customers across Asia, Europe and the Americas. The milestone achievement was reached in less than three years after the first loading from the facility. The Qatargas Q-Flex vessel “Al Hamla” was the first ship to load lean LNG from Berth 4 on 15th March 2009 during the Expansion Start-up stage. In October 2009, the Qatargas Q-Flex vessel “Al Kharaitiyat” became the first ship to load lean LNG from Berth 5, while the first ship to load lean LNG from Berth 6 was the RasGas Q-Flex vessel “Al Sahla” in February 2011.

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QATARGAS HAS COMPLETED ten years of operations on its offshore facilities without a Lost Time Incident (LTI) - a significant milestone demonstrating the company's outstanding safety performance. This world class performance across the entire offshore facilities and operations is the result of the continuous and proven commitment to safety, by the company's leadership and workforce. Expanding from a three to a nine platform facility, Qatargas Offshore facilities supply gas and condensate to the world's largest LNG plant onshore, with a production capacity of 42mn tonnes per annum (MTA) of Liquefied Natural Gas (LNG). The Qatargas offshore facilities are outstanding not only in terms of safety record, but also from a reliability perspective, ensuring sustained production of LNG from Qatargas' onshore plant. A brief ceremony was organised at the Qatargas offshore facilities to mark the occasion and congratulate the Offshore team on this achievement. The ceremony was attended by Sh. Khalid Bin Khalifa AlThani, Qatargas Chief Executive Officer, Ghanim Al-Kuwari, Chief Operating Officer - Administration, Sh. Khalid Bin Abdulla Al-Thani, Chief Operating Officer - Engineering & Ventures, Mats Gjers, Chief Operating Officer - Operations, Toufik Benmosbah, Chief Safety, Environment & Quality Officer and Abdelkader Haouari, Offshore Operations Manager. The Qatargas offshore facilities are located approximately 80 kilometers northeast of Qatar's mainland. A total of 85 wells together supply approximately 7.5 billion standard cubic feet of gas to the seven LNG production trains onshore. The gas, along with the associated condensate is transferred to shore via subsea pipelines.

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Business is booming in the world’s largest cluster of gas-related activities.

Ras Laffan

Ambitious developments raise

Qatar’s profile T

WO NUMBERS ARE prominently on display in Qatar’s busy capital, Doha, these days. The first is ‘77’ which stands for the nation’s total export capacity tonnage (millions of course) for liquefied natural gas (LNG). Better known overseas, the other is the year 2022. Both are closely related to the development of Ras Laffan Industrial City (RLIC). Founded by Qatar Petroleum, the multipurpose 300 km2 development is already renowned as the world’s largest concentration of industries and services based on natural gas. It sits almost on top of the North Field, the single largest non-associated gasfield anywhere, just 80-km northeast of the modern capital. Two huge LNG producers, Qatargas and RasGas, are located side-by-side adjacent to the world’s busiest LNG exporting port. The two-plants/twooperators gas-to-liquids industry is growing fast; details are given below. An important condensates refinery and olefins facility lie just across the road. We counted no less than three combined power/desalination plants operated by the national utility Kahramaa. Shipping-related engineering and services businesses proliferate. And light industry facilities in the neat surrounding township are growing fast, too.

www.raslaffan.qp.qa

That’s where the relevance of the year 2022 to RLIC comes in. A vital part of the bid to host the 2022 FIFA World Cup – global soccer’s four-yearly jamboree – was to offer the football world more than 10 state-of-the-art stadiums that

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Ras Laffan

Ambitious plans are underway

would be fully carbon-neutral in operation. A very tough challenge for a huge international event in one of the world’s hottest and driest climates, and at the height of summer, too. Massive arrays of photovoltaic panels on the roofs of the air-conditioned facilities were offered as the solution, and many of these will be manufactured in RLIC by newly established institutions such as Qatar Solar Industries. These will be the foundation of a major new export-capable industry for the future, all part of the Emirate’s plans via the Qatar Foundation for advanced science-based national status, based on a knowledge-based economy. There are plenty of signs of this in and around the bustling capital already.

Lucrative LNG, the product on which RLIC’s fortunes have been founded, started being produced just a decade and a half ago; by 2010 over 75 bn m3 was being exported annually, which is more than twice the amount sent out of any other world gas port. And it’s all taken place despite the impact of the shale gas revolution on the availability of the world’s increasingly favoured fuel. The value of frozen gas exports, mostly on lucrative long-term contract terms so far, although this is changing, exceeded those of crude oil for the first time in 2009. RLIC is also the location of the processing station for the undersea piped exports which are sold via Dolphin to the gas-poor UAE. Behind the City’s ambitious development plans lies a 20-year Master Plan which involves a complete overhaul of the already modern port facilities and all necessary support services. A moratorium continues in place on future development of gas exploitation, which means no more LNG trains are expected to be announced at present, but debottlenecking is proceeding actively at some of the older trains to increase export capacity even further as global demand increases – and Qatar’s reputation for reliability does the same. At the same time Nakilat (the Qatar Gas Transport Co) is building new construction, repair and maintenance facilities within the RLIC port boundaries for its dedicated fleet of gas carriers and service vessels, now the world’s largest.

Prospects Shell is expected to ramp up output to the full 140,000 bpd nameplate capacity within the year at Pearl, the world’s largest gas to liquids plant. Also turning out 120,000 bpd of condensates and bottled LPG this landmark facility sits right next door to the earlier, smaller but still highly profitable Oryx plant jointly owned by Qatar Petroleum with the alternative technology developer, South Africa’s Sasol. Slightly different processes are employed to produce the same ultraclean synthetic fuel; Oryx was the world’s pioneer commercial-scale GTL plant. RLIC’s commercial and industrial status has so far rested largely on the soaraway LNG industry outlined above, but it is the prospects for GTL and its many derivatives that the experts are most

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excited about for the future. The City is already the world’s leading production centre for this newgeneration commodity by a wide margin. The new downstream intermediary was used to most dramatic effect when the national airline made its first commercial flight with kerosene/GTLderived fuel back in 2009. Further commercialisation prospects are excellent in an energy-hungry world where diesel in particular is in regular short supply while gas reserves are overflowing, and are in many cases difficult to commercialise economically. Other uses include specialised lubricants and other mineral-substitute oils, and as an economic feedstock for various petrochemical products. As familiarity with the intermediate product and its possibilities grows no doubt further uses will be found, and a futures market could develop. Apart from helping preserve the environment, one of the special advantages of GTL-based diesel in particular is that it can be distributed via conventional road-fuel networks, unlike the alternative environmentally-friendly bio products which also, allegedly, require costly engine modifications. Automobile manufacturers are very excited about GTL indeed, and RLIC is now the world’s number-one source of supply. Oryx was undoubtedly a very economic and well timed development, and the costs at Pearl certainly escalated well above US$15 billion – more than three times the original estimate. However the experts say Shell’s timing has been impeccable, too. It always helps to be second in line at one location, of course and with the price of

alternative oil remaining above US$100 for WTI sustainably-high market share should be buildable rapidly. The Fischer-Tropsch technology employed by Shell is more or less a direct result of invaluable experience gained at the much smaller but highly reliable Bintulu (Sarawak) plant in Malaysia; pioneer production commenced there nearly 10 years ago. So at current crude prices the huge investment in Pearl could be returned within just a few years, with annual revenues of close to US$10 billion already being predicted.

Better earner As always with new products, other potential investors with surplus gas on their hands are waiting to see how the market develops. Thus in the long term GTL could even become a better earner than LNG, consolidating RLIC’s reputation of demonstrating commitment to the building of Qatar’s 21st century economy. With further LNG developments on hold because of that moratorium and the GTL industry getting close to capacity output Ras Laffan’s gasbased industries are now reaching a plateau, and the focus ahead of 2022 is shifting towards further infrastructure development, services and a range of completely new support industries such as PV panels. So, just as in Qatar’s other Industrial City, Mesaieed, close by Umm Said to the south - where a different cluster of industries such as Qafco’s world-leading nitrogen fertilizers are based - its future must firmly be as well assured as any industrial agglomeration - anywhere. ■

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Innovations

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Surface wellhead contract in Egypt awarded

Hi-Force launches new catalogue

AKER SOLUTIONS WILL be the sole supplier of all surface wellhead equipment for the Egyptian oil giant Badr Petroleum Company after the two parties signed a two-year frame agreement. The contract will cover installation and lifecycle services operations in Egypt’s western desert. Aker Solutions president of Asia Pacific, Dave Hutchinson, said, “We The equipment will be produced out of Aker's are very excited about manufacturing centre in Batam this award, as it marks the successful entry of our surface business into the Egyptian and North African markets. Our ambition is to grow Aker Solutions’ operations in the Middle East and North Africa.” The contract, which will be delivered out of Aker Solutions’ surface products manufacturing centre in Batam, Indonesia, was signed and booked as an order intake for the first quarter of 2012. Aker Solutions employs more than 23,000 people in more than 30 countries, of which approximately 320 staff work at its Batam facility.

UK’S HI-FORCE HAS launched its 2012 catalogue which is the company’s biggest and most comprehensive edition consisting of over 1,900 products. Commenting on the completion of the Hi-Force catalogue, sales and marketing director Mar Noordhoek said, "We believe we have created a first class catalogue based around our customers’ needs that is easy to use and packed full of helpful and technical information. Each year there is tremendous growth within our Company and we feel that this catalogue reflects that success." The catalogue includes the latest additions to the Hi-Force range. Most notably, the PB hydraulic pipe bender, which has proven to be one of the most popular products. The hydraulic pipe bender has been designed to bend various sizes and thicknesses of JIS standardised conduit pipe and gas pipe ranging from 15mm – 82mm. Made of aluminium, the bending frame is compact and lightweight so that it can be easily carried on and off site and can be operated by any Hi-Force manual or powered pump up to 700 Bar. To complement the pipe bender a range of bending shoes are also available. Also new to the range is; the GTB and PTB tyre bead breakers, the HP211 aluminium manually operated hand pump weighing just 2 kilograms, the HTW2000B manual torque wrench with a capacity of 2000Nm, the HT3000 and HT4500 torque multipliers with capacities up to 3000Nm and 4500Nm respectively, the new range of air driven hydrotest pumps - AHP3, the SJS10-M jaw spreader with built in manually operated hand pump and the addition of the Toughlift tool box which has been specifically designed to store and protect Hi-Force Toughlift accessories. Other changes include the ERA’s (extended reaction arms) which have been added to both the TWS-N and TWHN hydraulic torque wrench series allowing for greater user versatility, the HiForce manually operated foot pump is now available both with (HP227FPC) and without (HP227FP) a pressure gauge and protective bellows have been added to the HPC range of single acting pull cylinders.

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Emerson's new flue gas analyser EMERSON RELEASED ITS latest solution for combustion flue gas analysis, the Rosemount Analytical Model 6888 in situ oxygen analyser. The Model 6888 provides accurate measurement of the oxygen remaining in the flue gases coming from combustion processes such as boilers, incinerators, kilns and process heaters. By maintaining the ideal level of oxygen in the flue gases, optimal efficiency is achieved and the lowest levels of NOX, CO and CO2 are produced. “As the needs and compliance demands for flue gas analysis become greater, we are making our Rosemount Analytical instruments more and more accurate and easy-to-use to meet our customers’ requirements,” stated Dave Anderson, marketing director, Emerson Process Management, Rosemount Analytical. The in situ design of the Model 6888 places a zirconium oxide sensing element at the end of a probe which can be inserted directly into a flue gas stream. Probe lengths are available from 18 inches to 12 feet, and a slip mounting option provides the ability to mount a long probe at any insertion depth. Signal conditioning electronics reside in the head of each probe, eliminating the need for expensive signal cable. The Model 6888 is fully field-repairable. All active components can be replaced including the diffuser/filter, sensing cell, heater and thermocouple, and all electronics cards. A dual-channel operator interface unit provides an easy-to-use method of set-up, calibration and failure diagnostics. Anderson added, “The Model 6888 is a real breakthrough in what has traditionally been an old-line technology. It promises real savings in time and resources for users.”

Innovations

Schlumberger opens new laboratory SCHLUMBERGER OPENED ITS new Geoengineering Laboratory in Houston that will offer a wide variety of reservoir core analysis services for the oil and gas industry. The 30,000 sq ft facility is the latest addition to the Schlumberger global network of laboratories. The other facilities are located in Brazil, Canada, Malaysia, Poland, Venezuela and Salt Lake City, Utah. The new Houston facility features a conventional core analysis laboratory The facility will increase SLB's core analysis capabilities for the measurement of porosity, saturation and permeability. It also houses a special core analysis laboratory for performing tests of a more complex nature covering capillary pressure, relative permeability, electrical properties, nuclear magnetic resonance, enhanced oil recovery evaluations and more. Additionally, the Houston laboratory performs a number of TerraTek rock mechanics and core analysis services, primarily geomechanics, for unconventional reservoirs.

Innovations

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Flame retardant fabrics FLAME RESISTANT (FR) fabrics used in protective clothing can be categorised into two primary groups: FR treated or inherently FR. Both varieties of fabric undergo rigorous testing and must demonstrate flammability characteristics that protect the wearer from further injury in the event of an incident. FR treated fabrics are commonly made of 100 per cent cotton or a blend of 88 per cent cotton and 12 per cent nylon. Some flame retardant finishes for cotton fabrics are durable for the life of the garment. This treatment is durable to laundering as long as recommended procedures are followed. NonDurable FR treatments are not recommended, as after a number of launderings, the garment will no longer be FR. For example, the world’s largest FR apparel manufacturer Bulwark® uses only fabrics that provide durable FR protection, giving peace of mind: protection for the life of the garment, as long as care instructions are followed.

The use of products containing chlorine bleach or hydrogen peroxide to clean garments made of FR treated cotton or cotton blends is not recommended; repeated exposure to these substances could destroy the chemistry that provides the flame resistant characteristics of the fabric. Fabrics described as ‘inherently FR’ are made of fibres whose chemical structure will prevent them from sustaining combustion. This characteristic is built into the fiber and cannot be washed out or worn off. Adhering to recommended guidelines for cleaning garments made of inherently FR fabrics will prevent excessive shrinkage or colour loss during the laundering process. In order to optimise performance, it is essential that FR clothing be kept clean. If a garment becomes contaminated with a flammable substance, the flame resistance of that garment may be compromised leaving the

wearer with a reduced level of protection. Likewise, the use of starch or fabric softeners is not recommended because they too can become deposited on fabric in amounts that eventually could support combustion. Both FR treated and inherently FR garments from Bulwark® provide superior flame resistant protection. In making the choice between treated or inherently FR garments, consideration should be given not only to protection but also comfort, durability and cost. In addition, there are a number of innovative lightweight solutions specifically designed for hot climates that delivery greater wearer comfort through moisture management and breathability, without sacrificing protection. Examples are inherent Cooltouch2™ and treated Comfortouch™ garments from Bulwark®. These innovations were showcased at a recent Innovation in Oil & Gas Safety event in Dubai.

Tratos wins Baghdad cable contract

H2S innovations reduce costs

SPECIALIST CABLE MANUFACTURER Tratos Cavi S.p.A has been awarded a US$1.33mn contract to supply Iraq's state-owned Midland Refineries Company (MRC) with cables for installation at the Daura Refinery in Baghdad.

OIL AND GAS producers in the region are experiencing the challenges of producing resources laden with Hydrogen Sulfide (H2S) first hand. Working in this environment, companies must account for the increased risks to the safety of workers and corroding equipment in their project operating costs. Product recovery and flaring during well operations have a significant impact on the environment and are difficult to manage when H2S is present. AMGAS Services Inc. has created innovative ways to safely handle and process H2S. AMGAS offers a wide range of services, including H2S www.am-gas.com removal and control measures aimed at mitigating the dangers associated with processing sour oil and natural gas. The company’s team of professionals is trained in using the specialized and proprietary equipment, chemicals and processes. “H2S is very dangerous, so the chemicals and equipment used must be dependable,” says January McKee, President of AMGAS Services Inc. “For AMGAS, dependable innovation has always meant that chemicals and equipment have been tested and proven to be reliable”. Fluids containing H2S emit vapor equally as dangerous to workers and the environment. Treating the vapors requires dependable and innovative scrubbers to ensure the risks are eliminated and that the produced fluids can be stored, transported, processed or disposed. AMGAS has partnered with Rutledge E&P Pte Ltd. who provides service for upstream drilling and exploration activities. Rutledge is based in Singapore and has operations throughout the Middle East. AMGAS’s strategic partnership with Rutledge provides complete detection, protection and removal technologies for H2S environments. The Canadian based-company has over 25 years of experience working to reduce H2S and other noxious emissions. Their scavenging and scrubbing chemicals are supported by personnel with the knowledge and experience necessary to reduce costs, environmental impact and increase safety.

www.tratos.eu

A range of power cables, high temperature cables and fire resistant cables have been supplied to MRC, a new customer for Tratos, as part of the modernisation process of the Refinery. The Daura refinery, located in the south of Baghdad, was constructed in 1953 and started operations in 1955. It daily produces three million litres of gasoline, 1.5mn litres of kerosene and two million litres of gas oil, along with other products going to local power plants and industrial use. Tratos Cavi has been producing cables for use in the oil and gas industry throughout its 40 year history. The cables are manufactured to all the relevant American, British and European standards including BS6883, NEK 606 & UKOOA. The Tratos Group is one of the major European manufacturers of electrical, electronic and fibre optic cables.

62 Oil Review Middle East Issue Four 2012

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TDW repairs valve bypass line in Qatar

ALDERLEY FZE, A subsidiary of Alderley plc, has completed the client witnessed Factory Acceptance Tests (FAT) for 5 gas metering skids for the LSFO, FG and Gas Oil Pipelines Skids for LSFO,GO and FG pipeline project Project, Kuwait. The contract was issued by Petrofac International and is for the Kuwait, MAA Refinery and Azzour Power Station operated by KOC and KNPC. The project scope of supply is for 5 x 5 stream Ultrasonic Metering packages with header sizes varying from 34â&#x20AC;? to 52â&#x20AC;? and Stream sizes varying from 12â&#x20AC;? to 20â&#x20AC;? respectively. Each package has a master meter stream for checking the line meters. Part of the scope also includes special blast resistant Analyser shelters for each metering package with redundant Gas Chromatographs and sampling systems, and associated computer control systems for all of the metering systems.

TDW OFFSHORE SERVICES announced that it has completed a pipeline pressure isolation operation in Qatar on behalf of a major supplier of LNG. The operation took place at the customerâ&#x20AC;&#x2122;s LNG complex in Qatar. Natural gas is transported from platforms offshore Qatar through seven LNG trains to this complex. In order to facilitate replacement of a defective emergency shutdown (ESD) valve on a primary export line, pressure isolation services were required. The 38-inch diameter pipeline runs from two wellheads in the offshore natural gas condensate field to the onshore LNG processing facility. To isolate the pipeline section located upstream of the designated ESD valve, TDW launched two 38-inch SmartPlugÂŽ isolation modules using an existing pig-receiving trap located onshore at the receiving end of the export pipeline. Using its remotely-operated SmartTrackâ&#x201E;˘ tracking and pressure-monitoring system, TDW monitored the location of each module as it travelled 600 meters along the pipeline route, as well as the pressure of the pipeline. One module was positioned upstream of the designated ESD valve, and the other downstream of the valve. TDW then set the modules and safely isolated the affected section so that the modifications on the ESD valve could be safely carried out. "The fact that the SmartPlug isolation modules performed well and the TDW team worked so effectively with the customerâ&#x20AC;&#x2122;s team meant that we were able to create a safe environment in which to replace the valve," said Enzo Dellesite, director, market development-offshore for TDW. TDW hopes to build upon the success of the pipeline pressure isolation operation at the complex by providing additional services.

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Oil Review Middle East Issue Four 2012 63

Innovations

Alderley completes FAT for KOC/KNPC

S15 ORME 4 2012 Innovations 2_Layout 1 03/05/2012 14:45 Page 64

S15 ORME 4 2012 Innovations 2_Layout 1 03/05/2012 14:45 Page 65

MESC meeting growing demand for cables MIDDLE EAST SPECIALISED Cables (MESC) Group is a major supplier of cables and has been operating since 1994. Vice president-operations, MESC, Abdulkarim Masad said that the growing demand for high-end quality cables is changing the international perception of cables manufacturers worldwide as well as in the Middle East. Such a growth is bringing both challenges and opportunities for those operating in the cabling industry. Some of the main challenges facing the industry range from the increase in raw material prices and finished cables quality from some other poor suppliers are troubling factors faced by cable manufacturers. The energy sector in the Middle East is taking the lion’s share of global energy investment because of the vast number of development projects taking place simultaneously across www.mesccables.com the region. This is why MESC Group has expanded across the region and has three major manufacturing facilities around the region; MESC KSA, MESC UAE & MESC Jordan. Each of the companies have their own management and workforce team and have their own laboratories. MESC’s product line covers all types and ranges of cables, starting from Industrial, Instrumentation and Process Control Cables, Special Cables (BMS), Low and Medium Voltage Power Cables and Offshore Cables to the customised cables that are designed and manufactured according to customers’ specifications and requirements.

INOVA introduces new land cable system INOVA GEOPHYSICAL HAS released G3i™, a flexible and rugged land recording system. The mega channel recording system offers the industry a highly-portable technology that provides support for conducting a wide range of land seismic surveys, including high density wide azimuth acquisition for the world’s most challenging environments. G3i supports over 100,000 channels and can be used to capture 2D, high density 3D and time-lapse 4D data. “The addition of this new cabled land system will offer seismic players in the industry another alternative for cable based recording that meets a broad scope of operational demands, allowing contractors to achieve a higher rate of return on their assets,” INOVA said in a statement. Several key features provide immense benefit to geophysical contractors, including its rugged, aircraft grade aluminum enclosure and high-strength polycarbonate exterior for maximum durability. Power management and deployment logistics are simplified because the G3i system utilises PDL technology to evenly distribute battery power to multiple field station units using the power supply (PSU) and fiber tap (FTU) units along with standard 12V batteries. According to INOVA, the G3i was also designed with the “do more with less” philosophy in mind; as contractors can take advantage of having four analog channels in a 1.2 kg compact, remote acquisition module (RAM) station, as opposed to using the existing single channel stations offered by competitors. With less field equipment to transport, maintain, and troubleshoot, surveys can be operated more efficiently. Oil Review Middle East Issue Four 2012 65

Lubricants

S16 ORME 4 2012 Tech Focus 1_Layout 1 04/05/2012 11:00 Page 66

In an unforgiving environment where every day of unscheduled downtime can result in major financial losses, it is vital that oil and gas companies maintain their equipment by taking advantage of the various advanced lubricants at their disposal, writes Akram Reda, Industrial Marketing, Europe, Africa & Middle East, ExxonMobil Lubricants and Specialties

Utilising lubricants to

reduce downtime M

AJOR OIL AND gas producers face a daily challenge to meet current production targets, placing a great responsibility on oil and gas companies operating in the region to maximise productivity and reduce unscheduled downtime. Across the entire production process, from drilling to delivery, advanced industrial lubrication can play a key role in keeping operations running efficiently, 24 hours a day, as well as reducing operating costs. Drilling and exploration is a significant investment for oil and gas companies, with rig hire alone costing as much as tens or even hundreds of thousands of dollars per day. Taking this into account, companies must avoid any unplanned downtime.

A typical offshore oil and gas rig is reliant on a number of lubricants to ensure its efficient operation. Turbines and reciprocating engines provide primary and auxiliary power, gears and bearings are crucial in draw works, cranes, mud circulating, top drive and rotary tables and compressorsâ&#x20AC;&#x2122; power refrigeration and air

Examining changes in the oil analysis data over time (trending) is necessary to assess the condition of the lubricant

systems. Whether it is an engine oil, turbine oil, gear lubricant, hydraulic fluid or grease, one equipment failure can bring the entire operation to a halt. At the processing stage, lubrication remains critical to the overall productivity and performance of a plant. Take for example the key role of a turbine oil in keeping operations online. A turbine failure in an oil refinery and resulting shutdown can cost millions of dollars. When it comes to transportation, marine vessels depend on a range of lubricants to ensure they remain fully operational. From the main engine, propulsion systems, auxiliary engines and thrusters to the deck crane, deck machinery and winches, a wide range of

At the processing stage, lubrication remains critical to the overall productivity and performance of a plant

66 Oil Review Middle East Issue Four 2012

S16 ORME 4 2012 Tech Focus 1_Layout 1 03/05/2012 14:47 Page 67

Lubricants

S16 ORME 4 2012 Tech Focus 1_Layout 1 04/05/2012 11:01 Page 68

lubricants are required to ensure oil and gas is efficiently transported around the world.

Advanced lubrication Advancements in lubricant technology, especially fully-synthetic based products, have resulted in significant breakthroughs regarding the extension of equipment life and oil drain intervals. These breakthroughs can help oil and gas companies maximise productivity and reduce unscheduled downtime throughout the drilling, processing and transportation chain. For example, Mobil SHC fully synthetic lubricants can last up to six times longer, with upper operating temperature limits that can typically reach 50°C (90°F) higher than mineral oils. The high temperature performance of lubricants is particularly important for oil and gas companies operating in the Middle East, where the high ambient temperature coupled with the high speeds and heavy-loads placed on applications, requires a lubricant which can maintain protection in high-operating temperatures. Other research and development areas that leading lubricant providers have focused on in recent times include improving the energy efficiency of equipment while maintaining these extended operating periods. Recent breakthroughs from Mobil Industrial Lubricants include lubricants to improve the energy efficiency of natural gas engines that are used to power drilling and production rigs. These are in addition to hydraulic, gear and bearing oils which are used in a variety of applications. The natural gas engine oil, Mobil SHC Pegasus, uses breakthrough technologies to optimise equipment productivity and protection and is the first gas engine oil formulation on the market to deliver real energy saving potential. Extensive independent university laboratory and field tests have demonstrated that the product helps reduce fuel consumption by up to 1.5 per cent*. The new Mobil SHC Pegasus formulation also delivers the potential for increased oil drain intervals of more than 16,000 hours - three to four times that of premium natural gas engine oils. This can help reduce unplanned downtime as well as reduce the amount of waste oil generated. ExxonMobil’s state-of-the-art hydraulic oil, Mobil DTE 10 Excel, has been proven to help industrial organisations increase productivity, reduce unscheduled downtime and improve the energy efficiency of their machinery. Compared to standard hydraulic oils, Mobil DTE 10 Excel can provide up to a six per cent improvement in hydraulic system efficiency** and 300 per cent increase in oil drain intervals. The latest addition to the Mobil SHC brand of high-performance synthetic lubricants, Mobil SHC 600 Series oils, are expertly formulated to deliver a number of performance advantages over conventional oils. Featuring the latest Mobil SHC technology with advanced synthetic base fluids and a proprietary additive system, the oils can deliver a service life up to six times

68 Oil Review Middle East Issue Four 2012

By trending oil analysis data it is possible to proactively address undesirable conditions before they become problems

longer than competitive mineral oil based gear and bearing lubricants. In addition, developed through extensive laboratory and in-service testing with some of the world’s leading equipment manufacturers, the next-generation Mobil SHC 600 Series oils exhibit energy savings of up to 3.6 per cent*** compared with conventional oils.

Beyond oil analysis, visual system inspections should be conducted regularly to check and document the condition of systems Maximising productivity In order to help maximise the productivity of machinery and reduce costs, ExxonMobil recommends incorporating an oil and equipment condition monitoring programme alongside the use of high quality lubricants. As part of routine maintenance, the "health" of the lubricant and the equipment itself should be regularly checked. Typically, it is advised that maintenance professionals perform quarterly oil analysis and annual system inspections. Examining changes in the oil analysis data over time (trending) is necessary to assess the condition of the lubricant. By trending oil analysis data it is possible to proactively address undesirable conditions before they become problems, which is crucial given the huge potential downtime costs associated with an offshore rig being offline for any period of time. For equipment maintenance professionals who want an effective oil analysis monitoring programme, there is ExxonMobil’s proprietary online Signum oil analysis programme. Signum oil analysis offers engineers immediate access and direct control of their lubricant sampling programme.

Technical support Beyond oil analysis, visual system inspections should be conducted regularly to check and document the condition of systems. Inspection data can be used to establish the optimum time to perform maintenance on critical components such as filters, valves, hoses and pumps. Comprehensive leak detection should also be performed, especially if excessive oil usage is noted during a routine system inspection. Due to the 24/7 nature of the oil and gas sector, it is important that companies have access to experts that can work alongside inhouse engineers to develop optimised lubrication solutions for applications. Variables such as operating temperature, load, cycle and age of equipment have an impact on the most appropriate lubrication, monitoring and maintenance package. To service oil and gas companies in the Middle East, ExxonMobil has a Field Engineering Services (FES) team on the ground to offer technical support to companies operating in the region. On a day-to-day basis they work with companies to address lubrication issues as well as proactively identifying ways in which productivity can be further increased by switching to more advanced lubricants. The technical specialists in the Middle East are part of a global FES team, which shares application expertise and best practice through its work in supporting oil and gas companies in other areas of the world such as the Gulf of Mexico, the North Sea, Russia, the Asia Pacific region and Africa. To augment this technical expertise, ExxonMobil has specialist strategic distributors located in all of the key Middle East oil and gas markets to offer fast and reliable delivery of Mobil Industrial Lubricants. Oil and gas companies looking to optimise the productivity of their equipment need to ensure they have access to the latest lubricants and services, as well as application expertise. ■

S16 ORME 4 2012 Tech Focus 1_Layout 1 03/05/2012 14:47 Page 69

Extending Field Life

S16 ORME 4 2012 Tech Focus 1_Layout 1 03/05/2012 14:47 Page 70

A novel power generation technology from Maersk Oil is set to provide new commercial solutions for enhanced oil recovery and unlocking stranded gas fields, writes Bob Alford, TriGen Project Manager at Maersk Oil

Maersk Oil’s TriGen technology unlocks

clean energy M

AERSK OIL’S TRIGEN technology is derived from the space industry and involves burning gas together with pure oxygen to produce power, water and carbon dioxide. The resulting high purity CO2 is captured – making the power generation emission-free – and can be transported to fields for enhanced oil or gas recovery (EOR/EGR). This technology can provide synergy across the energy industry to create value for both resource owners and energy producers. The global energy business has traditionally been separated into upstream, downstream and power generation activities. This provided the right business focus for resource owners and power producers and made perfect sense with current oil extraction and power generation technology. With TriGen, however, linking power generation back to upstream oil and gas activities, a zero emission solution across the energy value chain becomes possible as all of its outputs are useful commodities. It was the EOR application that first caught the eye of Maersk Oil, as we had already started to study whether we could use CO2 to enhance recovery from our own mature oil fields, and were seeking low-cost sources of the gas.

A diagram explaining TriGen

70 Oil Review Middle East Issue Four 2012

However, we soon realised that the technology’s multi-stream output, including its ability to burn CO2-contaminated gas as fuel without any pre-treatment, actually gave it access a number of business opportunities around the world. We are currently exploring opportunities in the Middle East and South-East Asia that have different value chains and benefits, yet both can now be made commercial from the implementation of the TriGen technology.

In the Middle East, we are investigating whether TriGen’s low-cost CO2 can enable EOR projects In the Middle East, we are investigating whether TriGen’s low-cost CO2 can enable EOR projects. Gulf countries in particular have increasingly focused on clean energy, while many of its oil and gas reservoirs are well-suited to CO2EOR and nitrogen or CO2 based EGR. Here, gas would be burned to produce clean power and water for households. Nitrogen, a by-

product from the production of pure oxygen, and CO2 would be supplied to oil fields – nitrogen to maintain the pressure in depleting reservoirs and CO2 as the EOR agent coaxing out oil that would otherwise not be recovered. In TriGen’s oxyfuel combustion process, fuel is mixed with pure oxygen and burned at pressure in excess of 100 bar and temperatures over 2,200 degrees Celsius. TriGen gets its pure oxygen from a standard Air Separation Unit that compresses and cools atmospheric air until oxygen and nitrogen are separated by distillation. The hot combustion gasses that are produced (only steam and CO2) are expanded in a turbine that drives a generator while the pure water and resulting high quality CO2 are separated. The generated power becomes emission-free as the ‘reservoir ready’ CO2 is transported to oil and gas fields where it is injected deep underground for EOR/EGR. Traditionally, CO2-based EOR has only been feasible in areas with large sources of natural CO2 – chiefly in the United States. But the ability to produce pure CO2 as a by-product of a commercial power generating venture now makes CO2-based EOR attractive in regions such as the Middle East, which has limited sources of natural CO2.

S16 ORME 4 2012 Tech Focus 1_Layout 1 03/05/2012 14:47 Page 71

Extending Field Life

The pure oxygen combustion of TriGen

Additionally, as TriGen produces water, it can be placed in remote locations where water is not readily available. This water can be used for domestic purposes or irrigation. In the oil field, the low salinity water is beneficial for improving recovery in water floods. The technology provides Maersk Oil with a competitive advantage in the Gulf region, as it offers both the benefit of clean power and low-cost CO2 to increase recovery potential. The technology also complements our current work and studies on CO2-based EOR in Denmark and Qatar, enabling us to offer integrated field development solutions in this area.

CES, in collaboration with Maersk Oil, Siemens and the US Department of Energy, is maturing the technology. Derived from rocket science, where pure oxygen is used to burn fuel, CES has proven the technology on a smaller scale over the last 15 years. Siemens is currently converting a conventional gas/air turbine to a gas/oxygen turbine for a commercial power plant project in California using the TriGen technology. The converted turbine – approximately the size of a Maersk shipping container – will be hooked up to a power grid in North Los Angeles later this year and has the capacity to deliver 150 megawatts of electricity – enough to provide energy to over 100,000 homes. ■

The technology provides Maersk Oil with a competitive advantage in the Gulf region, as it offers both the benefit of clean power and low-cost CO2 to increase recovery potential

Bob Alford is senior manager of business development & strategy and TriGen project manager at Maersk Oil

In South East Asia, the value chain starts at a different point – at world class gas fields that lie undeveloped because they are contaminated by CO2. Such stranded gas fields could now potentially be produced economically because the TriGen technology can burn gas contaminated with up to 90 per cent of CO2 without requiring any costly pre-treatment for CO2 removal. We would be unlocking enormous value to the states that have been sitting on these fields, unable to produce them commercially. Although it is early days yet, with technical and commercial challenges to overcome, these are just the kind of projects that affirm Maersk Oil’s pioneering approach to business. We launched the project two years ago and in January 2011 announced the acquisition of rights to the combustion technology from US-based Clean Energy Systems (CES).

Oil Review Middle East Issue Four 2012 71

S17 ORME 4 2012 Tech Focus 2_Layout 1 04/05/2012 11:14 Page 72

Flow Measurement

Dr. Asaad Kenbar*outlines the latest measurement technologies for the LNG sector.

Improved measurement technologies

for LNG C

LIMATE CHANGE, CHANGING oil prices, increasing overall energy needs and fuel switching are all factors contributing to the growth in global demand for liquefied natural gas (LNG). Longer term, analysts expect global LNG demand to grow from 218mn metric tonnes per year (mt/year) in 2010 to 410mn mt/year by 2020 [1]. This growth will be met by the expansion of existing liquefaction plants and building new plants, as well as the use of small-scale LNG plants incorporated into FPSO (floating, production, storage and offloading) vessels. The latter new approach to LNG production will make it more akin to crude oil production than ever before, with LNG production being directly associated to specific fields. The high energy density of LNG means that it can be transported easily by ships from areas of production to areas of need. The current practice for measuring LNG delivered to or received from a ship’s tanks is made in the form of energy transferred based on the GIIGNL Handbook (International Group of Liquefied Natural Gas Importers). The GIIGNL is, however, only an agreed handbook of good practice, it is neither a standard nor a specification. A new ISO standard (ISO 10976) describing a procedure for measurement of LNG quantities on board LNG carriers is in the final stages of development and will be released in the near future. The calculation of LNG energy transferred requires measurement of LNG volume in the ship’s tanks, the density and gross calorific value (GCV). The calculation of the density and the GCV are made on the basis of the average composition of the LNG obtained from LNG sampling and subsequent analysis by chromatography. The following equation is currently used to calculate the LNG energy transferred (GIIGNL 2011): E = (VLNG . DLNG . GCVLNG) – Egd ± Eg-en where E Energy transferred from the LNG carrier to the unloading facilities (MMBTU). VLNG LNG volume (m3) (Liquid level measurement and correction tables) DLNG LNG density (kg/m3) (Using Revised Klosek-McKinley method) GCVLN LNG gross calorific value (MMBTU/kg) (measured composition) Egd Energy of the gas displaced from the storage tank (MMBTU) (Often estimated) Eg-en Energy of the gas consumed by carrier’s engines- If applicable. +ve for an LNG loading -ve for LNG unloading There are several challenges associated with the measurement of LNG energy transferred. Some of these are related to the measurement of the LNG volume, but the main challenges are faced with the measurement of LNG composition obtained from sampling. The GIIGNL estimates an overall uncertainty in the measured LNG energy transferred of ±0.86 per cent as given in the following table.

Element calculated Volume Density Gross Calorific Value Combined standard uncertainty Coverage factor Expanded overall uncertainty

Standard uncertainty ±0.21 % ±0.23 % ±0.30% 0.43% 2 (95% confidence level) 0.86%

72 Oil Review Middle East Issue Four 2012

The measurement of LNG volume in ships’ tanks requires accurate measurement of the level and temperature at various locations in the tank and then applying appropriate corrections. In principal, better accuracy can be achieved by direct measurement of the LNG flowrate, rather than measuring the volume in tanks. However, the nature of LNG presents some very real challenges for flow meter technology, the biggest of which is the cryogenic temperature at which LNG exists (approximately -160oC). At present the development of cryogenic flow metering has focused on ultrasonic and Coriolis techniques. Whilst these are promising, a number of issues including the establishment of a reliable calibration principal and quantifying installation effects (in particular for ultrasonic meters for fiscal applications) have still to be addressed. This is the main reason why LNG flow meters are currently used for allocation and control but not for custody transfer measurement. Flow meters are usually calibrated using water at ambient temperatures and due to the international scarcity of cryogenic test facilities, combined with the complexities of testing under low temperature conditions; little independant research has been done to establish if flow meters remain accurate under the extremely cold condition that LNG exists. To address some of the many challenges associated with the handling of LNG, in particular the measurement issues surrounding the delivery of LNG to a receiving terminal, NEL, supported by the UK National Measurement System (NMS), has been carrying out research to help industry establish a framework of measurement standards and capabilities. This research has been carried out through the NMS Engineering & Flow Programme research and more recently through the active participation in the European Metrology Research Programme (EMRP). The former focused on development of inline metering technologies, while the latter covers all aspects of LNG metrology.

The EMRP Project The European Metrology Research Programme (EMRP) is a metrology-focused European programme of coordinated R&D that facilitates closer integration of national research programmes. The programme is delivered through projects focussed on improving the European infrastructure for metrology, and provides measurement solutions to particular sector needs. The overall goal is to accelerate innovation and competitiveness in Europe whilst continuing to provide essential support to underpin the quality of life. The research is being executed in close collaboration with industry and has established an advisory group to maximise the benefits for industry. The EMRP LNG project addresses current issues with both state-of-the-art measurement technology by tank gauging methods and flow measurement by ultrasonic and Coriolis flow meters. The main objective is to achieve significant reduction of uncertainty in LNG energy transferred during custody transfer processes. The project has estimated an equivalent economic value of an uncertainty reduction of 0.5 per cent to be in the region of 60 M€/year on the total amount of imported LNG in Europe. The project runs for three years from May 2010 and the programme of work is jointly funded by the European Commission and the participating National Measurement Institutes (NMI’s). As the project deals with all aspects of LNG metrology, the work has been broken down into five main work packages (WP’s) to ensure efficient execution of the project.

S17 ORME 4 2012 Tech Focus 2_Layout 1 04/05/2012 11:15 Page 73

The knowledge and experimental data obtained from the first four work packages will feed into the fifth work package. The information will be presented to industry through various international committees and in the form of guidelines, new international standards and other forms of publications.

Development of Traceability for LNG Flow Meters One of the primary objectives of the project is to pave the way for the development of an SI traceable primary standard for calibrating LNG flow meters. This standard aims to address the traceability needs of LNG terminals where LNG flow rates range from 5000 to 10000 m3/h. However the build of such a facility is outside the scope of this project.

mid-scale standards. Since the development of a full-scale LNG calibration facility will take some time, the project is currently assessing an alternative approach for calibrating LNG flow meters. This is mainly focusing on the development of an economic calibration concept which transfers calibration with a fluid such as water at ambient conditions to cryogenic conditions by applying appropriate corrections. This will be supported by testing using the small and mid-scale facilities. This calibration scheme is currently adopted by industry but requires independent validation. In addition to the above, a novel cryogenic flow metering technology by Laser Doppler Velocimetry (LDV), is currently explored as a promising alternative

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Flow Measurement

This project will develop the required knowledge and experience towards the full scale facility by adopting a staged approach. The first and current stage is focusing on the development of a small scale primary LNG flow standard which handles flow rate up to 25 m3/hr. This will be followed by the development of midscale flow standard that handles LNG flow rates up to 200 m3/h using bootstrapping techniques and input from the small-scale primary standard. The mid-scale system will be useful for small LNG applications such as road tanker applications. The realisation of the full-scale facility crucially depends on the outcome from the small and

Flow Measurement

S17 ORME 4 2012 Tech Focus 2_Layout 1 04/05/2012 11:15 Page 74

to ultrasonic and Coriolis flow metering. LDV as a flow measurement technology has already been demonstrated in high pressure natural gas with an uncertainty of 0.1 – 0.2 per cent, but its application to cryogenic temperatures is challenging and currently under investigation.

LNG Sampling and Composition Measurement Currently the calculation of the density and the gross calorific value of the LNG transferred are made on the basis of the average composition of the LNG. This composition is obtained from LNG sampling and chromatographic analysis. The sampling stage is the most important point of the LNG measurement sequence as unrepresentative samples are responsible for the majority of errors that occur in the energy transferred calculation. The sampling procedure must therefore be consistent throughout the whole operation to ensure representative results. The accuracy of LNG composition obtained from sampling will have a direct influence on the accuracy of calculated density and gross calorific value, and subsequently the accuracy of LNG energy transferred. The LNG shipment value is often in the range of €40 - €50 million. A small error in the determination of the gross calorific value and density of the LNG therefore has a significant financial impact on the exporter/importer. A one per cent error in energy transferred equates to €400,000 - €500,000 in misallocation during custody transfer. Therefore, one of the main work packages of the EMRP project focuses on LNG sampling systems. This work package explores the current sampling technologies used in the LNG custody transfer measurements and newly developed technologies, specifically by Raman spectroscopy, and will propose recommendations for improvements.

Improved Calculation of LNG Density The density of LNG is calculated on the basis of the measured composition, temperature and pressure. Important sources of uncertainty are the choice of the correct equation of state, as well as the accuracy of temperature and

composition measurements. New and more accurate density reference data will be produced in this project in order to assess the many available density calculation methods that are based on very old reference data. The financial implications of different methods being applied to a cargo will also be evaluated. By analysing the information compiled, the most accurate method will be recommended for custody transfer.

Dissemination of Information The new results from this project will be disseminated to international organisations in the form of guidelines and standards related to LNG metrology. The challenge is to create a significant impact that facilitates international acceptance of the project results. The international working groups from ISO, CEN, GIIGNL and OIML are therefore engaged in order to achieve this. In addition, the project impact will be maximised by other activities such as organising workshops and conferences, presenting the project’s results at conferences and in scientific and key user journals. Two successful workshops have already been organised, the first at SP (Sweden) in 2010 and the second at NEL (UK) in 2011. These events attracted delegates from around the world. Several presentations directly relevant to the LNG metrology and its development were given by participants from industry. The events presented an excellent platform for sharing information and experience between the project partners and the LNG industry and gave rise to lively and inspiring discussions. ■

[1] http://www.naturalgasasia.com/global-lng-demand-forecast Dr. Asaad Kenbar, Principal Consultant at NEL, a world-class provider of technical consultancy, research, testing, flow measurement and programme management services to the energy, oil & gas and manufacturing industries, as well as government. NEL, part of the TÜV SÜD Group, is a global centre of excellence for flow measurement and fluid flow systems and is the custodian of the UK’s National Flow Measurement Standards.

Pipe weld inspection solution

Saudi valve and training facility now open

THE LATEST VERSION of the USM Vision innovative, ultrasonic (UT) weld inspection system, from the Inspection Technologies business of GE Measurement & Control, now features parallel scanning, linear scanning and the ability to incorporate phased array prpbes with up to 128 elements. As a result it now offers increased productivity and greater functionality and can be used on thicker pipes, while satisfying a wider range of inspection codes. This allows the benefits of the USM Vision technology to be realized beyond the fabrication yard in the oil and gas sector in the inspection of welded plate. USM Vision 1.2 continues the philosophy of the original instrument and allows nonUT trained specialists to gather reliable and accurate pipe weld inspection data, for subsequent remote assessment by a suitably qualified ultrasonics expert. This permits ultrasonic inspection to be used in situations conventionally requiring radiography, removing constraints such as extended film processing times, radiation screening and waste chemicals disposal. As a result, it facilitates the migration of skills from radiography to UT, reducing the possibility of bottlenecks, providing significant increases in productivity and improving operational health and safety.

FLOWSERVE CORPORATION, A leading provider of flow control products and services for the global infrastructure markets, and S&A Abahsain Co. Ltd., one of the top 50 business entities within Saudi Arabia, have formally inaugurated a new valve manufacturing plant and training center in the Dammam Second Industrial City. The Dammam manufacturing plant is a state-of-the-art, facility with capabilities for component machining, valve assembly, and testing. The facility is operated by Flowserve Abahsain Flow Control Company Ltd., a joint venture between Flowserve Corp. and S&A Abahsain Co. Ltd. Motassim Ma'ashouq, vice president of new business development with Saudi Aramco, was the special guest speaker at the event. Other dignitaries present for the ceremony included Abdullah Abahsain, CEO of S&A Abahsain; Shaukat Sheikh, managing director of S&A Abahsain; Mark Blinn, president and CEO of Flowserve; Tom Pajonas, chief operating officer of Flowserve; and John Lenander, vice president and general manager, Flowserve Flow Control Division, oil & gas sector. The Flowserve Abahsain joint venture was formed early in 2009 to supply valves to the oil and gas, petrochemical, power and water industries. The joint venture commissioned the Dammam manufacturing facility in late 2010, and completed the ISO 9001 certification, Saudi Aramco certification and other major customer approvals in 2011. The facility reached an important milestone in late 2011 with the successful manufacture, inspection and shipment of the facility's first large bore control valves to be completely assembled and tested in Saudi Arabia. A total of seven Flowserve Valtek Mark 100 16" ANSI 300 globe valves, with Flowserve Logix 3200MD positioners, were delivered on schedule to a major grass roots refinery project currently under construction in Saudi Arabia. The Dammam facility will have the capability to manufacture a range of valves and actuators, including Flowserve Valtek globe, ball, plug, butterfly and severe service control valves; Flowserve Valbart trunnion mounted ball valves; Flowserve Durco/Atomac Teflon-lined plug, ball and butterfly valves etc.

74 Oil Review Middle East Issue Four 2012

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Oil Review recently interviewed Dr. Amer Tarraf, Managing Director, Baumer Middle East FZE. Technical Focus

A passion for

sensors T

HE BAUMER GROUP is a leader at international level in the development and production of sensors, shaft encoders, measuring instruments as well as components for automatic image processing. The company’s customers include small, highly specialized plant and machine construction companies, large industrial enterprises and groups of companies operating at global level. Oil Review Middle East recently spoke with the managing director of the company’s Middle East operations, Dr Amer Tarraf concerning Baumer’s regional aspirations. Baumer has been present in Dubai with its new company Baumer Middle East FZE for several months now. What was the main reason for this move? As one of the first pioneers in the process instrumentation sector, we have known and served the market and customers in the Middle East for a long time. We are very well-known in the region especially due to our Bourdon® brand. I would say just about every technical school graduate in the world has learned about or learned how to apply the bourdon tube principle. With Bourdon-Haenni as a competence center for mechanical measuring instruments within the Baumer Group, we can guarantee excellent quality

and safety for applications in the oil & gas industry, for example. We aim to bring this expertise even closer to the customer and provide a single point of contact in the Middle East region. Ultimately it is also the next logical move in view of our involvement here on the ground and the promising customer relations we have established here.

product standards. That's why "Bourdon" makes up a large part of our portfolio of mechanical instruments. Our customers benefit greatly from this. Dr Amer Tarraf

Nowadays an international network is essential for handling projects as well as local support What part does the "Bourdon" brand play? To this day, the Bourdon tube, developed 160 years ago by Eugene Bourdon, the founder of Bourdon Sedeme SAS, has been the most common pressure measurement method, particularly in critical applications as in the oil & gas industry, for example. Nowadays this development is used by diverse manufacturers on the market, however Baumer is the sole supplier of high-quality and reliable Bourdon® Original Pressure Gauges. "Bourdon" is a synonym for reliability, safety, precision and robustness. These features are congruous with Baumer's values and our own

Oil Review Middle East Issue Four 2012 75

Technical Focus

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A comprehensive portfolio

What are the main product focuses and target groups? As a leading sensor manufacturer, Baumer is very strongly represented in the factory and process automation sectors as well as in the food industry, in the machine building or wind power industry. In the Middle East our focus lies on the oil & gas and water treatment industry. We have a great deal of know-how and many years of experience in these fields, which both guarantee great customer benefit. On top of this, we can offer an almost inimitably wide portfolio, which supports the entire process from crude oil to the end product. This includes, for example, a large number of diverse mechanical instruments, like pressure gauges and temperature meters, as well as high-quality diaphragm seals and a very wide portfolio of electronic pressure, temperature, filling level and conductivity sensors. In addition, Baumer offers a wide range of encoders used in drilling, for example. This variety of products is furnished with numerous types of required certifications and approvals, which enables us to offer the customer an appropriate product in virtually all applications.

You mentioned Baumer was a pioneer, what do you mean by that? The objective of the Baumer Group was and is to always be a step ahead of the market, to anticipate approaching needs sooner, and to achieve this by continuously expanding our range of products and technologies. Baumer continually launches innovations also in the oil & gas industry, which classically is safety- and availability-oriented. With special diaphragm seals developed in close collaboration with well-known field transmitter manufacturers and combined with in-house seals technology, Baumer offers perfect solutions for pressure and filling level sensing in remote technology. We meet new application requirements with regard to temperature, media and pressure with continually innovative solutions

How do you operate in international markets? With 36 companies in 18 countries around the globe, Baumer ranks among the leading international sensor manufacturers and suppliers. In view of increasing internationalization, especially in the EPC business for the oil & gas industry, an international structure is essential for efficient

76 Oil Review Middle East Issue Four 2012

inquiry handling and specific customer support. Baumer's modular technology and production concept enables our products to be used across industry sectors and our international experience to be utilized synergistically for country-specific adaptations. That way we can offer optimum solutions for our clients. According to our experience, clients do not just expect and buy a product but also co-operate with suppliers that offer many years of international experience and an international sales and service organization with good and competent on-site support.

Speaking of EPC â&#x20AC;&#x201C; what does Baumer have to offer in this sector? This business requires a tremendous amount of specialist-, market- and application knowledge and can only be conducted successfully if you can draw on global expertise and resources. For this Baumer offers a globally networked EPC team at its locations in France, Germany, Switzerland and India. This team is supported by the local presence of competent subsidiaries, as in the Middle East, North and South America, Europe, China, Singapore, South Korea and India. This network enables Baumer to supply the global EPC world with the required solutions quickly, efficiently and in accordance with customer wishes.

What can customers expect from you? Here at Baumer we take our customers' wishes very seriously. Baumer is committed to customer orientation, partnership and sustainability and offers a wide range of products and technologies otherwise not found on the market in this form. However, Baumer quality is not just defined by a large number of high-tech products, which we guarantee by the providing the necessary services on site, but also comprises our experience in the oil & gas industry and its specific developments, which we proved for example in the SATORP project in the Kingdom of Saudi Arabia. Well-known international players rely not only the safety aspects of Baumer products but also on our company's flexibility when it comes to adapting and combining products to meet very specific application requirements.

What marks out Baumer? Baumer is an internationally operating sensor manufacturer with the culture of an owner-

operated family enterprise and offers an almost unique range of products and technologies. Customer focus and partnership are an essential part of Baumer's identity. Together with our customers, we combine innovative technology and customer-oriented service to create intelligent solutions. Nowadays the markets demand not only high-quality products at competitive prices but also proactive support and service on a professional level. Exactly that is Baumer's culture and I believe that is where we make our contribution. Baumer Middle East is a part of this global sales and product network of the Baumer Group. We can draw on this expertise, so that means we can also handle projects in a complex international context flexibly and reliably.

What makes you optimistic? We are not newcomers to the market or the region. The feedback we received during the first couple of months is very positive, and on top of that we are very busy with inquiries and project talks. Nowadays an international network is essential for handling projects as well as local support. Frequently different parts of a project are separated geographically from one another. And in this case we are on the ground to support our customers and to provide a comprehensive portfolio. Besides, we are talking here about strongly growing markets in the Middle East. I think we can meet demanding customers' requirements with our standard products, our decade-long expertise and our ability to provide tailor-made high-quality solutions. â&#x2013;

The Baumer Group is a leading manufacturer and developer of sensors, encoders, measuring instruments and components for automated imageprocessing. Baumer combines innovative technology and customer-oriented service into intelligent solutions for factory and process automation and offers a uniquely wide range of related products and technologies. With more than 2,500 employees and production plants, sales branches and agencies in 36 subsidiaries and 18 countries the family-owned company is always close to the customer. Industrial clients in many sectors gain vital advantages and measurable added value from the worldwide consistency of Baumerâ&#x20AC;&#x2122;s high quality standards and its enormous innovative potential. For further information, visit www.baumer.com.

S17 ORME 4 2012 Tech Focus 2_Layout 1 03/05/2012 14:51 Page 77

Technical Focus

S17 ORME 4 2012 Tech Focus 2_Layout 1 04/05/2012 11:52 Page 78

Hydratight’s clever solution for Statoil EXPERTS FROM JOINT integrity and engineering services company Hydratight found an innovative solution to a tricky repair for Statoil, by using a MORGRIP connector to repair a six-inch super duplex pipe located within the constrained space of a subsea manifold, 340m under the surface of the North Sea. Hydratight was called in to repair a damaged pipe on a subsea wellhead ‘Christmas tree’ on the Troll C oil and gas platform, 100-km north-west of Bergen, Norway. A mandrel and its six inch supporting pipe were pulled out of position during an operation, overloading the pipe and forcing the shut-down of an associated 10-inch line, halting production. “At that depth solutions were limited,” said Hydratight application engineer Mark Fisher. A six-inch super duplex MORGRIP end-connector had to be a specially engineered solution to fit within the significant physical constraints of the damaged manifold. “The cracked pipe was partially inside the manifold, so we had to ensure that the MORGRIP’S overall dimensions were an absolute minimum to get it to fit,” explained Mark. The pipe – which carries a mixture of water, oil and gas – was pressuretested to 267 bar after the procedure, and will be tested again from time to time to make sure the pipe hasn’t deteriorated further. The MORGRIP successfully sealed the line in accordance with Statoil’s requirements. The pipe integrity was retained with no de-rating of the pipeline or deviation from original design.

Expanded pipeline coatings portfolio AS PART OF its continuing efforts to address the growing needs and demands of the region’s oil and gas segment and general pipeline industries, Jotun Powder Coatings, has revealed a strategic move to expand its current pipeline coatings portfolio. To bolster this move, the company has combined its powder and liquid coatings to create and develop a new extensive range of pipeline coating solutions; providing transmission pipelines with the required protection – both inside and out. The move complements Jotun’s efforts to increase its regional market share over the next three years. The move also aims to create a one-stop-shop for Jotun’s customers and provide a single point of contact to meet the unique pipeline coating needs of oil and gas companies and pipeline applicators - making the entire process smoother, more efficient, quicker and more economical. To date, Jotun currently enjoys a 30 per cent market share of the Middle East pipeline coatings market and plans to significantly increase its presence over the next three years. Jotun is widely recognized as a leading pipeline coating solutions provider; protecting more than 100,000-km of pipelines over the last 30 years. “Combining both liquid and powder coatings to create a new range of pipeline coating solutions that provide the best protection inside and out, is in line with our move towards achieving an increased presence in the region’s pipeline coatings segment,” said Andrea Meconcelli, Global Commercial Director for Functional and Architectural - Jotun Powder Coatings and the Global Concept Manager for Jotun Pipeline Solutions. “Our dedication towards the research and development of improved powder and liquid coating solutions has placed us at the forefront of the coatings industry. Jotun will continue to remain steadfast in its commitment to meet the demands of our growing customer base by offering a more streamlined supply chain covering all stages - from quotation to delivery.”

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78 Oil Review Middle East Issue Four 2012

USA A

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Communications & IT

How information management puts you in control of operational success, by Dirk Drozd, Senior Vice President - Middle East, AVEVA.

Unlocking the

silos A

RGUABLY THE MOST cost-effective investment that any plant operator can make today lies in Information Management software. Learn how current technologies can bring measurable business value in asset management.

The solution is not conventional data warehouse technology

The solution The problem The information necessary for efficient plant operation is often fragmented, hard to access and use, and of uncertain reliability. Over time, the many different applications for different tasks, each with its own data format, have created ‘silos’ of information: isolated, unable to be cross-referenced, and hard to use without the originating software.

The solution is not conventional data warehouse technology. The data is already stored, ‘warts and all’; the need is to find a better way of using it. Recognising this, AVEVA developed a solution to unlock the silos – AVEVA NET. AVEVA NET enables users right across the business to visualise and collaborate on all types of data and documents – securely, in a

highly automated way, and without any need for the original authoring applications in which the data was created. Through the AVEVA NET Gateways it can access and integrate disparate information, from documents and schematic diagrams to 3D models and even real-time process data, from any system the organisation has already invested in. It is read-only, so source data is not compromised; it validates and cross-references data automatically on

Blueback Reservoir Your Petrel plug-in developer We utilize the Ocean* development framework from Schlumberger to develop both commercial and proprietary plug-in products for Petrel*. Our strong knowledge within the domains of software development, commercialization and geosciences, provides us the best conditions for turning ideas into elegant and

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import, highlighting your data’s maturity, inconsistencies and gaps for correction. AVEVA describes this process as creating a ‘digital plant’, the accurate, as-built counterpart in the information world of the real plant in the physical world. And just as one can walk around and examine the real plant, so AVEVA NET enables any user, anywhere across the enterprise, to navigate the complex information asset that is the digital plant, using an intuitive browser application.

Extracting the asset value Once AVEVA NET is integrated with other

enterprise systems, such as engineering and design, ERP, financial management, or Enterprise Asset Management (EAM) solutions including AVEVA WorkMate, it can provide an unrivalled level of control over even the most complex assets. Correlating and viewing hitherto incompatible information can reveal and quantify hidden causes of operational issues, greatly enhancing the value of the existing management solutions. Equally valuable, AVEVA NET can compile reports from many data sources, including KPIs. This can also enable regulatory compliance reports to be configured, scheduled, and

updated as requirements change. There is also growing interest in using the technology to handle shift handover logs, where it can automate data entry, guarantee the transfer of accurate information between teams and reduce operational inefficiencies and risk. With AVEVA Information Management software at their fingertips, plant operators can ensure their asset performs reliably, safely and cost effectively. Managing and exploiting all the information available about the asset and unlocking the full value of their information assets will deliver measurable bottom line benefits. ■

Schlumberger acquires GEDCO

Sonardyne receives SPRINT order

SCHLUMBERGER HAS ACQUIRED GEDCO, a Calgary-based provider of integrated geophysical survey design software and services. The group will become part of the WesternGeco business unit. GEDCO has developed OMNI 3D*, the industry’s standard for seismic survey design and modeling, and VISTA*, a flexible 2D/3D seismic data processing package. The group also offers www.slb.com consulting services for 2D and 3D seismic and vertical seismic profile (VSP) solutions from design through interpretation. As the industry explores for oil and gas in increasingly complex geological environments with higher risks and ever increasing time pressure, survey design and modeling becomes even more critical to success.

SONARDYNE INTERNATIONAL LTD has received an order valued at over US$3mn from international oil and gas turnkey contractor, Saipem. The order includes six SPRINT systems and associated acoustic positioning equipment making it Sonardyne’s largest sale of acoustically aided inertial navigation technology to date. SPRINT (Subsea Precision Reference Inertial Navigation Technology) will be deployed in April in the West Delta Deep Marine concession (WDDM). This natural gas field is situated about 90-km offshore the North-West Nile Delta, at water depths between 400 and 1,000 metres. Saipem is responsible for the engineering, procurement, construction and installation of a total of eight new subsea wellheads and relevant infrastructures, umbilicals and flowlines. Since its launch in 2010 SPRINT has been operationally proven to extend the operating limits and increase the efficiency of subsea operations when using Ultra Short BaseLine (USBL) and Long BaseLine (LBL) positioning systems. In the Sparse LBL mode that Saipem plans to operate SPRINT in at WDDM, surveyors will be able to obtain accurate high integrity positioning data with less equipment to deploy than full LBL. This will significantly reduce operation time and vessel costs. SPRINT tightly couples Sonardyne’s Lodestar INS platform with Fusion 6G, the industry standard LBL system. With known transponder positions, the Lodestar mounted on an ROV can use the ranges from one or more seabed deployed transponders to acoustically aid the INS and constrain error growth in the absolute position output. Commenting on the order, Sonardyne’s Vice President Europe and Africa, Barry Cairns said, “We are delighted that Saipem has shown its commitment to SPRINT. The company has been a major user of Sonardyne products for many years and this latest order is recognition of the major cost and time savings SPRINT and sparse LBL will bring to its field development projects.”

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S19 ORME 4 2012 Arabic_Layout 1 03/05/2012 15:23 Page 84

19th International

CASPIAN OIL & GAS Exhibition and Conference Incorporating

Refining & Petrochemicals

5-8 June 2012 Baku • Azerbaijan

www.caspianoil-gas.com

LEADING OIL & GAS EVENT IN CASPIAN REGION

London • Moscow • Almaty • Baku • Tashkent • Atyrau • Aktau • Istanbul • Hamburg • Beijing • Poznan • Dubai

S19 ORME 4 2012 Arabic_Layout 1 03/05/2012 15:24 Page 85

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S19 ORME 4 2012 Arabic_Layout 1 03/05/2012 15:24 Page 87

É«eƒj á«aÉ°VGE §Øf ÅaÉμe π«eôH 5200 `H »°ûJÉHGC êÉàfGE OGR

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THE 4 TH SAUDI ARABIA INTERNATIONAL OIL & GAS EXHIBITION 24-26 SEPTEMBER 2012 DAMMAM, KINGDOM OF SAUDI ARABIA WWW.SAOGE.ORG

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É¡LÉàfGE øe ójõJ Ió«MƒdG øjôëÑdG IÉØ°üe

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ADVERTISERS INDEX Company ................................................Page Adghal Oilfield Supplies LLC..................................71 Aggreko Middle East Limited ..................................4 Al Mansoori ..............................................................15 ALAA Industrial Equipment Factory ....................16 Asturi Metal Builders (M) SDN BHD ....................41 Aveva Solutions Ltd ................................................47 Bapco ........................................................................45 Blueback Reservoir AS ..........................................79 Bredero Shaw ..........................................................13 Cansco Dubai LLC ....................................................91 CARBO Ceramics ....................................................30 Chevron ....................................................................10 DMG World Media (ADIPEC 2012) ..................................................49, 82 DMT GmbH and Company KG ..............................41 Dolphin Oilfield Equipment Services ..................28 Draeger Safety ........................................................44 Duferco ......................................................................64 Elliott Group ............................................................27 Emerson Process Management Valve Automation INC ..........................................17

Expotim International Fair ORG. INC (Basra Oil & Gas 2012) ..........................................86 Fugro Geoteam AS ....................................................7 Gates Engineering and Services ..........................53 Hi-Force Ltd. ............................................................19 Hydroflow Pump Rental Est ..................................63 Inmarco Industries FZC ..........................................44 Inova Geophysical Equipment Limited ..............69 International Exhibition Services SRL (SAOGE 2012) ..........................................................88 ITE Group Plc (Caspian Oil & Gas 2012) ..............84 Jotun Paints U.A.E. Ltd LLC ....................................5 LITREMETER ..............................................................73 Magnetrol International N.V. ................................60 Marelli Motori S.p.A. ..............................................31 Metscco Heavy Steel Industries Company Limited ....................................................33 Middle East Specialised Cables (MESC) ............67 Mimo Contracting ..................................................51 Nexans ......................................................................21 Oil Lift Technology Inc. ..........................................77 Oman Cement Company ........................................35

Petrotech Enterprises LLC ......................................37 Prakash Steelage Ltd. ............................................55 Ras Laffan Industrial City ......................................56 Red Helix International Ltd. ..................................42 Sabin Metal Corporation ........................................25 Saga PCE Pte Ltd ....................................................29 Schlumberger Oilfield Mktg Communications ....57 Schlumberger Technical Services, Inc. ................2 Shree Steel Overseas FZCO ..................................63 Sin Hiap Chuan Hardware and Engineering Pte Ltd ................................................73 Southern California Valve ......................................59 Specialized Oilfield Products ..................................9 Spina Group Srl ........................................................54 Suraj Limited ............................................................49 Tenaris ......................................................................23 Tranter Heat Exchangers ME (Cyprus) Ltd ..........39 Triplefast Middle East ............................................59 Veritas-MSI China Company Limited ..................80 VF Imagewear/Bulwark ........................................65 Voith Turbo GmbH & Co KG ..................................42 Ward Leonard Electric Company, Inc. ................78

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